BEST AVAILABLE RETROFIT TECHNOLOGY (BART) DETERMINATION

AMERICAN ELECTRIC POWER  NORTHEASTERN POWER PLANT

Prepared by: 

N.N. Dharmarajan  AEP 

Eugene Chen, P.E.  Senior Consultant 

Jeremy Townley  Consultant 

TRINITY CONSULTANTS

120 East Sheridan 

Suite 205 

Oklahoma City, OK 73104 

(405) 228-3292 

May 30, 2008 

Project 083701.0024 
American Electric Power i Trinity Consultants 

Northeastern Power Station 083701.0024 

TABLE OF CONTENTS

1. EXECUTIVE SUMMARY ........................................................................................ 1-1

2. BACKGROUND...................................................................................................... 2-1

2.1 BEST AVAILABLE RETROFIT TECHNOLOGY RULE................................................. 2-1 

2.2 MODELING PROTOCOL BACKGROUND .................................................................. 2-1 

2.3 LOCATION OF SOURCES AND RELEVANT CLASS I AREAS...................................... 2-2 

3. CALPUFF MODEL SYSTEM ............................................................................... 3-1

3.1 MODEL VERSIONS................................................................................................. 3-1 

3.2 MODELING DOMAIN ............................................................................................. 3-1 

4. CALMET............................................................................................................ 4-1

4.1 GEOPHYSICAL DATA............................................................................................. 4-1 

4.1.1 TERRAIN DATA ...................................................................................................4-1

4.1.2 LAND USE DATA.................................................................................................4-2

4.1.3 COMPILING TERRAIN AND LAND USE DATA.......................................................4-3

4.2 METEOROLOGICAL DATA ..................................................................................... 4-3 

4.2.1 MESOSCALE MODEL METEOROLOGICAL DATA .................................................4-3

4.2.2 SURFACE METEOROLOGICAL DATA ...................................................................4-4

4.2.3 UPPER AIR METEOROLOGICAL DATA.................................................................4-5

4.2.4 PRECIPITATION METEOROLOGICAL DATA..........................................................4-6

4.2.5 BUOY METEOROLOGICAL DATA.........................................................................4-7

4.3 CALMET CONTROL PARAMETERS....................................................................... 4-8 

4.3.1 VERTICAL METEOROLOGICAL PROFILE..............................................................4-8

4.3.2 INFLUENCES OF OBSERVATIONS .........................................................................4-9

5. CALPUFF........................................................................................................... 5-1

5.1 SOURCE EMISSIONS............................................................................................... 5-1 

5.2 RECEPTOR LOCATIONS.......................................................................................... 5-1 

5.3 BACKGROUND OZONE AND AMMONIA.................................................................. 5-1 

5.4 CALPUFF MODEL CONTROL PARAMETERS......................................................... 5-1 

6. CALPOST........................................................................................................... 6-1

6.1 CALPOST – LIGHT EXTINCTION ALGORITHM ..................................................... 6-1 

6.2 CALPOST PROCESSING METHOD......................................................................... 6-2 

6.3 NATURAL BACKGROUND ...................................................................................... 6-2 

6.4 EVALUATING VISIBILITY RESULTS ....................................................................... 6-2 

6.5 SUMMARY OF CALPOST CONTROL PARAMETERS............................................... 6-2 
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7. BART-ELIGIBLE EMISSION UNITS..................................................................... 7-1

7.1 DESCRIPTION OF BART-ELIGIBLE SOURCES .......................................................... 7-1 

7.2 MODELED STACK PARAMETERS ........................................................................... 7-2 

8. BART DETERMINATION ANALYSIS FOR NOX.................................................... 8-1

8.1 STEP 1 - IDENTIFY ALL AVAILABLE RETROFIT CONTROL TECHNOLOGIES............ 8-1 

8.1.1 COMBUSTION MODIFICATIONS ...........................................................................8-2

8.1.1.1 Flue Gas Recirculation ........................................................................8-2

8.1.1.2 Low NOX Burners and Overfire Air....................................................8-3

8.1.1.3 Reburning / Methane de-NOX .............................................................8-3

8.1.2 POST-COMBUSTION CONTROLS ..........................................................................8-4

8.1.2.1 Selective Non-Catalytic Reduction .....................................................8-4

8.1.2.2 Selective Catalytic Reduction..............................................................8-6

8.2 STEP 2 – ELIMINATE TECHNICALLY INFEASIBLE OPTIONS .................................... 8-7 

8.2.1 FLUE GAS RECIRCULATION ................................................................................8-8

8.2.2 REBURNING / METHANE DE-NOX .......................................................................8-8

8.3 STEP 3 – EVALUATE CONTROL EFFECTIVENESS OF REMAINING CONTROL 

TECHNOLOGIES..................................................................................................... 8-8 

8.4 STEP 4 – EVALUATE IMPACTS AND DOCUMENT RESULTS ..................................... 8-9 

8.4.1 COSTS OF COMPLIANCE ......................................................................................8-9

8.4.2 ENERGY IMPACTS & NON-AIR IMPACTS ..........................................................8-10

8.4.3 REMAINING USEFUL LIFE .................................................................................8-11

8.5 STEP 5 – EVALUATE VISIBILITY IMPACTS ........................................................... 8-11 

8.6 BART DETERMINATION FOR NOX...................................................................... 8-12 

9. BART DETERMINATION ANALYSIS FOR SO2..................................................... 9-1

9.1 STEP 1 - IDENTIFY ALL AVAILABLE RETROFIT CONTROL TECHNOLOGIES............ 9-1 

9.1.1 DRY FLUE GAS DESULFURIZATION ....................................................................9-1

9.1.2 WET FLUE GAS DESULFURIZATION....................................................................9-1

9.2 STEP 2 – ELIMINATE TECHNICALLY INFEASIBLE OPTIONS .................................... 9-2 

9.3 STEP 3 – EVALUATE CONTROL EFFECTIVENESS OF REMAINING CONTROL 

TECHNOLOGIES..................................................................................................... 9-2 

9.4 STEP 4 – EVALUATE IMPACTS AND DOCUMENT RESULTS ..................................... 9-2 

9.4.1 COST OF COMPLIANCE ........................................................................................9-3

9.4.2 ENERGY IMPACTS AND NON-AIR QUALITY IMPACTS.........................................9-3

9.4.3 REMAINING USEFUL LIFE ...................................................................................9-3

9.5 STEP 5 – EVALUATE VISIBILITY IMPACTS ............................................................. 9-3 

9.6 BART DETERMINATION FOR SO2 ......................................................................... 9-4 

APPENDIX A- METEOROLOGICAL STATIONS

APPENDIX B – SAMPLE CALMET CONTROL FILE
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APPENDIX C – SAMPLE CALPUFF CONTROL FILE

APPENDIX D – SAMPLE CALPOST CONTROL FILE

APPENDIX E – CONTROL SCENARIO EMISSION ESTIMATES

APPENDIX F – CONTROL COST CALCULATIONS

APPENDIX G – CALPUFF SYSTEM MODEL FILES
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LIST OF TABLES

TABLE 1-1. NORTHEASTERN STATION BART DETERMINATION SUMMARY......................................1-2

TABLE 2-1. BART-ELIGIBLE SOURCES ...............................................................................................2-2

TABLE 2-2. DISTANCE (KM) FROM STATION TO SURROUNDING CLASS I AREAS ..............................2-2

TABLE 3-1 CALPUFF MODELING SYSTEM VERSIONS ......................................................................3-1

TABLE 4-1. VERTICAL LAYERS OF THE CALMET METEOROLOGICAL DOMAIN................................4-9

TABLE 6-1. MONTHLY HUMIDITY FACTORS.......................................................................................6-2

TABLE 6-2. DEFAULT AVERAGE ANNUAL NATURAL BACKGROUND LEVELS ...................................6-2

TABLE 7-1. SUMMARY OF BART-ELIGIBLE EMISSION UNITS............................................................7-1

TABLE 7-2. STACK PARAMETERS .......................................................................................................7-2

TABLE 8-1. AVAILABLE NOX CONTROL TECHNOLOGIES...................................................................8-8

TABLE 8-2. RANKING OF CONTROL TECHNOLOGIES..........................................................................8-9

TABLE 8-3. NOX CONTROL COSTS SUMMARY .................................................................................8-10

TABLE 8-4. NE STATION NOX VISIBILITY RESULTS.........................................................................8-11

TABLE 9-1. RANKING OF CONTROL STRATEGIES ...............................................................................9-2

TABLE 9-2. SO2 CONTROLS COSTS SUMMARY...................................................................................9-3

TABLE 9-3. NE STATION SO2 VISIBILITY RESULTS............................................................................9-4

TABLE A-1. LIST OF SURFACE METEOROLOGICAL STATIONS ............................................................... 1

TABLE A-2. LIST OF UPPER AIR METEOROLOGICAL STATIONS............................................................. 5

TABLE A-3. LIST OF PRECIPITATION METEOROLOGICAL STATIONS...................................................... 6

TABLE A-4. LIST OF OVER WATER METEOROLOGICAL STATIONS...................................................... 14
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LIST OF FIGURES

FIGURE 2-1. PLOT OF SOURCES AND NEAREST CLASS I AREAS .........................................................2-3

FIGURE 3-1. REFINED METEOROLOGICAL MODELING DOMAIN.........................................................3-2

FIGURE 4-1. PLOT OF LAND ELEVATION USING USGS TERRAIN DATA ............................................4-2

FIGURE 4-2. PLOT OF LAND USE USING USGS LULC DATA.............................................................4-3

FIGURE 4-3. PLOT OF SURFACE STATION LOCATIONS........................................................................4-5

FIGURE 4-4. PLOT OF UPPER AIR STATIONS LOCATIONS ...................................................................4-6

FIGURE 4-5. PLOT OF PRECIPITATION METEOROLOGICAL STATIONS .................................................4-7

FIGURE 4-6. PLOT OF BUOY METEOROLOGICAL STATIONS ................................................................4-8

FIGURE 8-1. PRIMARY SNCR REACTION SEQUENCES........................................................................8-5

 
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1. EXECUTIVE SUMMARY

American Electric Power /Public Service Company of Oklahoma (AEP/PSO) operates the 

Northeastern (NE) Power Station, which is located at Section 4, T22N, R15E, in Rogers County, 

Oklahoma. The NE Power Station is currently operating in accordance with Oklahoma Department 

of Environmental Quality (DEQ) Title V Operating Permit, 96-288-TV, issued in June 30, 1999. The 

NE Power Station is considered eligible for the application of Best Available Retrofit Technology 

(BART)1

 as part of the Environmental Protection Agency (EPA) Regional Haze Rule. 

On March 30, 2007, AEP submitted to the Oklahoma DEQ, the BART determination for its BART 

eligible facilities in Oklahoma, in accordance with OAC 252:100, Subchapter 8, Permits for Part 70 

Sources, Part 11, Visibility Protection Standards, effective October 8, 2006. Specifically, AEP 

indicated that it would: 

S For its gas-fired NE Unit 2, meet the BART requirement to satisfy the “40CFR Part 51, 

Regional Haze regulations and Guidelines for Best Available Retrofit Technology (BART) 

Determinations; Final Rule, in effect on July 2005, of “current combustion control 

technology” for NOx control, as specified in these rules 

S For its solid-fuel fired NE Units 3 & 4, it would meet the “presumptive limits” for SO2 and 

NOx (as applicable to plants greater than 750 MW for the type of fuel and boiler), in 

accordance with the same 40CFR Part 51 rules cited above. For SO2 control, the presumptive 

limit of 0.15 Lbs/MMBtu would be met on a 30-day rolling average using Flue Gas 

Desulfurization (FGD) and for NOx control, the presumptive limit of 0.15 Lbs/MMBtu 

would be met on a 30-day rolling average using Low NOx burners/Overfire air. 

S The electrostatic precipitators would be BART for PM based on the modeling and 

engineering analysis performed and submitted to the Oklahoma DEQ. 

In a letter reply dated December 12, 2007, from Mr. Eddie Terrill, the Oklahoma DEQ requested a 

formal five-factor analysis be performed in order to determine BART for NOX and SO2 for NE units 3 

& 4. 

This report summarizes the result of the five factor analysis performed for SO2 and NOx for the 

BART-eligible Units 3 & 4 at the Northeastern Station. The message to be gleaned from the 

discussions in these sections, is that the high implementation costs to gain emissions reductions with 

minimal 98th percentile perceptible visibility benefits would seem to suggest that BART for these 

units be the existing low NOx burners for NOx and low sulfur fuel for SO2. As summarized in Table 

1-1 below, AEP proposes the following measures as BART: 

 

1

 40 CFR 51 Appendix Y, Guidelines for BART Determinations Under the Regional Haze Rule 
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TABLE 1-1. NORTHEASTERN STATION BART DETERMINATION SUMMARY

Unit ID NOX BART 

Determination 

SO2 BART 

Determination 

Northeastern Unit 3 Low-NOX Burners Low Sulfur coal 

Northeastern Unit 4 Low- NOX Burners Low Sulfur coal 

The five factors considered in determining BART described in this report are: 

▲ Cost of compliance 

▲ Energy impacts 

▲ Non-air quality impacts 

▲ The remaining useful life of the source; and 

▲ Visibility impacts 

Evaluation of the fifth factor, visibility impacts, requires the use of the CALPUFF modeling system. 

A substantial portion of this document (Sections 3-6) is devoted to describing the modeling 

methodology used in determining potential visibility impacts from the NE Station’s BART-eligible 

units 3 & 4: 

▲ Section 2 – Background 

▲ Section 3 – CALPUFF Modeling System 

▲ Section 4 – CALMET 

▲ Section 5 – CALPUFF 

▲ Section 6 – CALPOST 

▲ Section 7 – BART-eligible Units 

▲ Section 8 – NOX BART Determination 

▲ Section 9 – SO2 BART Determination 

The CALMET data set described in Section 4 was developed in adherence to the CALMET 

processing protocol approved by the Oklahoma DEQ on March 10, 2008, for a similar BARTdetermination related modeling effort. CALPUFF and CALPOST settings described in Section 5 and 

6 (sample files of which are included in the Appendices) have not been reviewed by the state but 

adhere, where practical, to the modeling settings and procedures established in CENRAP’s BART 

Modeling Guidelines.

2

 

Sections 7-9 address the five-factor analysis for NOX and SO2, and include an analysis of compliance 

costs and visibility impacts of various control technologies: 

 2

 Released December 2005. 
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2. BACKGROUND

2.1 BEST AVAILABLE RETROFIT TECHNOLOGY RULE

On July 1, 1999, the U.S. Environmental EPA published the final Regional Haze Rule (RHR). The 

stated “goal “ of the RHR is to restore visibility in 156 specific areas known as Class I areas, to 

natural background levels, over a 60-year period, across the United States. The Clean Air Act defines 

Class I areas as certain national parks (over 6000 acres), wilderness areas (over 5000 acres), national 

memorial parks (over 5000 acres), and international parks that were in existence on August 7, 1977. 

On July 6, 2005, the EPA published amendments to its 1999 RHR, (also known as the BART rule) 

that included guidance for making source-specific Best Available Retrofit Technology (BART) 

determinations. The BART rule defines BART-eligible sources as sources that meet the following 

criteria: 

(1) Have potential emissions of at least 250 tons per year of a visibility-impairing pollutant, 

(2) Began operation between August 7, 1962 and August 7, 1977, and 

(3) Are listed as one of the 26 listed source categories in the guidance. 

A BART-eligible source is not automatically subject to BART. Rather, BART-eligible sources are 

subject-to-BART if the sources are “reasonably anticipated to cause or contribute to visibility 

impairment in any federal mandatory Class I area.” EPA has determined that sources are reasonably 

anticipated to cause or contribute to visibility impairment if the visibility impacts from a source are 

greater than 0.5 deciviews (dv) when compared against a natural background. 

Air quality modeling is the tool that is used to determine a source’s visibility impacts. States have the 

authority to exempt certain BART-eligible sources from installing BART controls if the results of the 

dispersion modeling demonstrate that the source cannot reasonably be anticipated to cause or 

contribute to visibility impairment in a Class I area. Further, States also have the authority to define 

the modeling procedures for conducting modeling related to making BART determinations. 

2.2 MODELING PROTOCOL BACKGROUND

To promote consistency between States in the development of BART modeling protocols and to 

harmonize the approaches between adjacent RPOs, the Central States Regional Air Planning 

(CENRAP) organization developed BART Modeling Guidelines (December 15, 2005). The intent of 

the guidelines was to assist CENRAP States and source operators in the development of statewide and 

source-specific modeling protocols. 
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2.3 LOCATION OF SOURCES AND RELEVANT CLASS I AREAS

The sources listed in Table 2-1. BART-Eligible Sources are the sources that have been identified by 

AEP as sources that meet the three criteria for BART-eligible sources at the NE Station. 

TABLE 2-1. BART-ELIGIBLE SOURCES

EPN Description 

Unit 2 4,754 MMBtu/hr Gas-fired 

Unit 3 4,775 MMBtu/hr Coal Fired Boiler 

Unit 4 4,775 MMBtu/hr Coal Fired Boiler 

As required in CENRAP’s BART Modeling Guidelines, Class I areas within 300 km of each station 

will be included in each analysis. The following tables summarize the distances of the four closest 

Class I areas to the NE station. As seen from this summary, one Class I area (Wichita Mountains 

NWR) is more than 300 km from the station, but has been included in the analysis. Note that the 

distances listed in the tables below are the distances between the stations and the closest border of the 

Class I areas. 

TABLE 2-2. DISTANCE (KM) FROM STATION TO SURROUNDING CLASS I AREAS

Class I Area Name Distance from Source 

(km)

Caney Creek Wilderness 263 

Hercules-Glades Wilderness 244 

Upper Buffalo Wilderness 211 

Wichita Mountains National Wildlife Refuge 323 

A plot of the Class I areas with respect to the station is provided in Figure 2-1. 
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 FIGURE 2-1. PLOT OF SOURCES AND NEAREST CLASS I AREAS

-800 -600 -400 -200 0 200 400 600 800

LCC Easting (km)

-1600

-1400

-1200

-1000

-800

-600

-400

-200

LCC Northing (km)

Northeastern Station

WIMO

CACR

UPBU

HEGL

Class I Areas
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3. CALPUFF MODEL SYSTEM

The main components of the CALPUFF modeling system are CALMET, CALPUFF, and CALPOST. 

CALMET is the meteorological model that generates hourly three-dimensional meteorological fields 

such as wind and temperature. CALPUFF simulates the non-steady state transport, dispersion, and 

chemical transformation of air pollutants emitted from a source in “puffs.” CALPUFF calculates 

hourly concentrations of visibility affecting pollutants at each specified receptor in a modeling 

domain. CALPOST is the post-processor for CALPUFF that computes visibility impacts from a 

source based on the visibility affecting pollutant concentrations that were output by CALPUFF. 

3.1 MODEL VERSIONS

The versions of the CALPUFF modeling system programs that were used for conducting AEP’s 

BART modeling are listed in Table 3-1. 

TABLE 3-1 CALPUFF MODELING SYSTEM VERSIONS

Processor Version Level 

TERREL 3.3 030402 

CTGCOMP 2.21 030402 

CTGPROC 2.63 050128 

MAKEGEO 2.2 030402 

CALMET 5.53a 040716 

CALPUFF 5.8 070623 

POSTUTIL 1.3 030402 

CALPOST 5.6394 070622 

3.2 MODELING DOMAIN

The CALPUFF modeling system utilizes three modeling grids: the meteorological grid, the 

computational grid, and the sampling grid. The meteorological grid is the system of grid points at 

which meteorological fields are developed with CALMET. The computational grid determines the 

computational area for a CALPUFF run. Puffs are advected and tracked only while within the 

computational grid. The meteorological grid is defined so that it covers the areas of concern and 

gives enough marginal buffer area for puff transport and dispersion. A plot of the meteorological 

modeling domain with respect to the Class I areas being modeled is provided in Figure 3-1. The 
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computational domain was set to extend at least 50 km in all directions beyond the NE Station and the 

Class I areas of interest. Note that the map projection for the modeling domain was Lambert 

Conformal Conic (LCC) and the datum was the World Geodetic System 84 (WGS-84). The reference 

point for the modeling domain is Latitude 40oN, Longitude 97oW. The southwest corner was set to -

951.547 km LCC, -1646.637 km LCC corresponding to Latitude 24.813 oN and Longitude 87.778oW. 

The meteorological grid spacing was 4 km, resulting in 462 grid points in the X direction and 376 

grid points in the Y direction. 

FIGURE 3-1. REFINED METEOROLOGICAL MODELING DOMAIN

-800 -600 -400 -200 0 200 400 600 800

LCC Easting (km)

-1600

-1400

-1200

-1000

-800

-600

-400

-200

LCC Northing (km)

Northeastern Station

WIMO

CACR

UPBU

HEGL

Class I Areas

Meteorological Modeling Domain

Computational Modeling Domain 1
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4. CALMET

CALMET is the meteorological processor that compiles meteorological data from raw observations 

of surface and upper air conditions, precipitation measurements, mesoscale model output, and 

geophysical parameters into a single hourly, gridded data set for input into CALPUFF. CALMET 

was used to assimilate data for 2001- 2003 using National Weather Service (NWS) surface station 

observations, upper air station observations, precipitation station observations, buoy station 

observations (for overwater areas), and mesoscale model output to develop the meteorological field. 

4.1 GEOPHYSICAL DATA

CALMET requires geophysical data to characterize the terrain and land use parameters that 

potentially affect dispersion. Terrain features affect flows and create turbulence in the atmosphere 

and are potentially subjected to higher concentrations of elevated puffs. Different land uses exhibit 

variable characteristics such as surface roughness, albedo, Bowen ratio, and leaf-area index that also 

effect turbulence and dispersion. 

4.1.1 TERRAIN DATA

Terrain data was obtained from the United States Geological Survey (USGS) in 

1-degree (1:250,000 scale or approximately 90 meter resolution) digital format. The 

USGS terrain data was then processed by the TERREL program to generate grid-cell 

elevation averages across the modeling domain. A plot of the land elevations based on the 

USGS data for the modeling domain is provided in Figure 4-1. 
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FIGURE 4-1. PLOT OF LAND ELEVATION USING USGS TERRAIN DATA

-800 -600 -400 -200 0 200 400 600 800

LCC Easting(km)

-1600

-1400

-1200

-1000

-800

-600

-400

-200

LCC 

Northing (km)

Northeastern Station

0

982

1960

2950

3930

Terrain 

Elevation (m)

4.1.2 LAND USE DATA

The land use land cover (LULC) data from the USGS North American land cover 

characteristics data base in the Lambert Azimuthal equal area map projection was used in 

order to determine the land use within the modeling domain. The LULC data was 

processed by the CTGPROC program which generated land use for each grid cell across 

the modeling domain. A plot of the land use based on the USGS data for the modeling 

domain is provided in Figure 4-2. 
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FIGURE 4-2. PLOT OF LAND USE USING USGS LULC DATA

4.1.3 COMPILING TERRAIN AND LAND USE DATA

The terrain data files output by the TERELL program and the LULC files output by the 

CTGPROC program were uploaded into the MAKEGEO program to create a geophysical 

data file that was input into CALMET. 

4.2 METEOROLOGICAL DATA 

CALMET was used to assimilate data for 2001, 2002, and 2003 using mesoscale model output and 

National Weather Service (NWS) surface station observations, upper air station observations, 

precipitation station observations, and National Oceanic and Atmosphere Administrations (NOAA) 

buoy station observations to develop the meteorological field. 

4.2.1 MESOSCALE MODEL METEOROLOGICAL DATA

Hourly mesoscale data was also used as the initial guess field in developing the CALMET 

meteorological data. It is AEP’s intent to use the following 5th generation mesoscale model 

meteorological data sets (or MM5 data) in the analysis: 

• 2001 MM5 data at 12 km resolution generated by the U.S. EPA 

• 2002 MM5 data at 36 km resolution generated by the Iowa DNR 

-800 -600 -400 -200 0 200 400 600 800

LCC Easting (km)

-1600

-1400

-1200

-1000

-800

-600

-400

-200

L

C

C

N

o

r

t

h

i

n

g

(

k

)

m

10

27.5

45

62.5

80

Land Use

Northeastern Station
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• 2003 MM5 data set at 36 km resolution generated by the Midwest RPO 

The specific MM5 data that was used are subsets of the data listed above. As the 

contractor to CENRAP for developing the meteorological data sets for the BART 

modeling, Alpine Geophysics extracted three subsets of MM5 data for each year from 

2001 to 2003 from the data sets listed above using the CALMM5 extraction program. The 

three subsets covered the northern, central, and southern portions of CENRAP. AEP is 

proposing to use the southern set of the extracted MM5 data. 

The 2001 southern subset of the extracted MM5 data includes 30 files that are broken into 

10 to 11 day increments (3 files per month). The 2002 and 2003 southern subsets of 

extracted MM5 data include 12 files each of which are broken into 30 to 31 day increment 

files (1 file per month). Note that the 2001 to 2003 MM5 data extracted by Alpine 

Geophysics was not able to be used directly in the modeling analysis. To run the Alpine 

Geophysics extracted MM data in the EPA approved CALMET program, each of the MM5 

files needed to be adjusted by appending an additional six (6) hours, at a minimum, to the 

end of each file to account for the shift in time zones from the Greenwich Mean Time 

(GMT) prepared Alpine Geophysics data to Time Zone 6 for this analysis. No change to 

the data occurred. 

The time periods covered by the data in each of the MM5 files extracted by Alpine 

Geophysics include a specific number of calendar days, where the data starts at Hour 0 in 

GMT for the first calendar day and ends at Hour 23 in GMT on the last calendar day. In 

order to run CALMET in the local standard time (LST), which is necessary since the 

surface meteorological observations are recorded in LST, there must be hours of MM5 data 

referenced in a CALMET run that match the LST observation hours. Since the LST hours 

in Central Standard Time (CST) are 6 hours behind GMT, it is necessary to adjust the data 

in each MM5 file so that the time periods covered in the files match CST. 

Based on the above discussion, the Alpine Geophysics MM5 data was not used directly. 

Instead the data files were modified to add 8 additional hours of data to the end of each file 

from the beginning of the subsequent file. CALMET was then run using the appended 

MM5 data to generate a contiguous set of CALMET output files. The converted MM5 

data files occupy approximately 1.2 terabytes (TB) of hard drive space. 

4.2.2 SURFACE METEOROLOGICAL DATA

Parameters affecting turbulent dispersion that are observed hourly at surface stations 

include wind speed and direction, temperature, cloud cover and ceiling, relative humidity, 

and precipitation type. AEP used the surface stations listed in Table A-1 of Appendix A. 

The locations of the surface stations with respect to the modeling domain are shown in 

Figure 4-3. The stations were selected from the available data inventory to optimize spatial 

coverage and representation of the domain. Data from the stations was processed for use in 

CALMET using EPA’s SMERGE program. 
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Missing surface data was filled using procedures recommended by U.S. EPA.3 Missing 

data periods of 5 hours or less were replaced using these procedures. For periods greater 

than 5 hours, data was left either unfilled or was not used in CALMET processing. A large 

enough quantity of surface stations was included in the domain that overlapping areas of 

influence allowed data from an alternate station to be used. 

FIGURE 4-3. PLOT OF SURFACE STATION LOCATIONS

-800 -600 -400 -200 0 200 400 600 800

LCC Easting (km)

-1600

-1400

-1200

-1000

-800

-600

-400

-200

LCC Northing (km)

Northeastern Station

WIMO

CACR

UPBU

HEGL

Class I Areas

Surface Stations

4.2.3 UPPER AIR METEOROLOGICAL DATA

Observations of meteorological conditions in the upper atmosphere provide a profile of 

turbulence from the surface through the depth of the boundary layer in which dispersion 

occurs. Upper air data are collected by balloons launched simultaneously across the 

observation network at 0000 Greenwich Mean Time (GMT) (6:00 PM CST in Oklahoma) 

and 1200 GMT (6:00 AM CST in Oklahoma). Sensors observe pressure, wind speed and 

direction, and temperature (among other parameters) as the balloon rises through the 

 3

 “Procedures for Substituting Values for Missing NWS Meteorological Data for Use in Regulatory Air Quality 

Models”, Dennis Atkinson and Russell F. Lee, July 7, 1992, http://www.epa.gov/scram001/surface/missdata.txt 
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atmosphere. The upper air observation network is less dense than surface observation 

points since upper air conditions vary less and are generally not as affected by local effects 

(e.g., terrain or water bodies). The upper air stations used for this analysis are listed in 

Table A-2 of Appendix A. The locations of the upper air stations with respect to the 

modeling domain are shown in Figure 4-4. These stations were selected from the available 

data inventory to optimize spatial coverage and representation of the domain. Data from 

the stations was processed for use in CALMET using EPA’s READ62 program. Missing 

upper air data was replaced using a persistence method- the assumption that data from the 

preceding or following hours are representative of the missing period. Data from either the 

preceding or following hours were extrapolated to fill the missing hour. 

FIGURE 4-4. PLOT OF UPPER AIR STATIONS LOCATIONS

-800 -600 -400 -200 0 200 400 600 800

LCC Easting (km)

-1600

-1400

-1200

-1000

-800

-600

-400

-200

LCC Northing (km)

Northeastern Station

WIMO

CACR

UPBU

HEGL

Class I Areas

Upper Air Stations

4.2.4 PRECIPITATION METEOROLOGICAL DATA

The effects of chemical transformation and deposition processes on ambient pollutant 

concentrations were considered in this analysis. Therefore, it was necessary to include 

observations of precipitation in the CALMET analysis. The precipitation stations that were 

used for this analysis are listed in Table A-3 of Appendix A. The locations of the 

precipitation stations with respect to the modeling domain are shown in Figure 4-5. These 
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stations were selected from the available data inventory to optimize spatial coverage and 

representation of the domain. Data from the stations was processed for use in CALMET 

using EPA’s PMERGE program. 

FIGURE 4-5. PLOT OF PRECIPITATION METEOROLOGICAL STATIONS

-800 -600 -400 -200 0 200 400 600 800

LCC Easting (km)

-1600

-1400

-1200

-1000

-800

-600

-400

-200

LCC Northing (km)

Northeastern Station

WIMO

CACR

UPBU

HEGL

Class I Areas

Precipitation Stations

4.2.5 BUOY METEOROLOGICAL DATA

The effects of land/sea breeze on ambient pollutant concentrations were considered in this 

analysis. Therefore, it is necessary to include observations of buoy stations in the 

CALMET analysis. The buoy stations that were used for this analysis are listed in Table 

A-4 of Appendix A. The locations of the buoy stations with respect to the modeling 

domain are shown in Figure 4-6. These stations were selected from the available data 

inventory to optimize spatial coverage and representation of the domain along the 

coastline. Data from the stations was prepared by filling missing hour records with the 

CALMET missing parameter value (9999). No adjustments to the data occurred. 
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FIGURE 4-6. PLOT OF BUOY METEOROLOGICAL STATIONS

-800 -600 -400 -200 0 200 400 600 800

LCC Easting (km)

-1600

-1400

-1200

-1000

-800

-600

-400

-200

LCC Northing (km)

Northeastern Station

WIMO

CACR

UPBU

HEGL

Class I Areas

Buoy Stations

4.3 CALMET CONTROL PARAMETERS

Appendix B provides a sample CALMET input file used in AEP’s modeling analysis. A few details 

of the CALMET model setup for sensitive parameters are also discussed below. 

4.3.1 VERTICAL METEOROLOGICAL PROFILE

The height of the top vertical layer was set to 3,500 meters. This height corresponds to the 

top sounding pressure level for which upper air observation data was relied upon. The 

vertical dimension of the domain were divided into 12 layers with the maximum elevations 

for each layer shown in Table 4-1. The vertical dimensions are weighted towards the 

surface to resolve the mixing layer while using a somewhat coarser resolution for the 

layers aloft. 
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TABLE 4-1. VERTICAL LAYERS OF THE CALMET METEOROLOGICAL DOMAIN

Layer Elevation (m)

1 20 

2 40 

3 60 

4 80 

5 100 

6 150 

7 200 

8 250 

9 500 

10 1000 

11 2000 

12 3500 

CALMET allows for a bias value to be applied to each of the vertical layers. The bias 

settings for each vertical layer determine the relative weight given to the vertically 

extrapolated surface and upper air wind and temperature observations. The initial guess 

fields are computed with an inverse distance weighting (1/r2

) of the surface and upper air 

data. The initial guess fields may be modified by a layer dependent bias factor. Values for 

the bias factor may range from -1 to +1. A bias of -1 eliminates upper-air observations in 

the 1/r2

 interpolations used to initialize the vertical wind fields. Conversely, a bias of +1 

eliminates the surface observations in the interpolations for this layer. Normally, bias is set 

to zero (0) for each vertical layer, such that the upper air and surface observations are given 

equal weight in the 1/r2

 interpolations. The biases for each layer of the proposed modeling 

domain was set to zero. 

CALMET allows for vertical extrapolation of surface wind observations to layers aloft to 

be skipped if the surface station is close to the upper air station. Alternatively, CALMET 

allows data from all surface stations to be extrapolated. The CALMET parameter that 

controls this setting is IEXTRP. Setting IEXTRP to a value less than zero (0) means that 

layer 1 data from upper air soundings is ignored in any vertical extrapolations. IEXTRP 

was set to -4 for this analysis (i.e., the similarity theory is used to extrapolate the surface 

winds into the layers aloft, which provides more information on observed local effects to 

the upper layers). 

4.3.2 INFLUENCES OF OBSERVATIONS

Step 1 wind fields were based on an initial guess using MM5 data and refined to reflect 

terrain affects. Step 2 wind fields adjusted the Step 1 wind field by incorporating the 

influence of local observations. An inverse distance method is used to determine the 

influence of observations to the Step 1 wind field. RMAX1 and RMAX2 define the radius 

of influence for data from surface stations to land in the surface layer and data from upper 

air stations to land in the layers aloft. In general, RMAX1 and RMAX2 are used to 

exclude observations from being inappropriately included in the development of the Step 2 
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wind field if the distance from an observation station to a grid point exceeds the maximum 

radius of influence. 

If the distance from an observation station to a grid point was less than the value set for 

RMAX, the observation data was used in the development of the Step 2 wind field. R1 

represents the distance from a surface observation station at which the surface observation 

and the Step 1 wind field are weighted equally. R2 represents the comparable distance for 

winds aloft. R1 and R2 were used to weight the observation data with respect to the MM5 

data that was used to generate the Step 1 wind field. Large values for R1 and R2 give 

more weight to the observations, where as small values give more weight to the MM5 data. 

In this BART modeling analysis, RMAX 1 was set to 20 km, and R1 was set to 10 km. 

This limited the influence of the surface observation data from all surface stations to 20 km 

from each station, and equally weighed the MM5 and observation data at 10 km. RMAX2 

was set to 50 km, and R2 was set to 25 km. This limited the influence of the upper air 

observation data from all surface stations to 50 km from each station, and equally weighed 

the MM5 and observation data at 25 km. These settings of radius of influence allowed for 

adequate weighting of the MM5 data and the observation data across the modeling domain 

due to the vast domain to be modeled. RAMX 3 was set to 500 km. 
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5. CALPUFF

The CALPUFF model uses the output file from CALMET together with source, receptor, and 

chemical reaction information to predict hourly concentration impacts. A three-year CALPUFF 

analysis was conducted using data and model settings as described below. 

5.1 SOURCE EMISSIONS

Baseline (pre-BART) emission data is based upon CEMS data collected by AEP over the 2002-2005 

time frame. In accordance with CENRAP guidelines, the emission rate over the highest calendar day 

(24-hr average) was used to establish baseline emissions. 

Emission estimates for various control scenarios were developed based on AEP’s experience. The 

effectiveness of a number of different control technologies for NOX, and SO2 were examined. 

Emission estimates for these various scenarios are included in Appendix E. 4 The cost effectiveness 

has been evaluated on a facility-wide basis (as opposed to a unit-by-unit basis) because of the 

common stack shared by NE Units 3 & 4, with the intent to apply any applicable final selected control 

technology on each of the affected units at the facility. 

5.2 RECEPTOR LOCATIONS

The National Park Service (NPS) has electronic files available on their website that include the 

discrete locations and elevations of receptors to be evaluated in Class I area analyses. These receptor 

sets were used in the CALPUFF model. 

5.3 BACKGROUND OZONE AND AMMONIA

Background ozone concentrations are required in order to model the photochemical conversion of 

SO2 and NOX to sulfates (SO4) and nitrates (NO3). CALPUFF can use either a single background 

value representative of an area or hourly ozone data from one or more ozone monitoring stations. 

Hourly ozone data files were used in the CALPUFF simulation. As provided by the Oklahoma DEQ, 

hourly ozone data from the Oklahoma City, Glenpool, and Lawton monitors over the 2001-2003 time 

frame were used. Background concentrations for ammonia were assumed to be temporally and 

spatially invariant and were set to 3 ppb, as described in the CENRAP protocol. 

5.4 CALPUFF MODEL CONTROL PARAMETERS

Appendix C provides a sample CALPUFF input file that was used for the AEP refined modeling 

analyses. Please note that puff splitting is a generally accepted option in refined modeling analyses 

over large model domains for assessing impacts on Class I areas; however, this option would require 

significant computer resources and longer runtime. Based upon previous model runs performed on 

 4

 CENRAP BART Modeling Guidelines, Appendix B, 15 December 2005. 
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domains (and restricted computational grids) of the size described in this report, it is expected that 

runtimes could increase by a factor of 4 to 5 with the inclusion of puff-splitting. Due to this, the use 

of this option was evaluated during the modeling analysis and it was felt that it was not necessary to 

obtain representative concentrations at the individual Class I areas. 
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6. CALPOST 

A three-year CALPOST analysis was conducted to determine the visibility change in deciview (dv) 

caused by AEP’s BART-eligible sources when compared to a natural background. 

6.1 CALPOST – LIGHT EXTINCTION ALGORITHM 

The algorithm was used to calculate the daily light extinction attributable to AEP’s BART-eligible 

sources and light extinction attributable to a natural background. The change in deciviews based on 

the source and background light extinctions was evaluated using the equation below. 

∆ dv = 10*ln

b b

b

ext, background ext, source

ext, background

 +















EPA’s currently approved algorithm for assessing light extinction and the updated light extinction 

calculation algorithms developed by the Interagency Monitoring of Protected Visual Environments 

(IMPROVE) workgroup were used to assess visibility impacts from the NE Station. 

The background extinction coefficient bext, background is affected by various chemical species and the 

Rayleigh scattering phenomenon. The original equation for the background extinction coefficient in 

the FLM’s FLAG guidance is as follows: 

( ) bext background Mm = bSO + bNO + bOC + bSoil + bCoarse + bap + bRay

−

4 3

1

, 

where, 

[ ] ( ) ( )

[ ] ( )

[ ]

[ ]

[ ]

[ ]

( )

( )

[ ] 3

1

3 4 3

4 2 4 4

Concentration in μg m

Relative Humidity Function

Rayleigh Scattering 10 Mm by default

10 EC

0.6 Coarse Mass

1Soil

4 OC

3 NH NO

3 NH SO

=

=

=

=

=

=

=

=

=

−

f RH

b

b

b

b

b

b f RH

b f RH

Ray

ap

Coarse

Soil

OC

NO

SO [( ) ]

[ ]

[ ]

[ ]

[ ]

[ ]

Rayleigh Scattering isscattering due to air molecules

EC denotes the concentration of elemental carbon

Coarse Mass denotes the concentration of coarse dusts

Soil denotes the concentration of fine soils

OC denotes the concentration of organic carbon

NH NO denotes the ammonium nitrate concentration

NH SO denotes the ammoniumsulfate concentration

4 3

4 2 4
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6.2 CALPOST PROCESSING METHOD

CALPOST Method 6, which calculates hourly light extinction impacts for the source and background 

using monthly average relative humidity adjustment factors was used in the refined BART analysis. 

Monthly Class I area-specific relative humidity adjustment factors based on the centroid of the Class I 

areas as included in Table A-3 of EPA’s Guidance for Estimating Natural Visibility Conditions 

Under the Regional Haze Program were used. The factors for the Class I areas listed that were 

evaluated in the analysis are provided in Table 6-1. 

TABLE 6-1. MONTHLY HUMIDITY FACTORS

Class I Area Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Caney Creek 3.4 3.1 2.9 3.0 3.6 3.6 3.4 3.4 3.6 3.5 3.4 3.5 

Hercules-Glades 3.2 2.9 2.7 2.7 3.3 3.3 3.3 3.3 3.4 3.1 3.1 3.3 

Upper Buffalo 3.3 3.0 2.7 2.8 3.4 3.4 3.4 3.4 3.6 3.3 3.2 3.3 

Wichita Mountains 2.7 2.6 2.4 2.4 3.0 2.7 2.3 2.5 2.9 2.6 2.7 2.8 

6.3 NATURAL BACKGROUND

EPA’s default average annual aerosol concentrations for the U.S. that are included in Table 2-1 of 

EPA’s Guidance for Estimating Natural Visibility Conditions Under the Regional Haze Program

were used. The annual average concentrations are provided in Table 6-2 

TABLE 6-2. DEFAULT AVERAGE ANNUAL NATURAL BACKGROUND LEVELS

Class I Area Region SO4 NO3 OC EC Soil Coarse Mass

Caney Creek WEST 0.12 0.10 0.47 0.02 0.50 3.00

Hercules-Glades EAST 0.23 0.10 1.40 0.02 0.50 3.00

Upper Buffalo EAST 0.23 0.10 1.40 0.02 0.50 3.00

Wichita Mountains WEST 0.12 0.10 0.47 0.02 0.50 3.00 

6.4 EVALUATING VISIBILITY RESULTS

When evaluating cost-control effectiveness of the various control scenarios, the 98th percentile of the 

2001-2003 daily ∆dv values output by CALPOST was examined. Peak 24-hr impact values have 

been included for reference. 

6.5 SUMMARY OF CALPOST CONTROL PARAMETERS

Appendix E provides a sample CALPOST input file that was used for the modeling analysis. 

Variable values that differ from the CENRAP protocol are generally the result of data input/output 

handling issues (e.g., types of output, receptor numbers, etc.). 
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7. BART-ELIGIBLE EMISSION UNITS

The BART Guidelines define the following three steps for determining which emission units at a 

facility are BART-eligible: 

1. Identify the emission units in the BART source categories, 

2. Identify the start-up dates of those units, and 

3. Compare potential emissions to the 250 ton/yr cutoff. 

Electric Generating Units (EGU) are listed source categories under BART. AEP has determined that 

the NE coal-fired Units 3 and 4 are BART-eligible sources at the NE Generating Station because the 

units, were in existence on August 7, 1977 and began operation after August 7, 1962. Units 3 and 4 

both have the potential to emit NOX, SO2, and PM10 emissions greater than 250 tpy. A CALPUFF 

dispersion model was run to determine the visibility impact associated with emissions from these 

units. A summary of the parameters used in the BART modeling eligibility criteria for each emission 

unit is provided in Table 7-1. 

TABLE 7-1. SUMMARY OF BART-ELIGIBLE EMISSION UNITS

Emission 

Unit 

BART 

Source 

Category 

Year of 

Completion of 

Construction or 

Reconstruction 

Maximum 

(24-hr average) 

SO2 Emissions 

(lb/hr) 

Maximum 

(24-hr average) 

NOX Emissions 

(lb/hr) 

Maximum 

(24-hr average) 

PM/PM10 Emissions

(lb/hr) 

Unit 3 Boiler a 1974 6,126.3 3,115.5 220.3 

Unit 4 Boiler a 1974 5,929.6 2,746.6 330.6 

a

 Fossil-fuel boilers of more than 250 million BTUs per hour heat input. 

7.1 DESCRIPTION OF BART-ELIGIBLE SOURCES

NE Units 3 and 4 are tangentially-fired steam generating boilers burning western sub-bituminous 

coal, with natural gas or Number 2 fuel oil, used as secondary fuels for flame stabilization at low 

loads. Emissions from both units discharge through a common stack 600 feet in height and 27 feet in 

diameter. Particulate matter emissions are controlled by electrostatic precipitators (ESP) with 99.7% 

and 99.5% efficiencies for Units 3 and 4 respectively. Unit 3 has the capability of burning 266 tons 

per hour (tph) or 2,330,000 tons per year (tpy) of coal while unit 4 has the capability of burning 279 

tph or 2,450,000 tpy of coal. 

The boilers are subject to NSPS Subpart D which requires the following: 

(a) PM emissions shall not exceed 0.10 lb/MMBtu. 

(b) Opacity shall not exceed 20%, except for one six-minute period per hour of not more than 

27%. 

The boilers are currently meeting these standards with the electrostatic precipitator 
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7.2 MODELED STACK PARAMETERS

Actual stack parameters were input to the CALPUFF model to represent each emissions point. The 

location of each point was represented using the Lambert Conformal Coordinate (LCC) system. 

Table 7-2 summarizes the stack parameters modeled for the BART-eligible emission units at AEP’s 

NE Station. 

TABLE 7-2. STACK PARAMETERS

Emission Unit 

LCC East 

(km) 

LCC North

(km) 

Base 

Elevation

(m) 

Stack 

Height 

(m) 

Stack 

Diameter 

(m) 

Exhaust 

Temperature

(K) 

Exhaust 

Velocity

(m/s) 

Northeastern Unit 3 115.656 -394.267 195 183 8.23 424 18.97 

Northeastern Unit 4 115.656 -394.267 195 183 8.23 415 17.46 

As described further in this report, various retrofit control technologies were evaluated for these two 

units. Many of these technologies have the potential to alter source parameters from their existing 

profile. A summary of source parameters associated with each control technology are included in 

Appendix E. 
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8. BART DETERMINATION ANALYSIS FOR NOX

In general, BART is determined for each eligible emissions unit using the following five (5) steps 

from Section IV.D of the BART Guidelines: 

Step 1 – Identify all available retrofit control technologies, 

 Step 2 – Eliminate technically infeasible options, 

 Step 3 – Evaluate control effectiveness of remaining control technologies, 

 Step 4 – Evaluate impacts and document the results, and 

 Step 5 – Evaluate visibility impacts. 

The BART determinations for each visibility impairing pollutant are presented separately in the 

following sections in a step by step approach. 

Each required step of the BART determination analysis for emissions of NOX from Unit 3 and Unit 4 

is presented below. Whichever control is selected in the following BART determination will be 

applied to both units at the station. 

8.1 STEP 1 - IDENTIFY ALL AVAILABLE RETROFIT CONTROL TECHNOLOGIES

The BART Guidelines require the consideration of all “control technologies with a practical potential 

for application to the emissions unit and the regulated pollutant under evaluation.” The list of 

available control options should include “the most stringent option and a reasonable set of options for 

analysis...[, but] it is not necessary to list all permutations of available control levels that exist for a 

given technology – the list is complete if it includes the maximum level of control each technology is 

capable of achieving.” 

Per the BART Guidelines, the BART determination analysis must “take into account technology 

transfer of controls that have been applied to similar source categories and gas streams [in addition to] 

existing controls for the source category in question.” However, “technologies which have not yet 

been applied to (or permitted for) full scale operations need not be considered as available; [the U.S. 

EPA does] not expect the source owner to purchase or construct a process or control device that has 

not already been demonstrated in practice.” The BART Guidelines provides the following additional 

considerations for preparing the list of potential control options: 

S One of the control options should reflect the level of control equivalent to any applicable 

NSPS, 

S Source redesign should not be considered, 

S Fuel switching should not be considered, and 

S For emission units with existing control measures or devices, one of the control options 

should involve improvements to the existing controls. 
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Potential NOX control technologies and resulting emission control quantities for the NE Station’s Unit 

3 and Unit 4 were identified from a combination of control equipment vendor information, publiclyavailable air permits and applications, and technical literature published by the U.S. EPA, and the 

Regional Planning Organizations (RPOs). Each NOX control option identified as potentially 

applicable to either unit is listed below and explained in detail in the following subsections. 

S Selective Non-Catalytic Reduction (SNCR) 

S Low NOX Burners (LNB) and Over-fire Air (OFA) 

S Selective Catalytic Reduction (SCR) 

S Reburning / Methane de-NOX (MdN) 

S Flue Gas Recirculation (FGR) (Internal and External) 

Combustion-related NOX emissions are formed by two mechanisms. NOX formed from oxidation of 

molecular nitrogen (N2) in combustion air is referred to as “thermal NOX” and is dependent on high 

temperatures (approximately 2,800 °F) and an excess of combustion air. NOX formed by oxidation of 

nitrogen compounds in fuel is referred to as “fuel NOX.” The NOX formed from coal combustion is 

primarily fuel NOX.

5

 

The possible NOX emissions control technologies generally fit into one of two categories: combustion 

modifications, which are often associated with improving boiler performance, or flue gas treatment 

(i.e., post-combustion controls). Pre-combustion techniques to reduce fuel NOX have shown little 

promise.6

 Combustion modifications are the most common, commercially available means of 

controlling NOX emissions from fossil fuel-fired boilers.7

 

8.1.1 COMBUSTION MODIFICATIONS

8.1.1.1 FLUE GAS RECIRCULATION

Generally, FGR involves extracting a portion (15 to 30 percent) of the flue gas and 

readmitting it to the furnace through the burner window. When the flue gas is 

extracted from the economizer or air heater outlet, a separate fan/blower is needed 

to withdraw the flue gas. This setup is referred to as external or forced FGR. 

Internal or induced FGR refers to the setup where the flue gas is extracted from 

upstream of the stack using the forced draft (FD) fan instead of a separate FGR 

fan. In either setup, the recirculated flue gas acts as a thermal diluent (i.e., heat 

sink) to reduce combustion temperatures. It also dilutes the combustion reactants 

and reduces the excess air requirements thereby reducing the concentration of 

oxygen in the combustion zone. Thus, thermal NOX formation is inhibited.8

 The 

onset of thermal NOX occurs around 2,800 °F, and NOX generation increases 

exponentially with temperatures beyond 2,800 °F. As only thermal NOX can be 

 5

 MACTEC, Midwest RPO Boiler BART Engineering Analysis, March 30, 2005. 6

 NCASI, NOX Control in Forest Products Industry Boilers: A Review of Technologies, Costs and Industry 

Experience, Special Report 03-04. 

7

 Ibid. 

8

 U.S. EPA, Clean Air Technology Center, Nitrogen Oxides (NOX), Why and How They Are Controlled. Research 

Triangle Park, North Carolina, EPA-456/F-99-006R, November 1999. 
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controlled by this technique, it is especially effective only in oil and gas-fired 

units.9

8.1.1.2 LOW NOX BURNERS AND OVERFIRE AIR

LNB technology utilizes advanced burner design to reduce NOX formation 

through the restriction of oxygen, flame temperature, and/or residence time. A 

LNB is a staged combustion process that is designed to split fuel combustion into 

two zones, primary combustion and secondary combustion. Two general types of 

LNB exist: staged fuel and staged air. Lower emission rates can be achieved with 

a staged fuel burner than with a staged air burner. Staged fuel LNB separate the 

combustion zone into two regions. The first region is a lean primary combustion 

region where the total quantity of combustion air is supplied with a fraction of the 

fuel. Combustion in the primary region (first stage) takes place in the presence of 

a large excess of oxygen at substantially lower temperatures than a standard 

burner. In the second region, the remaining fuel is injected and combusted with 

any oxygen left over from the primary region. The remaining fuel is introduced in 

the second stage outside of the primary combustion zone so that the fuel/oxygen 

are mixed diffusively (rather than turbulently), which maximizes the reducing 

conditions. This technique inhibits the formation of thermal NOX, but has little 

effect on fuel NOX. By increasing residence times staged air LNB provide 

reducing conditions, which have a greater impact on fuel NOX than staged fuel 

burners. The estimated NOX control efficiency for LNB in high temperature 

applications is 25 percent.10 Combustion modification with LNB is used in both 

gas/oil-fired and coal-fired units.11 

In OFA, about 10 to 20 percent of the combustion air flow is directed to separate 

air ports located downstream of the burners. OFA works by reducing the excess 

air in the burner zone, thereby enhancing the combustion staging effect and 

theoretically reducing NOX emissions. Residual unburned material, such as CO 

and unburned carbon, which inevitably escapes the main burner zone, is oxidized 

as the OFA is admixed later.12

LNB with OFA as a combined control technology can reduce emissions from each 

boiler across the full load. Based on this, LNB with OFA will continue to be 

reviewed as a viable BART control technology. 

8.1.1.3 REBURNING / METHANE DE-NOX

In reburning, also known as “off-stoichiometric combustion” or “fuel staging,” a 

fraction (5 to 25 percent) of the total fuel heat input is diverted to a second 

 9

 NCASI, NOX Control in Forest Products Industry Boilers: A Review of Technologies, Costs and Industry 

Experience, Special Report 03-04. 

10 MACTEC, Midwest RPO Boiler BART Engineering Analysis, March 30, 2005. 11 NCASI, NOX Control in Forest Products Industry Boilers: A Review of Technologies, Costs and Industry 

Experience, Special Report 03-04. 

12 Ibid. 
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combustion zone downstream of the primary zone. The fuel in the fuel-rich 

secondary zone acts as a reducing agent, reducing NO, which is formed in the 

primary zone, to N2. Low nitrogen-containing fuels such as natural gas and 

distillate oil are typically used for reburning to minimize further NOX formation. 

Generally, it is more economical for a facility to use the same fuel for reburning as 

it does for primary combustion, although there are exceptions. In order to use coal 

as a reburning fuel, it must be finely ground, which requires additional pulverizing 

equipment.13

Methande de- NOX (MdN) utilizes the injection of natural gas together with 

recirculated flue gases (for enhanced mixing) to create an oxygen-rich zone above 

the combustion grate. OFA is then injected at a higher furnace elevation to burn 

out the combustibles. This process is claimed to yield between 50 and 70 percent 

NOX reduction and to be suitable for all solid fuel-fired stoker boilers. However, 

as of 2002, MdN had only been demonstrated for a short duration in one pulp mill 

wood-fired stoker boiler that also burned small amounts of waste treatment plant 

residuals, with NOX reductions of 40 to 50 percent reported.14

8.1.2 POST-COMBUSTION CONTROLS

8.1.2.1 SELECTIVE NON-CATALYTIC REDUCTION

SNCR is a post-combustion NOX control technology based on the reaction of urea 

or ammonia (NH3) and NOX. In the SNCR chemical reaction, urea or ammoniabased chemicals are injected into the combustion gas path to reduce the NOX to 

nitrogen and water. The primary SNCR reaction sequences are shown in Figure 

8-1.15

 13 STAPPA and ALAPCO, Controlling Fine Particulate Matter Under the Clean Air Act: A Menu of Options, 

March 2006. 14 NCASI, NOX Control in Forest Products Industry Boilers: A Review of Technologies, Costs and Industry 

Experience, Special Report 03-04. 

15 ABB Power Plant Laboratories, Engineering development of coal-fired high performance power systems – 

Phase II topical report, Selective Non-Catalytic Reduction System Development Subcontract to United Technologies 

Research Center, Contract No. DE-AC22-95PC95144, February 24, 1997 (reprinted in NCASI’s Special Report No. 03-04). 
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FIGURE 8-1. PRIMARY SNCR REACTION SEQUENCES 

For industrial coal-fired boilers, SNCR can achieve approximately 40 percent 

NOX control.16 In utility applications and based on AEP’s prior experience it is 

estimated that 25 to 30% reductions could be realized for NE Station units 3 & 4.. 

An important consideration for implementing SNCR is the operating temperature 

range. The optimum temperature range is approximately 1,600 to 2,000 °F.17 

Operation at temperatures below this range results in ammonia slip. Operation 

above this range results in oxidation of ammonia, forming additional NOX. In 

addition, the urea must have sufficient residence time, about 3 to 5 seconds, at the 

optimum operating temperatures for efficient NOX reduction. Therefore, the 

injection point is typically prior to convective heat recovery.18 

According to the U.S. EPA, the performance of an SNCR system is affected by six 

factors. 

These are a) inlet NOX level, b) temperature, c) mixing, d) residence time, e) 

reagent-to- NOX ratio, and f) fuel sulfur content. Lower inlet NOX

concentrations reduce the reaction kinetics and hence the achievable NOX

emissions reductions. As mentioned above, temperatures below the desired 

window result in ammonia emissions (slip), and temperatures above the 

desired window result in NH3 being oxidized to NOX. Mixing becomes an 

important consideration in regions distant from an injection nozzle where the 

level of turbulence is reduced and stratification of the reagent and flue gas 

will probably be a greater problem, especially at low boiler loads. 

Residence time becomes important to allow the desired reactions to go to 

 16 MRPO, Interim White Paper – Midwest RPO Candidate Control Measures, March 29, 2005. 17 U.S. EPA, Clean Air Technology Center, Nitrogen Oxides (NOX), Why and How They Are Controlled. 

Research Triangle Park, North Carolina, EPA-456/F-99-006R, November 1999. 18 U.S. EPA. Summary of NOX Control Technologies and their Availability and Extent of Application. Research 

Triangle Park, North Carolina. EPA-450/3-92-004, February 1992. 
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completion. Small, packaged, water tube boilers and boilers with varying 

steam loads are therefore difficult applications for SNCR. As higher than the 

theoretical NH3 to NOX ratios are generally required to achieve desired NOX

emission reductions, a trade-off exists between NOX control and the presence 

of NH3 in the flue gas. The main disadvantage of SNCR is the low NOX

reduction that is experienced when the allowable ammonia slip is low. 

Finally, in the case of high sulfur fuels, excess NH3 can react with sulfur 

trioxide to form ammonium sulfate salt compounds that deposit on 

downstream equipment leading to plugging and reduced heat transfer 

efficiencies.19

One concern about the SNCR process is its ability to perform adequately under 

changing load and fuel conditions.20 Based on its research regarding this concern, 

NCASI concludes that SNCR is most widely used for base-loaded boilers, and is 

not suited for power boilers that experience wide temperature variances, i.e., high 

load swings. NCASI also points out that the use of SNCR systems on coal-fired 

boilers is still in the development stage.21

The NOXOUT process is an SNCR hybrid based on the following chemical 

reaction that ideally occurs in the temperature range of 1700 to 2000 °F: 

2 NO + NH2CONH2 + 1/2 O2 → 2 N2 + CO2 + 2 H2O 

The problems with typical SNCR systems (e.g., ammonia slippage and heat 

transfer surface fouling with byproduct formation) also exist with the NOXOUT 

process. 

8.1.2.2 SELECTIVE CATALYTIC REDUCTION

SCR is a post-combustion gas treatment process in which NH3 is injected into the 

exhaust gas in the presence of a catalyst bed usually located between the boiler 

and air preheater. The catalyst lowers the activation energy required for NOX

decomposition.22 On the catalyst surface, NH3 and nitric oxide (NO) react to form 

diatomic nitrogen and water. The overall chemical reaction can be expressed as: 

4NO + 4NH3 + O2 → 4N2 + 6H2O 

When operated within the optimum temperature range of approximately 575 to 

750 °F, the reaction can result in removal efficiencies between 70 and 90 percent. 

For coal-fired industrial boilers, SCR can achieve approximately 80 percent NOX

 19 U.S. EPA, New source performance standards, subpart Db – technical support for proposed revisions to NOX, 

EPA-453-/R-95-012 (republished in NCASI’s Special Report 03-04). 20 NCASI, NOX Control in Forest Products Industry Boilers: A Review of Technologies, Costs and Industry 

Experience, Special Report 03-04. 

21 Ibid. 

22 MACTEC, Midwest RPO Boiler BART Engineering Analysis, March 30, 2005. 
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control.23 The specific temperature ranges are 600 to 750 °F for conventional 

(vanadium or titanium) catalysts, 470 to 510 °F for platinum catalysts, and 600 to 

1000 °F for high-temperature zeolite catalysts.24 SCR units have the ability to 

function effectively under fluctuating temperature conditions (usually ± 50 °F), 

although fluctuation in exhaust gas temperature reduces removal efficiency by 

disturbing the chemical kinetics (speed) of the NOX -removal reaction. 

According to the U.S. EPA, the performance of an SCR system is affected by six 

factors. 

These are a) NOX level at SCR inlet, b) flue gas temperature, c) NH3-to-NOx 

ratio, d) fuel sulfur content, e) gas flow rate, and f) catalyst condition. For 

SCR, when inlet NOX concentrations fall below 150 ppm, the reduction 

efficiencies decrease with decreasing NOX concentrations. Each type of 

catalyst has an optimum operating temperature range. Temperatures below 

this range result in ammonia emissions (slip), and temperatures above the 

desired range result in NH3 being oxidized to NOX. For up to about 80 

percent NOX reduction efficiencies, a 1:1 NH3:NOX ratio is sufficient. For 

higher efficiencies, higher reagent to NOX ratios are required which may 

result in higher NH3 slip. In the case of high sulfur fuels, excess NH3 can 

react with sulfur trioxide to form ammonium sulfate salt compounds that 

deposit and foul downstream equipment. SCR application experience in the 

case of medium-to-high sulfur fuels is limited. For a given flue gas flow rate, 

the catalyst structural design should be chosen so that the residence time 

needed for the reduction reactions to take place on the catalyst surface is 

achievable.25

8.2 STEP 2 – ELIMINATE TECHNICALLY INFEASIBLE OPTIONS

Step 1 of the BART determination is the identification of all available retrofit NOX control 

technologies. A list of control technologies was obtained by reviewing the U.S. EPA’s Clean Air 

Technology Center, control equipment vendor information, publicly-available air permits, 

applications, and BART analyses, and technical literature published by the U.S. EPA and the RPOs. 

The available retrofit NOX control technologies are summarized in Table 8-1. 

 23 MRPO, Interim White Paper – Midwest RPO Candidate Control Measures, March 29, 2005. 24 MACTEC, Midwest RPO Boiler BART Engineering Analysis, March 30, 2005. 25 U.S. EPA, New source performance standards, subpart Db – technical support for proposed revisions to NOX, 

EPA-453-/R-95-012 (republished in NCASI’s Special Report 03-04). 
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TABLE 8-1. AVAILABLE NOX CONTROL TECHNOLOGIES 

NOX Control Technologies 

Flue Gas Recirculation (FGR) 

Combustion Controls Low NOX Burners (LNB) Overfire Air (OFA) 

Reburning Methane, De- NOX (MdN) 

Selective Catalytic Reduction (SCR) Post-Combustion Controls 

Selective Non-Catalytic Reduction (SNCR) 

8.2.1 FLUE GAS RECIRCULATION

FGR is used to reduce thermal NOX formation. Emissions due to fuel-bound NOX, which are 

significant for coal-fired boilers, are not meaningfully affected by FGR. Therefore, FGR is 

not technically feasible to control NOX emissions from coal-fired boilers.26 

8.2.2 REBURNING / METHANE DE-NOX

MdN is not considered feasible because (1) it is not fully demonstrated and (2) it incorporates 

FGR, which is clearly technically infeasible (see Section 8.2.1). 

The remaining control technologies LNB/OFA, SCR, SNCR, are considered technically feasible as 

retrofit technologies at the Northeastern Station. 

8.3 STEP 3 – EVALUATE CONTROL EFFECTIVENESS OF REMAINING CONTROL 

TECHNOLOGIES

Table 8-2. Ranking of Control presents a ranking of the technically feasible control strategies in 

order of their effectiveness (i.e., potential control efficiency). For controls with a range of 

performance levels, the BART Guidelines note: 

It is not [the U.S. EPA’s] intent to require analysis of each possible level of efficiency for a 

control technique as such an analysis would result in a large number of options. It is 

important, however, that in analyzing the technology you take into account the most stringent 

emission control level that the technology is capable of achieving. 

A detailed summary of control scenario emissions is included in Appendix E. 

 26 U.S. EPA. Alternative Control Technologies Document: NOX Emissions from Utility Boilers. (EPA-453/R-94-

023). 
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TABLE 8-2. RANKING OF CONTROL TECHNOLOGIES

Control Strategy Applicability Potential Control Efficiency 

SNCR Unit 3 & Unit 4 25-30% 

LNB & OFA Unit 3 & Unit 4 65-75%

SCR Unit 3 & Unit 4 85-90% 

a

 Based on AEP operating experiences. 

A summary of pre-BART baseline emissions as well as expected emission rates for each of 

the control technologies are summarized in Appendix E. Short-term controlled emission 

rates (lb/hr) were modeled in CALPUFF in order to evaluate visibility impacts. These 

controlled emission rates were calculated using the maximum 24-hr emission rate (in lb/hr) 

observed over the 2002-05 period as a baseline emission rate. This baseline emission rate (as 

described in Section 7.1) was then adjusting downward based upon the level of control 

efficiency expected for each technology. A summary of the lb/MMbtu emission factor that 

corresponds to the controlled emission rate is also included in Appendix E. 

Annual controlled emissions (tpy) were used in compliance cost calculated described further 

below. Baseline (pre-BART) emission estimates were calculated using a baseline lb/MMBtu 

emission factor (as observed over the 2002-05 time frame) and a capacity factor adjusted 

firing rate as described in Permit Memorandum 96-288-TV. Controlled emission estimates 

were calculated using the annual average firing rate and lb/MMBtu emission factor 

corresponding to the appropriate control technology. 

8.4 STEP 4 – EVALUATE IMPACTS AND DOCUMENT RESULTS

Step four for the BART analysis procedure is the impact analysis. The BART determination 

guidelines list five factors to be considered in the impact analysis: 

▲ Cost of compliance 

▲ Energy impacts 

▲ Non-air quality impacts 

▲ The remaining useful life of the source; and 

▲ Visibility impacts 

Each of the first four factors are addressed in Step 4. The fifth factor, visibility impacts, is evaluated 

in Step 5. 

8.4.1 COSTS OF COMPLIANCE

Per the BART Guidelines, the costs of compliance analysis for each control option consists of 

comparisons of the average cost effectiveness and the incremental cost effectiveness, which 

are defined in Section IV.D.4 as follows: 
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Average cost effectiveness means the total annualized costs of control divided by the 

annual emissions reduction (the difference between baseline annual emissions and 

the estimate of emissions after controls), using the following formula: 

Average cost effectiveness (dollars per ton removed) = Control option annualized 

cost ÷ (Baseline annual emissions – Annual emissions with Control option) 

...the incremental cost effectiveness calculation compares the costs of performance 

level of a control option to those of the next most stringent option, as shown in the 

following formula (with respect to cost per emissions reduction): 

Incremental Cost Effectiveness (dollars per incremental ton removed) = (Total 

annualized costs of control option) – (Total annualized costs of next control option) ÷ 

(Control option annual emissions) – (Next control option annual emissions) 

Compliance costs associated with implementing the evaluated control systems were 

developed in-house by AEP, and represent both annual operating costs and annualized capital 

costs associated with retrofit construction. A detailed summary of those costs is included in 

Appendix F. Estimates of annual pollutant reductions for the evaluated control technologies 

are included in Appendix E. 

The average and incremental cost effectiveness for each feasible control option for the NE 

Station’s Unit 3 and Unit 4 are summarized in Table 8-3. 

TABLE 8-3. NOX CONTROL COSTS SUMMARY

 Average Cost 

Effectiveness 

Incremental Cost 

Effectiveness 

Emission Unit Control Strategy $/ton $/ton

Unit 3 & Unit 4 SNCR 2,751 N/A 

 LNB/OFA 149 -1,257 

 SCR 2,472 10,996 

8.4.2 ENERGY IMPACTS & NON-AIR IMPACTS

SCR systems will require additional electricity to prime blowers and pumps and the extra 

fan horsepower needed to overcome the high pressure drop in the systems. These 

electricity needs will deter from the net plant output and represents a sizable energy 

penalty. 

SCR can potentially cause significant environmental impacts related to the usage and 

storage of ammonia. Storage of aqueous ammonia above 10,000 lbs is regulated by a risk 

management program (RMP), since the accidental release of ammonia has the potential to 

cause serious injury and death to persons in the vicinity of the release. Ammonia can also 
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be emitted in the exhaust of boilers that operate with SCR or SNCR for NOX control due to 

ammonia slip. 

Ammonia slip from SCR and SNCR systems occurs either from ammonia injection at 

temperatures too low for effective reaction with NOx, leading to an excess of unreacted 

ammonia, or from over-injection of reagent leading to uneven distribution; which also 

leads to an excess of unreacted ammonia. Ammonia released from SCR and SNCR 

systems will react with sulfates and nitrates in the atmosphere to form ammonium sulfate. 

Together, ammonium sulfate and ammonium nitrate are the predominant sources of 

regional haze. 

8.4.3 REMAINING USEFUL LIFE

The remaining useful life of NE Unit 3 and 4 do not impact the annualized capital costs of 

potential controls because the useful lives of the units are anticipated to be at least as long 

as the capital cost recovery period, which is 20 years. 

8.5 STEP 5 – EVALUATE VISIBILITY IMPACTS

A summary of visibility impacts from each NOX control technology is summarized below. A 

comparison of all the modeled emission rates is provided in Table 8-4 below. 

TABLE 8-4. NE STATION NOX VISIBILITY RESULTS

 Peak Impact 98th Percentile 

Pollutant Class I Area 

Control 

Technology (∆dv) 

% Reduction 

from 

previous 

% Reduction 

from 

Baseline (∆dv) 

% Reduction 

from 

previous 

% Reduction 

from 

Baseline 

NOX Caney Creek Baseline 2.34 -- -- 0.94 -- -- 

 SNCR 1.81 23% 23% 0.72 24% 24% 

 LNB/OFA 0.74 59% 68% 0.27 62% 71% 

 SCR 0.26 65% 89% 0.09 66% 90% 

 Herc-Glades Baseline 1.67 -- -- 0.48 -- -- 

 SNCR 1.27 24% 24% 0.36 25% 25% 

 LNB/OFA 0.51 60% 70% 0.14 61% 70% 

 SCR 0.18 65% 89% 0.05 67% 90% 

 Upper Buffalo Baseline 2.27 -- -- 0.53 -- -- 

 SNCR 1.75 23% 23% 0.40 25% 25% 

 LNB/OFA 0.72 59% 68% 0.15 62% 72% 

 SCR 0.25 65% 89% 0.05 66% 90% 

 Wichita Mts Baseline 2.36 -- -- 0.59 -- -- 

 SNCR 1.81 23% 23% 0.45 25% 25% 

 LNB/OFA 0.73 60% 69% 0.18 61% 70% 

 SCR 0.25 66% 89% 0.06 66% 90% 
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8.6 BART DETERMINATION FOR NOX

In the BART guidelines, EPA calculated that for all types of boilers other than cyclone boilers, 

combustion control technology (represented by LNB w/ OFA) is generally more cost-effective than 

post-combustion controls (represented by SNCR and SCR). EPA estimates that approximately 75 

percent of the BART units (non-cyclone) could meet the presumptive NOX limits at a cost of $100 to 

$1,000 per ton of NOX removed based on the use of combustion control technology. For the units 

that could not meet the presumptive limits using combustion control technology, EPA estimates that 

almost all of these sources could meet the presumptive limits using advanced combustion controls; 

the EPA estimates that the cost of such controls are usually less than $1,500 per ton removed. 

Table 8-3 indicates the cost effectiveness of a combustion controls system (represented by LNB with 

OFA), SCR and SNCR for the Northeastern Units. Of these systems, SNCR results in a smaller 

improvement in visibility than LNB w/OFA. While SCR results in a larger improvement in visibility 

than LNB w/OFA, the incremental cost of the SCR over the combustion control system is greater than 

nearly $10,000 per ton of NOX removed for the Northeastern Units. 
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9. BART DETERMINATION ANALYSIS FOR SO2

9.1 STEP 1 - IDENTIFY ALL AVAILABLE RETROFIT CONTROL TECHNOLOGIES

SO2 emissions are a function of the sulfur content in the fuel combusted. Thus, the type of coal being 

combusted is important in defining comparable controls/limits. 

H2SO4 is also a function of the fuel sulfur content. It is formed when the fuel sulfur is oxidized 

beyond SO2 to sulfur trioxide (SO3), which, for practical purposes, immediately becomes H2SO4 in 

the presence of water vapor. Units with SCR may experience some additional H2SO4 generation 

because the SCR catalyst will oxidize some additional portion of SO2 to SO3. 

9.1.1 DRY FLUE GAS DESULFURIZATION (DFGD) 

In a DFGD system (which uses a spray dryer absorber [SDA]), an alkaline reagent (usually 

lime), in the form of a slurry, is atomized into the flue gas stream, where it reacts with and 

collects the SO2.

27 As with wet scrubbing, DFGD, when followed by a particulate control 

device, also removes significant amounts of H2SO4 mist emissions. DFGD does not require 

the installation of a wastewater treatment plant since the water in the slurry is evaporated by 

the heat of the flue gas and the reagent exits the system in the form of a powder. 

The amount of SO2 and H2SO4 removed with DFGD varies with two primary parameters: 

size of the reagent particles and the residence time for the scrubbing to occur. As the unit 

surface area increases (i.e., the particle size decreases), the pollutant and the reagent have 

greater contact resulting in a higher SO2 and H2SO4 removal rates. The residence time of the 

pollutant and reagent mixture also dictates the amount of SO2 and H2SO4 mist removed. A 

particulate matter control is then used to remove the reacted dust (i.e., CaSO4) from the flue 

gas stream. 

9.1.2 WET FLUE GAS DESULFURIZATION (WFGD) 

WFGD, also known as wet scrubbing, is sometimes used to control SO2 emissions from 

combustion sources. In a WFGD system, the combustion exhaust gas is typically contacted 

with an aqueous alkaline liquid inside a spray tower. SO2 reacts with the suspended alkaline 

reagent and is removed from the exhaust gas stream. 

The use of water in the process necessitates a water treatment system prior to discharge. 

WFGD systems incur high capital, operation, and maintenance costs. Therefore, WFGD 

systems are typically only used on units combusting high-sulfur fuels where the small 

incremental increase in SO2 removal (over DFGD) justifies the additional costs. 

 27 U.S. EPA. Air Pollution Control Technology Fact Sheet: Flue Gas Desulfurization (FGD) - Wet, Spray Dry, 

and Dry Scrubbers. (EPA-452/F-03-034). 
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9.2 STEP 2 – ELIMINATE TECHNICALLY INFEASIBLE OPTIONS

Both control scenarios discussed above are considered technically feasible. 

9.3 STEP 3 – EVALUATE CONTROL EFFECTIVENESS OF REMAINING CONTROL 

TECHNOLOGIES

Table 9-1 presents a ranking of the technically feasible control strategies in order of their 

effectiveness. 

TABLE 9-1. RANKING OF CONTROL STRATEGIES

Control Strategy Applicability Potential Control Efficiencya

DFGD Unit 3 & Unit 4 83% 

WFGD Unit 3 & Unit 4 93% 

a

 Based on estimates from AEP. 

A summary of pre-BART baseline emissions as well as expected emission rates for each of 

the control technologies are summarized in Appendix E. Short-term controlled emission 

rates (lb/hr) were modeled in CALPUFF in order to evaluate visibility impacts. These 

controlled emission rates were calculated using the maximum 24-hr emission rate (in lb/hr) 

observed over the 2002-05 period as a baseline emission rate. This baseline emission rate (as 

described in Section 7.1) was then adjusting downward based upon the level of control 

efficiency expected for each technology. A summary of the lb/MMbtu emission factor that 

corresponds to each controlled emission rate is also included in Appendix E. 

Annual controlled emission rates (tpy), calculated as discussed below, were used in 

compliance cost determinations. These emission rates were calculated using a baseline 

lb/MMBtu emission factor (as observed over the 2002-05 time frame), maximum design 

hourly heat rate in BTU/Hr as described in Permit Memorandum 96-288-TV and an annual 

capacity factor of 85% and by applying the removal efficiencies corresponding to the 

appropriate control technology. 

9.4 STEP 4 – EVALUATE IMPACTS AND DOCUMENT RESULTS

Step four for the BART analysis procedure is the impact analysis. The BART determination 

guidelines list the five factors to be considered in the impact analysis: 

▲ Cost of compliance 

▲ Energy impacts 

▲ Non-air quality impacts 

▲ The remaining useful life of the source; and 

▲ Visibility impacts 
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Each of the first four factors are addressed in Step 4. The fifth factor, visibility impacts, is evaluated 

in Step 5. 

9.4.1 COST OF COMPLIANCE

Compliance costs associated with implementing DFGD and WFGD systems were 

developed in-house by AEP. Both annual operating costs and annualized capital costs 

associated with a retrofit construction were included. Included below in Table 9-2 is a 

brief cost analysis of the control equipment modeled in this BART determination. A 

detailed summary of those costs is included in Appendix F. 

TABLE 9-2. SO2 CONTROLS COSTS SUMMARY

 Average Cost 

Effectiveness 

Incremental Cost 

Effectiveness 

Emission Unit Control Strategy $/ton $/ton

Unit 3 & Unit 4 DFGD 3,266 N/A 

 WFGD 3,599 6,356 

9.4.2 ENERGY IMPACTS AND NON-AIR QUALITY IMPACTS

FGD systems require electricity to prime pumps and additional fan horsepower to 

overcome the high pressure drop in the systems. These electricity needs will deter from 

the net plant output and is a sizable energy penalty. 

Wet FGD systems generate wastewater and sludge that must be treated. This places 

additional burdens on the wastewater treatment and solid waste management capabilities. 

If wet scrubbing produces calcium sulfite sludge, the sludge will be water-laden, and it 

must be stabilized for landfilling. If wet scrubbing produces calcium sulfate sludge, it is 

stable and easy to dewater. However, control costs will be significantly higher because 

additional equipment is required in either waste disposal practices.. 

Disposal of material from dry FGD systems is also required and will result in landfill 

impacts. 

9.4.3 REMAINING USEFUL LIFE

The remaining useful life of Unit 3 and Unit 4 do not impact the annualized capital costs 

because the useful lives of the units are anticipated to be at least as long as the capital cost 

recovery period, which is 20 years. 

9.5 STEP 5 – EVALUATE VISIBILITY IMPACTS

The final impact analysis was conducted to assess the visibility improvement for existing emission 

rates when compared to the presumptive BART emission rates. The existing and presumptive BART 

emission levels were modeled using CALPUFF. The existing emission rates are the maximum 24-

hour average emission rate for each unit during the 2002-2005 time period, as called for in the 
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CENRAP modeling guidleines. The BART rates are the presumptive limits (in lb/MMBtu) 

multiplied by the historical maximum daily heat inputs. A summary of the existing and BART 

emission rates is provided in Appendix E. 

The visibility improvement due to the presumptive BART limits was calculated as the difference 

between the existing visibility impairment and the visibility impairment for the presumptive rates. A 

comparison of all the modeled emission rates is provided in Table 9-3 below. 

TABLE 9-3. NE STATION SO2 VISIBILITY RESULTS

 Peak Impact 98th Percentile 

Pollutant Class I Area 

Control 

Technology (∆dv) 

% Reduction 

from 

previous 

% Reduction 

from 

Baseline (∆dv) 

% Reduction 

from 

previous 

% Reduction 

from 

Baseline 

SO2 Caney Creek Baseline 4.54 -- -- 1.26 -- -- 

 DFGD 0.72 84% 84% 0.21 84% 84% 

 WFGD 0.34 53% 93% 0.12 44% 91% 

 Herc-Glades Baseline 3.12 -- -- 1.00 -- -- 

 DFGD 0.57 82% 82% 0.15 86% 86% 

 WFGD 0.31 46% 90% 0.07 52% 93% 

 Upper Buffalo Baseline 4.72 -- -- 0.91 -- -- 

 DFGD 0.38 92% 92% 0.13 86% 86% 

 WFGD 0.19 50% 96% 0.06 50% 93% 

 Wichita Mts Baseline 5.17 -- -- 1.20 -- -- 

 DFGD 1.01 80% 80% 0.21 83% 83% 

 WFGD 0.52 49% 90% 0.09 55% 92% 

9.6 BART DETERMINATION FOR SO2

The average cost effectiveness for the DFGD and WFGD are $3,266 and $3,599, respectively. The 

incremental costs of installing a WFGD system are estimated at approximately $6,500. Although 

WFGD does result in a greater visibility improvement than a DGFD system, the incremental visibility 

improvement is very limited. Of the four neighboring Class I areas, the greatest incremental 

improvement achieved (from pre-BART baseline conditions) by moving from DFGD to WFGD is 
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approximately 10%, or 0.49 dv (peak impact, Wichita Mountains). AEP notes that the incremental 

cost of a WFGD system is excessive when balanced against the limited visibility gains and 

wastewater management issues inherent to WGFD. 
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APPENDIX A- METEOROLOGICAL STATIONS

TABLE A-1. LIST OF SURFACE METEOROLOGICAL STATIONS

Number 

Station 

Acronym 

Station 

ID 

LCC 

East 

(km) 

LCC North

(km) Long Lat 

1 KDYS 69019 -267.672 -834.095 96.9968 39.9925 

2 KNPA 72222 932.565 -1020.909 97.0110 39.9908 

3 KBFM 72223 857.471 -996.829 97.0101 39.9910 

4 KGZH 72227 946.767 -899.515 97.0112 39.9919 

5 KTCL 72228 870.843 -706.104 97.0103 39.9936 

6 KNEW 53917 674.172 -1078.342 97.0080 39.9903 

7 KNBG 12958 677.719 -1104.227 97.0080 39.9900 

8 BVE 12884 741.996 -1153.463 97.0088 39.9896 

9 KPTN 72232 550.88 -1124.295 97.0065 39.9898 

10 KMEI 13865 774.911 -814.225 97.0092 39.9926 

11 KPIB 72234 728.416 -915.165 97.0086 39.9917 

12 KGLH 72235 557.072 -703.097 97.0066 39.9936 

13 KHEZ 11111 540.777 -912.22 97.0064 39.9918 

14 KMCB 11112 622.755 -949.618 97.0074 39.9914 

15 KGWO 11113 640.102 -695.286 97.0076 39.9937 

16 KASD 72236 692.381 -1043.261 97.0082 39.9906 

17 KPOE 72239 363.294 -984.839 97.0043 39.9911 

18 KBAZ 72241 -102.133 -1140.886 96.9988 39.9897 

19 KGLS 72242 215.108 -1185.604 97.0025 39.9893 

20 KDWH 11114 140.413 -1101.174 97.0017 39.9900 

21 KIAH 12960 158.266 -1108.37 97.0019 39.9900 

22 KHOU 72243 167.147 -1147.402 97.0020 39.9896 

23 KEFD 12906 178.551 -1152.782 97.0021 39.9896 

24 KCXO 72244 152.739 -1069.309 97.0018 39.9903 

25 KCLL 11115 60.898 -1044.381 97.0007 39.9906 

26 KLFK 93987 214.643 -969.355 97.0025 39.9912 

27 KUTS 11116 136.056 -1026.773 97.0016 39.9907 

28 KTYR 11117 150.451 -846.207 97.0018 39.9924 

29 KCRS 72246 56.655 -882.642 97.0007 39.9920 

30 KGGG 72247 214.572 -841.163 97.0025 39.9924 

31 KGKY 11118 -9.365 -812.25 96.9999 39.9927 

32 KDTN 72248 304.827 -821.713 97.0036 39.9926 

33 KBAD 11119 312.743 -825.101 97.0037 39.9925 

34 KMLU 11120 465.834 -816.211 97.0055 39.9926 

35 KTVR 11121 561.446 -840.225 97.0066 39.9924 

36 KTRL 11122 68.599 -806.417 97.0008 39.9927 

37 KOCH 72249 216.81 -930.252 97.0026 39.9916 

38 KBRO 12919 -44.167 -1571.387 96.9995 39.9858 
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Number 

Station 

Acronym 

Station 

ID 

LCC 

East 

(km) 

LCC North

(km) Long Lat 

39 KALI 72251 -103.012 -1363.74 96.9988 39.9877 

40 KLRD 12920 -246.548 -1381.603 96.9971 39.9875 

41 KSSF 72252 -143.386 -1183.35 96.9983 39.9893 

42 KRKP 11123 -4.965 -1324.914 96.9999 39.9880 

43 KCOT 11124 -219.097 -1280.964 96.9974 39.9884 

44 KLBX 11125 150.245 -1207.466 97.0018 39.9891 

45 KSAT 12921 -143.024 -1160.935 96.9983 39.9895 

46 KHDO 12962 -211.702 -1178.172 96.9975 39.9894 

47 KSKF 72253 -154.625 -1177.555 96.9982 39.9894 

48 KHYI 11126 -84.156 -1122.487 96.9990 39.9899 

49 KTKI 72254 38.788 -754.791 97.0005 39.9932 

50 KBMQ 11127 -118.39 -1027.031 96.9986 39.9907 

51 KATT 11128 -67.587 -1075.97 96.9992 39.9903 

52 KSGR 11129 131.478 -1151.702 97.0016 39.9896 

53 KGTU 11130 -65.624 -1033.173 96.9992 39.9907 

54 KVCT 12912 6.587 -1236.788 97.0001 39.9888 

55 KPSX 72255 73.878 -1253.33 97.0009 39.9887 

56 KACT 13959 -22.12 -929.156 96.9997 39.9916 

57 KPWG 72256 -30.147 -944.073 96.9996 39.9915 

58 KILE 72257 -65.288 -988.507 96.9992 39.9911 

59 KGRK 11131 -79.643 -990.173 96.9991 39.9911 

60 KTPL 11132 -38.203 -981.19 96.9996 39.9911 

61 KPRX 13960 143.317 -703.663 97.0017 39.9936 

62 KDTO 72258 -17.018 -752.974 96.9998 39.9932 

63 KAFW 11133 -29.564 -777.061 96.9997 39.9930 

64 KFTW 72259 -34.302 -795.502 96.9996 39.9928 

65 KMWL 11134 -99.769 -798.767 96.9988 39.9928 

66 KRBD 11135 12.453 -810.467 97.0002 39.9927 

67 KDRT 11136 -384.069 -1170.59 96.9955 39.9894 

68 KFST 22010 -566.418 -988.838 96.9933 39.9911 

69 KGDP 72261 -739.127 -873.302 96.9913 39.9921 

70 KSJT 72262 -333.338 -952.54 96.9961 39.9914 

71 KMRF 23034 -676.265 -1042.616 96.9920 39.9906 

72 KMAF 72264 -489.668 -878.107 96.9942 39.9921 

73 KINK 23023 -586.882 -890.654 96.9931 39.9920 

74 KABI 72265 -252.044 -836.353 96.9970 39.9924 

75 KLBB 13962 -445.006 -689.313 96.9948 39.9938 

76 KATS 11137 -696.818 -763.258 96.9918 39.9931 

77 KCQC 11138 -785.757 -515.724 96.9907 39.9953 

78 KROW 23009 -698.822 -712.898 96.9918 39.9936 

79 KSRR 72268 -789.593 -686.226 96.9907 39.9938 

80 KCNM 11139 -682.79 -822.109 96.9919 39.9926 

81 KALM 36870 -838.056 -752.338 96.9901 39.9932 

82 KLRU 72269 -931.527 -804.112 96.9890 39.9927 
American Electric Power A-3 Trinity Consultants 

Northeastern Power Station 083701.0024 

Number 

Station 

Acronym 

Station 

ID 

LCC 

East 

(km) 

LCC North

(km) Long Lat 

83 KTCS 72271 -952.353 -695.469 96.9888 39.9937 

84 KSVC 93063 -1042.03 -752.033 96.9877 39.9932 

85 KDMN 72272 -1006.77 -799.231 96.9881 39.9928 

86 KMSL 72323 854.846 -536.687 97.0101 39.9952 

87 KPOF 72330 578.62 -336.733 97.0068 39.9970 

88 KGTR 11140 779.065 -689.108 97.0092 39.9938 

89 KTUP 93862 753.875 -600.337 97.0089 39.9946 

90 KMKL 72334 727.051 -454.383 97.0086 39.9959 

91 KLRF 72340 440.654 -550.661 97.0052 39.9950 

92 KHKA 11141 643.365 -424.419 97.0076 39.9962 

93 KHOT 72341 358.094 -604.603 97.0042 39.9945 

94 KTXK 11142 278.022 -720.623 97.0033 39.9935 

95 KLLQ 72342 488.655 -698.008 97.0058 39.9937 

96 KMWT 72343 254.18 -599.224 97.0030 39.9946 

97 KFSM 13964 237.97 -512.87 97.0028 39.9954 

98 KSLG 72344 224.881 -419.064 97.0027 39.9962 

99 KVBT 11143 248.074 -399.892 97.0029 39.9964 

100 KHRO 11144 343.525 -405.601 97.0041 39.9963 

101 KFLP 11145 404.239 -399.142 97.0048 39.9964 

102 KBVX 11146 480.712 -457.853 97.0057 39.9959 

103 KROG 11147 258.44 -397.685 97.0031 39.9964 

104 KSPS 13966 -138.053 -664.886 96.9984 39.9940 

105 KHBR 72352 -186.121 -551.123 96.9978 39.9950 

106 KCSM 11148 -198.844 -513.911 96.9977 39.9954 

107 KFDR 11149 -181.653 -625.205 96.9979 39.9944 

108 KGOK 72353 -35.905 -458.97 96.9996 39.9959 

109 KTIK 72354 -34.581 -506.938 96.9996 39.9954 

110 KPWA 11150 -58.596 -493.951 96.9993 39.9955 

111 KSWO 11151 -7.42 -425.828 96.9999 39.9962 

112 KMKO 72355 146.972 -479.879 97.0017 39.9957 

113 KRVS 72356 91.059 -438.276 97.0011 39.9960 

114 KBVO 11152 87.136 -357.069 97.0010 39.9968 

115 KMLC 11153 110.647 -563.566 97.0013 39.9949 

116 KOUN 72357 -40.731 -527.298 96.9995 39.9952 

117 KLAW 11154 -129.405 -600.222 96.9985 39.9946 

118 KCDS 72360 -300.297 -610.668 96.9965 39.9945 

119 KGNT 72362 -985.117 -475.563 96.9884 39.9957 

120 KGUP 11155 -1059.48 -427.151 96.9875 39.9961 

121 KAMA 23047 -425.319 -518.171 96.9950 39.9953 

122 KBGD 72363 -395.603 -466.083 96.9953 39.9958 

123 KFMN 72365 -993.449 -297.944 96.9883 39.9973 

124 KSKX 72366 -770.464 -355.855 96.9909 39.9968 

125 KTCC 23048 -597.271 -511.241 96.9930 39.9954 

126 KLVS 23054 -732.565 -448.329 96.9914 39.9960 
American Electric Power A-4 Trinity Consultants 

Northeastern Power Station 083701.0024 

Number 

Station 

Acronym 

Station 

ID 

LCC 

East 

(km) 

LCC North

(km) Long Lat 

127 KEHR 72423 812.573 -199.695 97.0096 39.9982 

128 KEVV 93817 822.929 -172.715 97.0097 39.9984 

129 KMVN 72433 704.666 -154.54 97.0083 39.9986 

130 KMDH 11156 676.745 -218.041 97.0080 39.9980 

131 KBLV 11157 617.659 -136.018 97.0073 39.9988 

132 KSUS 3966 547.898 -130.122 97.0065 39.9988 

133 KPAH 3816 725.985 -293.319 97.0086 39.9974 

134 KJEF 72445 419.01 -145.496 97.0050 39.9987 

135 KAIZ 11158 387.096 -200.609 97.0046 39.9982 

136 KIXD 72447 182.322 -126.913 97.0022 39.9989 

137 KWLD 72450 0 -298.57 97.0000 39.9973 

138 KAAO 11159 -18.976 -248.773 96.9998 39.9978 

139 KIAB 11160 -23.392 -263.471 96.9997 39.9976 

140 KEWK 11161 -24.645 -215.58 96.9997 39.9981 

141 KGBD 72451 -161.892 -180.781 96.9981 39.9984 

142 KHYS 11162 -195.191 -124.723 96.9977 39.9989 

143 KCFV 11163 126.442 -319.698 97.0015 39.9971 

144 KFOE 72456 114.618 -115.26 97.0014 39.9990 

145 KEHA 72460 -432.761 -320.089 96.9949 39.9971 

146 KALS 72462 -777.592 -245.892 96.9908 39.9978 

147 KDRO 11164 -945.713 -259.163 96.9888 39.9977 

148 KLHX 72463 -568.426 -195.178 96.9933 39.9982 

149 KSPD 2128 -494.076 -285.176 96.9942 39.9974 

150 KCOS 93037 -664.022 -102.596 96.9922 39.9991 

151 KGUC 72467 -857.452 -115.301 96.9899 39.9990 

152 KMTJ 93013 -940.981 -109.358 96.9889 39.9990 

153 KCEZ 72476 -1020.87 -233.14 96.9880 39.9979 

154 KCPS 72531 591.652 -136.14 97.0070 39.9988 

155 KLWV 72534 808.939 -94.46 97.0096 39.9992 

156 KPPF 74543 130.433 -293.855 97.0015 39.9973 

157 KHOP 74671 841.751 -324.569 97.0099 39.9971 

158 KBIX 74768 778.252 -1028.514 97.0092 39.9907 

159 KPQL 11165 814.599 -1019.583 97.0096 39.9908 

160 MMPG 76243 -348.007 -1248.779 96.9959 39.9887 

161 MMMV 76342 -446.576 -1449.334 96.9947 39.9869 

162 MMMY 76394 -316.664 -1581.176 96.9963 39.9857 
American Electric Power A-5 Trinity Consultants 

Northeastern Power Station 083701.0024 

TABLE A-2. LIST OF UPPER AIR METEOROLOGICAL STATIONS

Number 

Station 

Acronym 

Station 

ID 

LCC 

East 

(km) 

LCC 

North 

(km) Long Lat 

1 KABQ 23050 -869.46 -501.713 96.9897 39.9955 

2 KAMA 23047 -425.319 -518.171 96.9950 39.9953 

3 KBMX 53823 951.609 -702.935 97.0112 39.9936 

4 KBNA 13897 920.739 -377.164 97.0109 39.9966 

5 KBRO 12919 -44.167 -1571.39 96.9995 39.9858 

6 KCRP 12924 -51.535 -1360.35 96.9994 39.9877 

7 KDDC 13985 -259.352 -242.681 96.9969 39.9978 

8 KDRT 22010 -384.069 -1170.59 96.9955 39.9894 

9 KEPZ 3020 -914.558 -852.552 96.9892 39.9923 

10 KFWD 3990 -28.034 -793.745 96.9997 39.9928 

11 KJAN 3940 650.105 -826.452 97.0077 39.9925 

12 KLCH 3937 364.461 -1089.15 97.0043 39.9902 

13 KLZK 3952 432.063 -560.441 97.0051 39.9949 

14 KMAF 23023 -489.668 -878.107 96.9942 39.9921 

15 KOUN 3948 -40.731 -527.298 96.9995 39.9952 

16 KSHV 13957 298.869 -831.166 97.0035 39.9925 

17 KSIL 53813 698.079 -1054.03 97.0082 39.9905 
American Electric Power A-6 Trinity Consultants 

Northeastern Power Station 083701.0024 

TABLE A-3. LIST OF PRECIPITATION METEOROLOGICAL STATIONS

Number 

Station 

Acronym 

Station 

ID 

LCC 

East 

(km) 

LCC 

North 

(km) Long Lat 

1 ADDI 10063 906.825 -601.428 97.0107 39.9946 

2 ALBE 10140 917.606 -821.64 97.0108 39.9926 

3 BERR 10748 892.454 -683.388 97.0105 39.9938 

4 HALE 13620 881.928 -601.878 97.0104 39.9946 

5 HAMT 13645 863.663 -612.725 97.0102 39.9945 

6 JACK 14193 898.014 -915.623 97.0106 39.9917 

7 MBLE 15478 851.953 -1022.41 97.0101 39.9908 

8 MUSC 15749 880.113 -567.484 97.0104 39.9949 

9 PETE 16370 935.558 -908.259 97.0110 39.9918 

10 THOM 18178 900.858 -915.326 97.0106 39.9917 

11 TUSC 18385 895.631 -713.223 97.0106 39.9936 

12 VERN 18517 825.585 -685.773 97.0098 39.9938 

13 BEEB 30530 462.394 -532.485 97.0055 39.9952 

14 BRIG 30900 318.015 -554.857 97.0038 39.9950 

15 CALI 31140 419.619 -731.44 97.0050 39.9934 

16 CAMD 31152 386.546 -699.659 97.0046 39.9937 

17 DIER 32020 268.114 -643.184 97.0032 39.9942 

18 EURE 32356 286.738 -390.862 97.0034 39.9965 

19 GILB 32794 383.362 -435.625 97.0045 39.9961 

20 GREE 32978 450.594 -483.201 97.0053 39.9956 

21 STUT 36920 509.943 -596.328 97.0060 39.9946 

22 TEXA 37048 278.022 -720.623 97.0033 39.9935 

23 ALAM 50130 -749.044 -267.856 96.9912 39.9976 

24 ARAP 50304 -441.903 -152.324 96.9948 39.9986 

25 COCH 51713 -819.794 -148.582 96.9903 39.9987 

26 CRES 51959 -828.107 -119.911 96.9902 39.9989 

27 GRAN 53477 -451.781 -203.82 96.9947 39.9982 

28 GUNN 53662 -829.573 -141.995 96.9902 39.9987 

29 HUGO 54172 -539.364 -81.948 96.9936 39.9993 

30 JOHN 54388 -483.95 -201.915 96.9943 39.9982 

31 KIM 54538 -544.501 -283.337 96.9936 39.9974 

32 MESA 55531 -993.391 -256.696 96.9883 39.9977 

33 ORDW 56136 -549.552 -55.741 96.9935 39.9995 

34 OURA 56203 -904.197 -168.246 96.9893 39.9985 

35 PLEA 56591 -1005.94 -229.472 96.9881 39.9979 

36 PUEB 56740 -633.961 -176.872 96.9925 39.9984 

37 TYE 57320 -662.095 -242.254 96.9922 39.9978 
American Electric Power A-7 Trinity Consultants 

Northeastern Power Station 083701.0024 

Number 

Station 

Acronym 

Station 

ID 

LCC 

East 

(km) 

LCC 

North 

(km) Long Lat 

38 SAGU 57337 -790.269 -176.061 96.9907 39.9984 

39 SANL 57428 -726.777 -285.47 96.9914 39.9974 

40 SHEP 57572 -714.046 -252.189 96.9916 39.9977 

41 TELL 58204 -920.205 -215.382 96.9891 39.9981 

42 TERC 58220 -708.229 -296.023 96.9916 39.9973 

43 TRIN 58429 -642.489 -293.805 96.9924 39.9973 

44 TRLK 58436 -646.185 -295.727 96.9924 39.9973 

45 WALS 58781 -654.989 -262.821 96.9923 39.9976 

46 WHIT 58997 -619.615 -250.12 96.9927 39.9977 

47 ASHL 110281 684.787 -169.285 97.0081 39.9985 

48 CAIR 111166 697.177 -301.436 97.0082 39.9973 

49 CARM 111302 772.938 -177.782 97.0091 39.9984 

50 CISN 111664 758.146 -151.446 97.0090 39.9986 

51 FLOR 113109 751.801 -139.837 97.0089 39.9987 

52 HARR 113879 762.044 -246.62 97.0090 39.9978 

53 KASK 114629 650.464 -239.886 97.0077 39.9978 

54 LAWR 114957 829.038 -128.708 97.0098 39.9988 

55 MTCA 115888 827.797 -149.966 97.0098 39.9986 

56 MURP 115983 682.261 -251.649 97.0081 39.9977 

57 NEWT 116159 766.098 -72.902 97.0090 39.9993 

58 REND 117187 731.633 -185.058 97.0086 39.9983 

59 SMIT 118020 770.027 -283.638 97.0091 39.9974 

60 SPAR 118147 658.275 -185.973 97.0078 39.9983 

61 VAND 118781 685.449 -127.048 97.0081 39.9989 

62 WEST 119193 778.655 -147.215 97.0092 39.9987 

63 EVAN 122738 842.476 -172.871 97.0100 39.9984 

64 NEWB 126151 855.854 -223.713 97.0101 39.9980 

65 PRIN 127125 836.901 -153.449 97.0099 39.9986 

66 STEN 128442 859.099 -156.613 97.0101 39.9986 

67 JTML 128967 788.703 -239.572 97.0093 39.9978 

68 ARLI 140326 -101.734 -271.373 96.9988 39.9976 

69 BAZI 140620 -210.423 -201.758 96.9975 39.9982 

70 BEAU 140637 59.762 -288.39 97.0007 39.9974 

71 BONN 140957 211.236 -103.29 97.0025 39.9991 

72 CALD 141233 -32.689 -330.586 96.9996 39.9970 

73 CASS 141351 54.006 -217.645 97.0006 39.9980 

74 CENT 141404 170.503 -206.038 97.0020 39.9981 

75 CHAN 141427 150.257 -286.094 97.0018 39.9974 

76 CLIN 141612 155.623 -157.682 97.0018 39.9986 

77 COLL 141730 -265.465 -156.95 96.9969 39.9986 
American Electric Power A-8 Trinity Consultants 

Northeastern Power Station 083701.0024 

Number 

Station 

Acronym 

Station 

ID 

LCC 

East 

(km) 

LCC 

North 

(km) Long Lat 

78 COLU 141740 220.541 -316.555 97.0026 39.9971 

79 CONC 141867 58.918 -175.589 97.0007 39.9984 

80 DODG 142164 -226.497 -277.655 96.9973 39.9975 

81 ELKH 142432 -400.112 -321.784 96.9953 39.9971 

82 ENGL 142560 -264.927 -324.066 96.9969 39.9971 

83 ERIE 142582 162.669 -291.383 97.0019 39.9974 

84 FALL 142686 83.491 -288.177 97.0010 39.9974 

85 GALA 142938 -136.931 -176.83 96.9984 39.9984 

86 GARD 142980 -304.059 -215.308 96.9964 39.9981 

87 GREN 143248 64.308 -307.161 97.0008 39.9972 

88 HAYS 143527 -190.307 -161.342 96.9978 39.9985 

89 HEAL 143554 -292.133 -175.921 96.9966 39.9984 

90 HILL 143686 214.018 -174.006 97.0025 39.9984 

91 INDE 143954 139.335 -315.058 97.0016 39.9972 

92 IOLA 143984 153.451 -269.438 97.0018 39.9976 

93 JOHR 144104 134.784 -203.41 97.0016 39.9982 

94 KANO 144178 -50.289 -181.177 96.9994 39.9984 

95 KIOW 144341 -113.967 -329.843 96.9987 39.9970 

96 MARI 145039 -4.343 -195.712 97.0000 39.9982 

97 MELV 145210 137.104 -186.781 97.0016 39.9983 

98 MILF 145306 39.504 -106.05 97.0005 39.9990 

99 MOUD 145536 152.624 -318.136 97.0018 39.9971 

100 OAKL 145888 -306.378 -96.814 96.9964 39.9991 

101 OTTA 146128 158.639 -178.635 97.0019 39.9984 

102 POMO 146498 143.864 -176.707 97.0017 39.9984 

103 SALI 147160 -29.426 -166.908 96.9997 39.9985 

104 SMOL 147551 -34.639 -171.31 96.9996 39.9985 

105 STAN 147756 225.026 -164.85 97.0027 39.9985 

106 SUBL 147922 -303.514 -292.808 96.9964 39.9974 

107 TOPE 148167 139.116 -104.91 97.0016 39.9991 

108 TRIB 148235 -387.855 -180.643 96.9954 39.9984 

109 UNIO 148293 211.43 -272.537 97.0025 39.9975 

110 WALL 148535 -376.076 -152.432 96.9956 39.9986 

111 WICH 148830 -23.729 -288.579 96.9997 39.9974 

112 WILS 148946 -111.502 -156.22 96.9987 39.9986 

113 BENT 150611 781.608 -348.109 97.0092 39.9969 

114 CALH 151227 865.268 -261.635 97.0102 39.9976 

115 CLTN 151631 749.287 -365.634 97.0088 39.9967 

116 HERN 153798 859.01 -352.458 97.0101 39.9968 

117 MADI 155067 854.116 -265.064 97.0101 39.9976 
American Electric Power A-9 Trinity Consultants 

Northeastern Power Station 083701.0024 

Number 

Station 

Acronym 

Station 

ID 

LCC 

East 

(km) 

LCC 

North 

(km) Long Lat 

118 PADU 156110 753.185 -293.024 97.0089 39.9974 

119 PCTN 156580 834.464 -280.496 97.0099 39.9975 

120 ALEX 160103 433.824 -959.253 97.0051 39.9913 

121 BATN 160549 562.794 -1032.4 97.0066 39.9907 

122 CALH 161411 436.113 -817.451 97.0052 39.9926 

123 CLNT 161899 578.969 -999.986 97.0068 39.9910 

124 JENA 164696 455.225 -912.366 97.0054 39.9918 

125 LACM 165078 364.784 -1089.92 97.0043 39.9901 

126 MIND 166244 346.708 -812.651 97.0041 39.9927 

127 MONR 166314 463.225 -814.905 97.0055 39.9926 

128 NATC 166582 369.451 -905.316 97.0044 39.9918 

129 SHRE 168440 299.526 -831.143 97.0035 39.9925 

130 WINN 169803 408.309 -884.596 97.0048 39.9920 

131 BROK 221094 621.827 -914.236 97.0073 39.9917 

132 CONE 221900 737.007 -823.513 97.0087 39.9926 

133 JAKS 224472 650.361 -826.097 97.0077 39.9925 

134 LEAK 224966 805.886 -943.78 97.0095 39.9915 

135 MERI 225776 774.942 -814.558 97.0092 39.9926 

136 SARD 227815 658.33 -593.661 97.0078 39.9946 

137 SAUC 227840 763.399 -1005.93 97.0090 39.9909 

138 TUPE 229003 753.571 -600.03 97.0089 39.9946 

139 ADVA 230022 657.892 -298.102 97.0078 39.9973 

140 ALEY 230088 505.348 -305.864 97.0060 39.9972 

141 BOLI 230789 331.651 -291.689 97.0039 39.9974 

142 CASV 231383 310.855 -392.187 97.0037 39.9965 

143 CLER 231674 575.868 -302.209 97.0068 39.9973 

144 CLTT 231711 307.465 -190.83 97.0036 39.9983 

145 COLU 231791 421.287 -155.672 97.0050 39.9986 

146 DREX 232331 228.23 -185.776 97.0027 39.9983 

147 ELM 232568 257.758 -159.419 97.0030 39.9986 

148 FULT 233079 470.408 -150.668 97.0056 39.9986 

149 HOME 233999 619.93 -415.469 97.0073 39.9962 

150 JEFF 234271 424.774 -172.095 97.0050 39.9984 

151 JOPL 234315 238.245 -318.262 97.0028 39.9971 

152 LEBA 234825 402.239 -276.263 97.0048 39.9975 

153 LICK 234919 480.849 -280.775 97.0057 39.9975 

154 LOCK 235027 302.048 -300.612 97.0036 39.9973 

155 MALD 235207 659.982 -377.876 97.0078 39.9966 

156 MARS 235298 332.062 -94.655 97.0039 39.9991 

157 MAFD 235307 391.968 -300.033 97.0046 39.9973 
American Electric Power A-10 Trinity Consultants 

Northeastern Power Station 083701.0024 

Number 

Station 

Acronym 

Station 

ID 

LCC 

East 

(km) 

LCC 

North 

(km) Long Lat 

158 MCES 235415 471.737 -143.942 97.0056 39.9987 

159 MILL 235594 309.516 -311.398 97.0037 39.9972 

160 MTGV 235834 426.937 -310.43 97.0050 39.9972 

161 NVAD 235987 243.915 -272.715 97.0029 39.9975 

162 OZRK 236460 349.133 -390.626 97.0041 39.9965 

163 PDTD 236777 334.055 -265.018 97.0039 39.9976 

164 POTO 236826 572.215 -251.455 97.0068 39.9977 

165 ROLL 237263 484.503 -253.958 97.0057 39.9977 

166 ROSE 237300 500.59 -175.393 97.0059 39.9984 

167 SALE 237506 498.94 -274.122 97.0059 39.9975 

168 SENE 237656 233.959 -383.703 97.0028 39.9965 

169 SPRC 237967 238.112 -373.616 97.0028 39.9966 

170 SPVL 237976 332.385 -309.374 97.0039 39.9972 

171 STEE 238043 503.354 -205.135 97.0059 39.9981 

172 STOK 238082 310.911 -279.239 97.0037 39.9975 

173 SWSP 238223 324.053 -150.325 97.0038 39.9986 

174 TRKD 238252 340.418 -395.428 97.0040 39.9964 

175 TRUM 238466 326.883 -197.796 97.0039 39.9982 

176 UNIT 238524 238.567 -154.494 97.0028 39.9986 

177 VIBU 238609 519.633 -267.258 97.0061 39.9976 

178 VIEN 238620 470.383 -193.872 97.0056 39.9983 

179 WAPP 238700 606.68 -358.746 97.0072 39.9968 

180 WASG 238746 556.425 -164.993 97.0066 39.9985 

181 WEST 238880 489.373 -377.809 97.0058 39.9966 

182 ALBU 290234 -869.46 -501.713 96.9897 39.9955 

183 ARTE 290600 -689.529 -773.897 96.9919 39.9930 

184 AUGU 290640 -973.07 -598.391 96.9885 39.9946 

185 CARL 291469 -680.335 -811.474 96.9920 39.9927 

186 CARR 291515 -819.836 -665.132 96.9903 39.9940 

187 CLAY 291887 -547.124 -374.102 96.9935 39.9966 

188 CLOV 291939 -566.973 -599.296 96.9933 39.9946 

189 CUBA 292241 -890.304 -392.495 96.9895 39.9965 

190 CUBE 292250 -951.142 -489.293 96.9888 39.9956 

191 DEMI 292436 -1007.99 -799.087 96.9881 39.9928 

192 DURA 292665 -767.148 -577.618 96.9909 39.9948 

193 EANT 292700 -735.089 -366.94 96.9913 39.9967 

194 LAVG 294862 -738.245 -461.163 96.9913 39.9958 

195 PROG 297094 -811.39 -578.971 96.9904 39.9948 

196 RAMO 297254 -733.737 -615.175 96.9913 39.9944 

197 ROSW 297610 -698.544 -712.921 96.9918 39.9936 
American Electric Power A-11 Trinity Consultants 

Northeastern Power Station 083701.0024 

Number 

Station 

Acronym 

Station 

ID 

LCC 

East 

(km) 

LCC 

North 

(km) Long Lat 

198 ROY 297638 -644.735 -422.422 96.9924 39.9962 

199 SANT 298085 -807.375 -445.708 96.9905 39.9960 

200 SPRI 298501 -676.681 -374.272 96.9920 39.9966 

201 STAY 298518 -810.491 -495.501 96.9904 39.9955 

202 TNMN 299031 -912.488 -413.425 96.9892 39.9963 

203 TUCU 299156 -604.359 -508.834 96.9929 39.9954 

204 WAST 299569 -638.605 -820.288 96.9925 39.9926 

205 WISD 299686 -856.967 -756.366 96.9899 39.9932 

206 AIRS 340179 -212.731 -597.062 96.9975 39.9946 

207 ARDM 340292 -12.242 -645.633 96.9999 39.9942 

208 BENG 340670 174.368 -568.011 97.0021 39.9949 

209 CANE 341437 71.857 -637.935 97.0009 39.9942 

210 CHRT 341544 203.233 -632.067 97.0024 39.9943 

211 CHAN 341684 10.494 -475.655 97.0001 39.9957 

212 CHIK 341750 -83.175 -547.26 96.9990 39.9951 

213 CCTY 342334 -165 -479.536 96.9981 39.9957 

214 DUNC 342654 -88.38 -610.04 96.9990 39.9945 

215 ELKC 342849 -216.769 -507.879 96.9974 39.9954 

216 FORT 343281 -129.964 -541.113 96.9985 39.9951 

217 GEAR 343497 -118.53 -482.187 96.9986 39.9956 

218 HENN 344052 -31.964 -601.206 96.9996 39.9946 

219 HOBA 344202 -189.062 -547.36 96.9978 39.9951 

220 KING 344865 24.538 -664.103 97.0003 39.9940 

221 LKEU 344975 141.702 -520.6 97.0017 39.9953 

222 LEHI 345108 71.634 -612.05 97.0009 39.9945 

223 MACI 345463 -254.63 -466.154 96.9970 39.9958 

224 MALL 345589 -55.127 -425.644 96.9994 39.9962 

225 MAYF 345648 -258.49 -512.583 96.9970 39.9954 

226 MUSK 346130 149.764 -466.905 97.0018 39.9958 

227 NOWA 346485 121.551 -364.038 97.0014 39.9967 

228 OKAR 346620 -88.424 -473.338 96.9990 39.9957 

229 OKEM 346638 63.188 -504.958 97.0008 39.9954 

230 OKLA 346661 -54.198 -510.562 96.9994 39.9954 

231 PAOL 346859 -23.665 -573.142 96.9997 39.9948 

232 PAWH 346935 57.704 -369.174 97.0007 39.9967 

233 PAWN 346944 16.927 -398.139 97.0002 39.9964 

234 PONC 347196 -8.871 -363.068 96.9999 39.9967 

235 PRYO 347309 150.763 -407.824 97.0018 39.9963 

236 SHAT 348101 -256.963 -407.368 96.9970 39.9963 

237 STIG 348497 171.02 -523.736 97.0020 39.9953 
American Electric Power A-12 Trinity Consultants 

Northeastern Power Station 083701.0024 

Number 

Station 

Acronym 

Station 

ID 

LCC 

East 

(km) 

LCC 

North 

(km) Long Lat 

238 TULS 348992 99.361 -419.873 97.0012 39.9962 

239 TUSK 349023 156.629 -592.395 97.0019 39.9946 

240 WMWR 349629 -156.42 -581.308 96.9982 39.9947 

241 WOLF 349748 30.212 -538.388 97.0004 39.9951 

242 BOLI 400876 760.886 -500.256 97.0090 39.9955 

243 BROW 401150 710.048 -480.346 97.0084 39.9957 

244 CETR 401587 877.35 -456.294 97.0104 39.9959 

245 DICS 402489 872.14 -391.132 97.0103 39.9965 

246 DYER 402680 695.792 -409.316 97.0082 39.9963 

247 GRNF 403697 760.795 -395.69 97.0090 39.9964 

248 JSNN 404561 765.932 -476.414 97.0090 39.9957 

249 LWER 405089 885.291 -487.757 97.0105 39.9956 

250 LEXI 405210 790.003 -471.897 97.0093 39.9957 

251 MASO 405720 694.163 -496.166 97.0082 39.9955 

252 MEMP 405954 671.8 -522.492 97.0079 39.9953 

253 MWFO 405956 681.292 -516.15 97.0080 39.9953 

254 MUNF 406358 678.65 -495.241 97.0080 39.9955 

255 SAMB 408065 697.077 -382.536 97.0082 39.9965 

256 SAVA 408108 800.788 -498.682 97.0095 39.9955 

257 UNCY 409219 711.595 -384.605 97.0084 39.9965 

258 ABIL 410016 -251.753 -836.027 96.9970 39.9924 

259 AMAR 410211 -425.302 -517.839 96.9950 39.9953 

260 AUST 410428 -67.587 -1075.97 96.9992 39.9903 

261 BRWN 411136 -43.861 -1571.39 96.9995 39.9858 

262 COST 411889 60.611 -1044.72 97.0007 39.9906 

263 COCR 412015 -51.832 -1360.01 96.9994 39.9877 

264 CROS 412131 -204.599 -868.469 96.9976 39.9922 

265 DFWT 412242 -1.867 -786.341 97.0000 39.9929 

266 EAST 412715 -171.024 -840.253 96.9980 39.9924 

267 ELPA 412797 -886.583 -860.763 96.9895 39.9922 

268 HICO 414137 -97.323 -888.181 96.9989 39.9920 

269 HUST 414300 157.976 -1108.38 97.0019 39.9900 

270 KRES 414880 -434.746 -611.717 96.9949 39.9945 

271 LKCK 414975 99.734 -693.521 97.0012 39.9937 

272 LNGV 415348 220.962 -844.674 97.0026 39.9924 

273 LUFK 415424 214.652 -969.69 97.0025 39.9912 

274 MATH 415661 -86.438 -1330.47 96.9990 39.9880 

275 MIDR 415890 -489.385 -878.123 96.9942 39.9921 

276 MTLK 416104 -672.024 -1008.98 96.9921 39.9909 

277 NACO 416177 223.065 -925.966 97.0026 39.9916 
American Electric Power A-13 Trinity Consultants 

Northeastern Power Station 083701.0024 

Number 

Station 

Acronym 

Station 

ID 

LCC 

East 

(km) 

LCC 

North 

(km) Long Lat 

278 NAVA 416210 28.358 -892.028 97.0003 39.9919 

279 NEWB 416270 239.111 -721.818 97.0028 39.9935 

280 BPAT 417174 288.962 -1110.65 97.0034 39.9900 

281 RANK 417431 -472.048 -959.488 96.9944 39.9913 

282 SAAG 417943 -333.338 -952.54 96.9961 39.9914 

283 SAAT 417945 -143.322 -1161.27 96.9983 39.9895 

284 SHEF 418252 -463.759 -1019.19 96.9945 39.9908 

285 STEP 418623 -112.988 -857.918 96.9987 39.9922 

286 STER 418630 -376.683 -897.195 96.9956 39.9919 

287 VALE 419270 -720.749 -1015.17 96.9915 39.9908 

288 VICT 419364 6.882 -1236.45 97.0001 39.9888 

289 WACO 419419 -21.834 -928.823 96.9997 39.9916 

290 WATR 419499 -353.767 -916.015 96.9958 39.9917 

291 WHEE 419665 57.489 -1008.99 97.0007 39.9909 

292 WPDM 419916 262.792 -737.786 97.0031 39.9933 

293 DORA 232302 433.256 -378.797 97.0051 39.9966 

294 DIXN 112353 756.057 -267.193 97.0089 39.9976 

295 DAUP 12172 864.408 -1050.41 97.0102 39.9905 

296 FREV 123104 847.031 -117.884 97.0100 39.9989 

297 WARR 18673 890.447 -788.703 97.0105 39.9929 

298 MDTN 235562 493.264 -87.222 97.0058 39.9992 
American Electric Power A-14 Trinity Consultants 

Northeastern Power Station 083701.0024 

TABLE A-4. LIST OF OVER WATER METEOROLOGICAL STATIONS

Number 

Station 

ID 

Input file 

Name 

LCC 

East 

(km) 

LCC North

(km) Long Lat 

1 42001 42001 746.874 -1541.35 89.67 25.9 

2 42002 42002 265.486 -1650.616 94.42 25.19 

3 42007 42007 795.674 -1063.667 88.77 30.09 

4 42019 42019 163.178 -1342.917 95.36 27.91 

5 42020 42020 30.212 -1453.738 96.7 26.94 

6 42035 42035 254.465 -1193.539 94.41 29.25 

7 42040 42040 859.497 -1160.066 88.21 29.18 

8 BURL1 42045 743.116 -1202.117 89.43 28.9 

9 DPIA1 42046 861.385 -1039.466 88.07 30.25 

10 GDIL1 42047 687.984 -1164.910 89.96 29.27 

11 PTAT2 42048 -4.980 -1353.398 97.05 27.83 

12 SRST2 42049 288.163 -1175.682 94.05 29.67 
American Electric Power B-1 Trinity Consultants 

Northeastern Power Station 083701.0024 

APPENDIX B – SAMPLE CALMET CONTROL FILE
01Met01a.inp

2001 - RefinedJanuary 1 - January 10---------------- Run title (3 lines) ------------------------------------------ CALMET MODEL CONTROL FILE ---------------------------------------------------------------------------------------------------------INPUT GROUP: 0 -- Input and Output File NamesSubgroup (a)------------Default Name Type File Name------------ ---- ---------GEO.DAT input ! GEODAT=GEO.DAT !SURF.DAT input ! SRFDAT=SURF2001.DAT !CLOUD.DAT input * CLDDAT= *PRECIP.DAT input ! PRCDAT=precip01.DAT !MM4.DAT input ! MM4DAT=W:\01CENRAPMM\extracted_2001_01a_epa_12km.unx !WT.DAT input * WTDAT= *CALMET.LST output ! METLST=01Met01a.LST !CALMET.DAT output ! METDAT=01MET01a.MET !PACOUT.DAT output * PACDAT= *All file names will be converted to lower case if LCFILES = TOtherwise, if LCFILES = F, file names will be converted to UPPER CASE T = lower case ! LCFILES = T ! F = UPPER CASENUMBER OF UPPER AIR & OVERWATER STATIONS: Number of upper air stations (NUSTA) No default ! NUSTA = 17 ! Number of overwater met stations (NOWSTA) No default ! NOWSTA = 12 ! !END!--------------------------------------------------------------------------------Subgroup (b)---------------------------------Upper air files (one per station)---------------------------------Default Name Type File Name------------ ---- ---------

Page 1
01Met01a.inp

UP1.DAT input 1 ! UPDAT=UPABQ01.DAT! !END!UP2.DAT input 2 ! UPDAT=UPAMA01.DAT! !END!UP3.DAT input 3 ! UPDAT=UPBMX01.DAT! !END!UP4.DAT input 4 ! UPDAT=UPBNA01.DAT! !END!UP5.DAT input 5 ! UPDAT=UPBRO01.DAT! !END!UP6.DAT input 6 ! UPDAT=UPCRP01.DAT! !END!UP7.DAT input 7 ! UPDAT=UPDDC01.DAT! !END!UP8.DAT input 8 ! UPDAT=UPDRT01.DAT! !END!UP9.DAT input 9 ! UPDAT=UPEPZ01.DAT! !END!UP10.DAT input 10 ! UPDAT=UPFWD01.DAT! !END!UP11.DAT input 11 ! UPDAT=UPJAN01.DAT! !END!UP12.DAT input 12 ! UPDAT=UPLCH01.DAT! !END!UP13.DAT input 13 ! UPDAT=UPLZK01.DAT! !END!UP14.DAT input 14 ! UPDAT=UPMAF01.DAT! !END!UP15.DAT input 15 ! UPDAT=UPOUN01.DAT! !END!UP16.DAT input 16 ! UPDAT=UPSHV01.DAT! !END!UP17.DAT input 17 ! UPDAT=UPSIL01.DAT! !END!--------------------------------------------------------------------------------Subgroup (c)-----------------------------------------Overwater station files (one per station)-----------------------------------------Default Name Type File Name------------ ---- ---------OW1.DAT input 1 ! SEADAT=42001_01_sea.dat! !END!OW2.DAT input 2 ! SEADAT=42002_01_sea.dat! !END!OW3.DAT input 3 ! SEADAT=42007_01_sea.dat! !END!OW4.DAT input 4 ! SEADAT=42019_01_sea.dat! !END!OW5.DAT input 5 ! SEADAT=42020_01_sea.dat! !END!OW6.DAT input 6 ! SEADAT=42035_01_sea.dat! !END!OW7.DAT input 7 ! SEADAT=42040_01_sea.dat! !END!OW8.DAT input 8 ! SEADAT=42045_01_sea.dat! !END!OW9.DAT input 9 ! SEADAT=42046_01_sea.dat! !END!OW10.DAT input 10 ! SEADAT=42047_01_sea.dat! !END!OW11.DAT input 11 ! SEADAT=42048_01_sea.dat! !END!OW12.DAT input 12 ! SEADAT=42049_01_sea.dat! !END!--------------------------------------------------------------------------------Subgroup (d)----------------Other file names----------------Default Name Type File Name------------ ---- ---------DIAG.DAT input * DIADAT= *PROG.DAT input * PRGDAT= *

Page 2
01Met01a.inp

TEST.PRT output * TSTPRT= *TEST.OUT output * TSTOUT= *TEST.KIN output * TSTKIN= *TEST.FRD output * TSTFRD= *TEST.SLP output * TSTSLP= *--------------------------------------------------------------------------------NOTES: (1) File/path names can be up to 70 characters in length (2) Subgroups (a) and (d) must have ONE 'END' (surround by delimiters) at the end of the group (3) Subgroups (b) and (c) must have an 'END' (surround by delimiters) at the end of EACH LINE !END!-------------------------------------------------------------------------------INPUT GROUP: 1 -- General run control parameters-------------- Starting date: Year (IBYR) -- No default ! IBYR= 2001 ! Month (IBMO) -- No default ! IBMO= 1 ! Day (IBDY) -- No default ! IBDY= 1 ! Hour (IBHR) -- No default ! IBHR= 0 ! Base time zone (IBTZ) -- No default ! IBTZ= 6 ! PST = 08, MST = 07 CST = 06, EST = 05 Length of run (hours) (IRLG) -- No default ! IRLG= 240 ! Run type (IRTYPE) -- Default: 1 ! IRTYPE= 1 ! 0 = Computes wind fields only 1 = Computes wind fields and micrometeorological variables (u*, w*, L, zi, etc.) (IRTYPE must be 1 to run CALPUFF or CALGRID) Compute special data fields required by CALGRID (i.e., 3-D fields of W wind components and temperature) in additional to regular Default: T ! LCALGRD = T ! fields ? (LCALGRD) (LCALGRD must be T to run CALGRID) Flag to stop run after

Page 3
01Met01a.inp

 SETUP phase (ITEST) Default: 2 ! ITEST= 2 ! (Used to allow checking of the model inputs, files, etc.) ITEST = 1 - STOPS program after SETUP phase ITEST = 2 - Continues with execution of COMPUTATIONAL phase after SETUP!END!-------------------------------------------------------------------------------INPUT GROUP: 2 -- Map Projection and Grid control parameters-------------- Projection for all (X,Y): ------------------------- Map projection (PMAP) Default: UTM ! PMAP = LCC ! UTM : Universal Transverse Mercator TTM : Tangential Transverse Mercator LCC : Lambert Conformal Conic PS : Polar Stereographic EM : Equatorial Mercator LAZA : Lambert Azimuthal Equal Area False Easting and Northing (km) at the projection origin (Used only if PMAP= TTM, LCC, or LAZA) (FEAST) Default=0.0 ! FEAST = 0.000 ! (FNORTH) Default=0.0 ! FNORTH = 0.000 ! UTM zone (1 to 60) (Used only if PMAP=UTM) (IUTMZN) No Default ! IUTMZN = 0 ! Hemisphere for UTM projection? (Used only if PMAP=UTM) (UTMHEM) Default: N ! UTMHEM = N ! N : Northern hemisphere projection S : Southern hemisphere projection Latitude and Longitude (decimal degrees) of projection origin (Used only if PMAP= TTM, LCC, PS, EM, or LAZA) (RLAT0) No Default ! RLAT0 = 40N ! (RLON0) No Default ! RLON0 = 97W ! TTM : RLON0 identifies central (true N/S) meridian of projection

Page 4
01Met01a.inp

 RLAT0 selected for convenience LCC : RLON0 identifies central (true N/S) meridian of projection RLAT0 selected for convenience PS : RLON0 identifies central (grid N/S) meridian of projection RLAT0 selected for convenience EM : RLON0 identifies central meridian of projection RLAT0 is REPLACED by 0.0N (Equator) LAZA: RLON0 identifies longitude of tangent-point of mapping plane RLAT0 identifies latitude of tangent-point of mapping plane Matching parallel(s) of latitude (decimal degrees) for projection (Used only if PMAP= LCC or PS) (XLAT1) No Default ! XLAT1 = 33N ! (XLAT2) No Default ! XLAT2 = 45N ! LCC : Projection cone slices through Earth's surface at XLAT1 and XLAT2 PS : Projection plane slices through Earth at XLAT1 (XLAT2 is not used) ---------- Note: Latitudes and longitudes should be positive, and include a letter N,S,E, or W indicating north or south latitude, and east or west longitude. For example, 35.9 N Latitude = 35.9N 118.7 E Longitude = 118.7E Datum-region ------------ The Datum-Region for the coordinates is identified by a character string. Many mapping products currently available use the model of the Earth known as the World Geodetic System 1984 (WGS-G ). Other local models may be in use, and their selection in CALMET will make its output consistent with local mapping products. The list of Datum-Regions with official transformation parameters is provided by the National Imagery and Mapping Agency (NIMA). NIMA Datum - Regions(Examples) ------------------------------------------------------------------------------ WGS-G WGS-84 GRS 80 Spheroid, Global coverage (WGS84) NAS-C NORTH AMERICAN 1927 Clarke 1866 Spheroid, MEAN FOR CONUS (NAD27) NWS-27 NWS 6370KM Radius, Sphere NWS-84 NWS 6370KM Radius, Sphere ESR-S ESRI REFERENCE 6371KM Radius, Sphere Datum-region for output coordinates (DATUM) Default: WGS-G ! DATUM = WGS-G !

Page 5
01Met01a.inp

 Horizontal grid definition: --------------------------- Rectangular grid defined for projection PMAP, with X the Easting and Y the Northing coordinate No. X grid cells (NX) No default ! NX = 462 ! No. Y grid cells (NY) No default ! NY = 376 ! Grid spacing (DGRIDKM) No default ! DGRIDKM = 4. ! Units: km Reference grid coordinate of SOUTHWEST corner of grid cell (1,1) X coordinate (XORIGKM) No default ! XORIGKM = -951.547 ! Y coordinate (YORIGKM) No default ! YORIGKM = -1646.637 ! Units: km Vertical grid definition: ------------------------- No. of vertical layers (NZ) No default ! NZ = 12 ! Cell face heights in arbitrary vertical grid (ZFACE(NZ+1)) No defaults Units: m ! ZFACE = 0.,20.,40.,60.,80.,100.,150.,200.,250.,500.,1000.,2000.,3500. !!END!-------------------------------------------------------------------------------INPUT GROUP: 3 -- Output Options-------------- DISK OUTPUT OPTION Save met. fields in an unformatted output file ? (LSAVE) Default: T ! LSAVE = T ! (F = Do not save, T = Save) Type of unformatted output file:

Page 6
01Met01a.inp

 (IFORMO) Default: 1 ! IFORMO = 1 ! 1 = CALPUFF/CALGRID type file (CALMET.DAT) 2 = MESOPUFF-II type file (PACOUT.DAT) LINE PRINTER OUTPUT OPTIONS: Print met. fields ? (LPRINT) Default: F ! LPRINT = T ! (F = Do not print, T = Print) (NOTE: parameters below control which met. variables are printed) Print interval (IPRINF) in hours Default: 1 ! IPRINF = 1 ! (Meteorological fields are printed every 1 hours) Specify which layers of U, V wind component to print (IUVOUT(NZ)) -- NOTE: NZ values must be entered (0=Do not print, 1=Print) (used only if LPRINT=T) Defaults: NZ*0  ! IUVOUT = 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 ! ----------------------- Specify which levels of the W wind component to print (NOTE: W defined at TOP cell face -- 12 values) (IWOUT(NZ)) -- NOTE: NZ values must be entered (0=Do not print, 1=Print) (used only if LPRINT=T & LCALGRD=T) ----------------------------------- Defaults: NZ*0  ! IWOUT = 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 ! Specify which levels of the 3-D temperature field to print (ITOUT(NZ)) -- NOTE: NZ values must be entered (0=Do not print, 1=Print) (used only if LPRINT=T & LCALGRD=T) ----------------------------------- Defaults: NZ*0  ! ITOUT = 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 ! Specify which meteorological fields to print (used only if LPRINT=T) Defaults: 0 (all variables)

Page 7
01Met01a.inp

 ----------------------- Variable Print ? (0 = do not print, 1 = print) -------- ------------------ ! STABILITY = 0 ! - PGT stability class ! USTAR = 0 ! - Friction velocity ! MONIN = 0 ! - Monin-Obukhov length ! MIXHT = 0 ! - Mixing height ! WSTAR = 0 ! - Convective velocity scale ! PRECIP = 0 ! - Precipitation rate ! SENSHEAT = 0 ! - Sensible heat flux ! CONVZI = 0 ! - Convective mixing ht. Testing and debug print options for micrometeorological module Print input meteorological data and internal variables (LDB) Default: F ! LDB = F ! (F = Do not print, T = print) (NOTE: this option produces large amounts of output) First time step for which debug data are printed (NN1) Default: 1 ! NN1 = 1 ! Last time step for which debug data are printed (NN2) Default: 1 ! NN2 = 1 ! Testing and debug print options for wind field module (all of the following print options control output to wind field module's output files: TEST.PRT, TEST.OUT, TEST.KIN, TEST.FRD, and TEST.SLP) Control variable for writing the test/debug wind fields to disk files (IOUTD) (0=Do not write, 1=write) Default: 0 ! IOUTD = 0 ! Number of levels, starting at the surface, to print (NZPRN2) Default: 1 ! NZPRN2 = 0 ! Print the INTERPOLATED wind components ? (IPR0) (0=no, 1=yes) Default: 0 ! IPR0 = 0 ! Print the TERRAIN ADJUSTED surface wind

Page 8
01Met01a.inp

 components ? (IPR1) (0=no, 1=yes) Default: 0 ! IPR1 = 0 ! Print the SMOOTHED wind components and the INITIAL DIVERGENCE fields ? (IPR2) (0=no, 1=yes) Default: 0 ! IPR2 = 0 ! Print the FINAL wind speed and direction fields ? (IPR3) (0=no, 1=yes) Default: 0 ! IPR3 = 0 ! Print the FINAL DIVERGENCE fields ? (IPR4) (0=no, 1=yes) Default: 0 ! IPR4 = 0 ! Print the winds after KINEMATIC effects are added ? (IPR5) (0=no, 1=yes) Default: 0 ! IPR5 = 0 ! Print the winds after the FROUDE NUMBER adjustment is made ? (IPR6) (0=no, 1=yes) Default: 0 ! IPR6 = 0 ! Print the winds after SLOPE FLOWS are added ? (IPR7) (0=no, 1=yes) Default: 0 ! IPR7 = 0 ! Print the FINAL wind field components ? (IPR8) (0=no, 1=yes) Default: 0 ! IPR8 = 0 !!END!-------------------------------------------------------------------------------INPUT GROUP: 4 -- Meteorological data options-------------- NO OBSERVATION MODE (NOOBS) Default: 0 ! NOOBS = 0 ! 0 = Use surface, overwater, and upper air stations 1 = Use surface and overwater stations (no upper air observations) Use MM5 for upper air data 2 = No surface, overwater, or upper air observations Use MM5 for surface, overwater, and upper air data NUMBER OF SURFACE & PRECIP. METEOROLOGICAL STATIONS Number of surface stations (NSSTA) No default ! NSSTA = 162 !

Page 9
01Met01a.inp

 Number of precipitation stations (NPSTA=-1: flag for use of MM5 precip data) (NPSTA) No default ! NPSTA = 298 ! CLOUD DATA OPTIONS Gridded cloud fields: (ICLOUD) Default: 0 ! ICLOUD = 0 ! ICLOUD = 0 - Gridded clouds not used ICLOUD = 1 - Gridded CLOUD.DAT generated as OUTPUT ICLOUD = 2 - Gridded CLOUD.DAT read as INPUT ICLOUD = 3 - Gridded cloud cover from Prognostic Rel. Humidity FILE FORMATS Surface meteorological data file format (IFORMS) Default: 2 ! IFORMS = 2 ! (1 = unformatted (e.g., SMERGE output)) (2 = formatted (free-formatted user input)) Precipitation data file format (IFORMP) Default: 2 ! IFORMP = 2 ! (1 = unformatted (e.g., PMERGE output)) (2 = formatted (free-formatted user input)) Cloud data file format (IFORMC) Default: 2 ! IFORMC = 1 ! (1 = unformatted - CALMET unformatted output) (2 = formatted - free-formatted CALMET output or user input)!END!-------------------------------------------------------------------------------INPUT GROUP: 5 -- Wind Field Options and Parameters-------------- WIND FIELD MODEL OPTIONS Model selection variable (IWFCOD) Default: 1 ! IWFCOD = 1 ! 0 = Objective analysis only 1 = Diagnostic wind module Compute Froude number adjustment effects ? (IFRADJ) Default: 1 ! IFRADJ = 1 ! (0 = NO, 1 = YES) Compute kinematic effects ? (IKINE) Default: 0 ! IKINE = 0 !

Page 10
01Met01a.inp

 (0 = NO, 1 = YES) Use O'Brien procedure for adjustment of the vertical velocity ? (IOBR) Default: 0 ! IOBR = 0 ! (0 = NO, 1 = YES) Compute slope flow effects ? (ISLOPE) Default: 1 ! ISLOPE = 1 ! (0 = NO, 1 = YES) Extrapolate surface wind observations to upper layers ? (IEXTRP) Default: -4 ! IEXTRP = -4 ! (1 = no extrapolation is done, 2 = power law extrapolation used, 3 = user input multiplicative factors for layers 2 - NZ used (see FEXTRP array) 4 = similarity theory used -1, -2, -3, -4 = same as above except layer 1 data at upper air stations are ignored Extrapolate surface winds even if calm? (ICALM) Default: 0 ! ICALM = 0 ! (0 = NO, 1 = YES) Layer-dependent biases modifying the weights of surface and upper air stations (BIAS(NZ)) -1<=BIAS<=1 Negative BIAS reduces the weight of upper air stations (e.g. BIAS=-0.1 reduces the weight of upper air stations by 10%; BIAS= -1, reduces their weight by 100 %) Positive BIAS reduces the weight of surface stations (e.g. BIAS= 0.2 reduces the weight of surface stations by 20%; BIAS=1 reduces their weight by 100%) Zero BIAS leaves weights unchanged (1/R**2 interpolation) Default: NZ*0 ! BIAS = 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 , 0 ,  Minimum distance from nearest upper air station to surface station for which extrapolation of surface winds at surface station will be allowed (RMIN2: Set to -1 for IEXTRP = 4 or other situations where all surface stations should be extrapolated) Default: 4. ! RMIN2 = -1.0 ! Use gridded prognostic wind field model output fields as input to the diagnostic wind field model (IPROG) Default: 0 ! IPROG = 14 ! (0 = No, [IWFCOD = 0 or 1] 1 = Yes, use CSUMM prog. winds as Step 1 field, [IWFCOD = 0]

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 2 = Yes, use CSUMM prog. winds as initial guess field [IWFCOD = 1] 3 = Yes, use winds from MM4.DAT file as Step 1 field [IWFCOD = 0] 4 = Yes, use winds from MM4.DAT file as initial guess field [IWFCOD = 1] 5 = Yes, use winds from MM4.DAT file as observations [IWFCOD = 1] 13 = Yes, use winds from MM5.DAT file as Step 1 field [IWFCOD = 0] 14 = Yes, use winds from MM5.DAT file as initial guess field [IWFCOD = 1] 15 = Yes, use winds from MM5.DAT file as observations [IWFCOD = 1] Timestep (hours) of the prognostic model input data (ISTEPPG) Default: 1 ! ISTEPPG = 1 ! RADIUS OF INFLUENCE PARAMETERS Use varying radius of influence Default: F ! LVARY = T! (if no stations are found within RMAX1,RMAX2, or RMAX3, then the closest station will be used) Maximum radius of influence over land in the surface layer (RMAX1) No default ! RMAX1 = 20. ! Units: km Maximum radius of influence over land aloft (RMAX2) No default ! RMAX2 = 50. ! Units: km Maximum radius of influence over water (RMAX3) No default ! RMAX3 = 500. ! Units: km OTHER WIND FIELD INPUT PARAMETERS Minimum radius of influence used in the wind field interpolation (RMIN) Default: 0.1 ! RMIN = 0.1 ! Units: km Radius of influence of terrain features (TERRAD) No default ! TERRAD = 10. ! Units: km Relative weighting of the first guess field and observations in the SURFACE layer (R1) No default ! R1 = 10. ! (R1 is the distance from an Units: km observational station at which the observation and first guess field are equally weighted) Relative weighting of the first guess field and observations in the layers ALOFT (R2) No default ! R2 = 25. !

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 (R2 is applied in the upper layers Units: km in the same manner as R1 is used in the surface layer). Relative weighting parameter of the prognostic wind field data (RPROG) No default ! RPROG = 54. ! (Used only if IPROG = 1) Units: km ------------------------ Maximum acceptable divergence in the divergence minimization procedure (DIVLIM) Default: 5.E-6 ! DIVLIM= 5.0E-06 ! Maximum number of iterations in the divergence min. procedure (NITER) Default: 50 ! NITER = 50 ! Number of passes in the smoothing procedure (NSMTH(NZ)) NOTE: NZ values must be entered Default: 2,(mxnz-1)*4 ! NSMTH =  2 , 4 , 4 , 4 , 4 , 4 , 4 , 4 , 4 , 4 , 4 , 4 ! Maximum number of stations used in each layer for the interpolation of data to a grid point (NINTR2(NZ)) NOTE: NZ values must be entered Default: 99. ! NINTR2 =  99 , 99 , 99 , 99 , 99 , 99 , 99 , 99 , 99 , 99 , 99 , 99 ! Critical Froude number (CRITFN) Default: 1.0 ! CRITFN = 1. ! Empirical factor controlling the influence of kinematic effects (ALPHA) Default: 0.1 ! ALPHA = 0.1 ! Multiplicative scaling factor for extrapolation of surface observations to upper layers (FEXTR2(NZ)) Default: NZ*0.0  ! FEXTR2 = 0., 0., 0., 0., 0., 0., 0., 0., 0., 0., 0., 0. ! (Used only if IEXTRP = 3 or -3) BARRIER INFORMATION Number of barriers to interpolation of the wind fields (NBAR) Default: 0 ! NBAR = 0 ! THE FOLLOWING 4 VARIABLES ARE INCLUDED ONLY IF NBAR > 0

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 NOTE: NBAR values must be entered No defaults for each variable Units: km X coordinate of BEGINNING of each barrier (XBBAR(NBAR)) ! XBBAR = 0. ! Y coordinate of BEGINNING of each barrier (YBBAR(NBAR)) ! YBBAR = 0. ! X coordinate of ENDING of each barrier (XEBAR(NBAR)) ! XEBAR = 0. ! Y coordinate of ENDING of each barrier (YEBAR(NBAR)) ! YEBAR = 0. ! DIAGNOSTIC MODULE DATA INPUT OPTIONS Surface temperature (IDIOPT1) Default: 0 ! IDIOPT1 = 0 ! 0 = Compute internally from hourly surface observations 1 = Read preprocessed values from a data file (DIAG.DAT) Surface met. station to use for the surface temperature (ISURFT) No default ! ISURFT = 64 ! (Must be a value from 1 to NSSTA) (Used only if IDIOPT1 = 0) -------------------------- Domain-averaged temperature lapse rate (IDIOPT2) Default: 0 ! IDIOPT2 = 0 ! 0 = Compute internally from twice-daily upper air observations 1 = Read hourly preprocessed values from a data file (DIAG.DAT) Upper air station to use for the domain-scale lapse rate (IUPT) No default ! IUPT = 10 ! (Must be a value from 1 to NUSTA) (Used only if IDIOPT2 = 0) -------------------------- Depth through which the domain-scale lapse rate is computed (ZUPT) Default: 200. ! ZUPT = 200. ! (Used only if IDIOPT2 = 0) Units: meters -------------------------- Domain-averaged wind components (IDIOPT3) Default: 0 ! IDIOPT3 = 0 !

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 0 = Compute internally from twice-daily upper air observations 1 = Read hourly preprocessed values a data file (DIAG.DAT) Upper air station to use for the domain-scale winds (IUPWND) Default: -1 ! IUPWND = -1 ! (Must be a value from -1 to NUSTA) (Used only if IDIOPT3 = 0) -------------------------- Bottom and top of layer through which the domain-scale winds are computed (ZUPWND(1), ZUPWND(2)) Defaults: 1., 1000. ! ZUPWND= 1., 2000. ! (Used only if IDIOPT3 = 0) Units: meters -------------------------- Observed surface wind components for wind field module (IDIOPT4) Default: 0 ! IDIOPT4 = 0 ! 0 = Read WS, WD from a surface data file (SURF.DAT) 1 = Read hourly preprocessed U, V from a data file (DIAG.DAT) Observed upper air wind components for wind field module (IDIOPT5) Default: 0 ! IDIOPT5 = 0 ! 0 = Read WS, WD from an upper air data file (UP1.DAT, UP2.DAT, etc.) 1 = Read hourly preprocessed U, V from a data file (DIAG.DAT) LAKE BREEZE INFORMATION Use Lake Breeze Module (LLBREZE) Default: F ! LLBREZE = F ! Number of lake breeze regions (NBOX) ! NBOX = 0 ! X Grid line 1 defining the region of interest ! XG1 = 0. ! X Grid line 2 defining the region of interest ! XG2 = 0. ! Y Grid line 1 defining the region of interest ! YG1 = 0. ! Y Grid line 2 defining the region of interest ! YG2 = 0. !

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 X Point defining the coastline (Straight line) (XBCST) (KM) Default: none ! XBCST = 0. ! Y Point defining the coastline (Straight line) (YBCST) (KM) Default: none ! YBCST = 0. ! X Point defining the coastline (Straight line) (XECST) (KM) Default: none ! XECST = 0. ! Y Point defining the coastline (Straight line) (YECST) (KM) Default: none ! YECST = 0. ! Number of stations in the region Default: none ! NLB = 0 !  (Surface stations + upper air stations) Station ID's in the region (METBXID(NLB)) (Surface stations first, then upper air stations) ! METBXID = 0 !!END!-------------------------------------------------------------------------------INPUT GROUP: 6 -- Mixing Height, Temperature and Precipitation Parameters-------------- EMPIRICAL MIXING HEIGHT CONSTANTS Neutral, mechanical equation (CONSTB) Default: 1.41 ! CONSTB = 1.41 ! Convective mixing ht. equation (CONSTE) Default: 0.15 ! CONSTE = 0.15 ! Stable mixing ht. equation (CONSTN) Default: 2400. ! CONSTN = 2400.! Overwater mixing ht. equation (CONSTW) Default: 0.16 ! CONSTW = 0.16 ! Absolute value of Coriolis parameter (FCORIOL) Default: 1.E-4 ! FCORIOL = 1.0E-04! Units: (1/s) SPATIAL AVERAGING OF MIXING HEIGHTS Conduct spatial averaging (IAVEZI) (0=no, 1=yes) Default: 1 ! IAVEZI = 1 ! Max. search radius in averaging

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 process (MNMDAV) Default: 1 ! MNMDAV = 1 ! Units: Grid cells Half-angle of upwind looking cone for averaging (HAFANG) Default: 30. ! HAFANG = 30. ! Units: deg. Layer of winds used in upwind averaging (ILEVZI) Default: 1 ! ILEVZI = 1 ! (must be between 1 and NZ) OTHER MIXING HEIGHT VARIABLES Minimum potential temperature lapse rate in the stable layer above the current convective mixing ht. Default: 0.001 ! DPTMIN = 0.001 ! (DPTMIN) Units: deg. K/m Depth of layer above current conv. mixing height through which lapse Default: 200. ! DZZI = 200. ! rate is computed (DZZI) Units: meters Minimum overland mixing height Default: 50. ! ZIMIN = 20. ! (ZIMIN) Units: meters Maximum overland mixing height Default: 3000. ! ZIMAX = 3500. ! (ZIMAX) Units: meters Minimum overwater mixing height Default: 50. ! ZIMINW = 20. ! (ZIMINW) -- (Not used if observed Units: meters overwater mixing hts. are used) Maximum overwater mixing height Default: 3000. ! ZIMAXW = 3500. ! (ZIMAXW) -- (Not used if observed Units: meters overwater mixing hts. are used) TEMPERATURE PARAMETERS 3D temperature from observations or from prognostic data? (ITPROG) Default:0 !ITPROG = 0 ! 0 = Use Surface and upper air stations (only if NOOBS = 0) 1 = Use Surface stations (no upper air observations) Use MM5 for upper air data (only if NOOBS = 0,1) 2 = No surface or upper air observations Use MM5 for surface and upper air data (only if NOOBS = 0,1,2) Interpolation type (1 = 1/R ; 2 = 1/R**2) Default:1 ! IRAD = 1 !

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 Radius of influence for temperature interpolation (TRADKM) Default: 500. ! TRADKM = 500. ! Units: km Maximum Number of stations to include in temperature interpolation (NUMTS) Default: 5 ! NUMTS = 5 ! Conduct spatial averaging of temp- eratures (IAVET) (0=no, 1=yes) Default: 1 ! IAVET = 1 ! (will use mixing ht MNMDAV,HAFANG so make sure they are correct) Default temperature gradient Default: -.0098 ! TGDEFB = -0.0098 ! below the mixing height over water (K/m) (TGDEFB) Default temperature gradient Default: -.0045 ! TGDEFA = -0.0045 ! above the mixing height over water (K/m) (TGDEFA) Beginning (JWAT1) and ending (JWAT2) land use categories for temperature ! JWAT1 = 55 ! interpolation over water -- Make ! JWAT2 = 55 ! bigger than largest land use to disable PRECIP INTERPOLATION PARAMETERS Method of interpolation (NFLAGP) Default = 2 ! NFLAGP = 2 ! (1=1/R,2=1/R**2,3=EXP/R**2) Radius of Influence (km) (SIGMAP) Default = 100.0 ! SIGMAP = 100. ! (0.0 => use half dist. btwn nearest stns w & w/out precip when NFLAGP = 3) Minimum Precip. Rate Cutoff (mm/hr) Default = 0.01 ! CUTP = 0.01 ! (values < CUTP = 0.0 mm/hr)!END!-------------------------------------------------------------------------------INPUT GROUP: 7 -- Surface meteorological station parameters-------------- SURFACE STATION VARIABLES (One record per station -- 15 records in all)

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 1 2 Name ID X coord. Y coord. Time Anem. (km) (km) zone Ht.(m) ----------------------------------------------------------! SS1 ='KDYS' 69019 -267.672 -834.095 6 4 !! SS2 ='KNPA' 72222 932.565 -1020.909 6 10 !! SS3 ='KBFM' 72223 857.471 -996.829 6 10 !! SS4 ='KGZH' 72227 946.767 -899.515 6 10 !! SS5 ='KTCL' 72228 870.843 -706.104 6 10 !! SS6 ='KNEW' 53917 674.172 -1078.342 6 8 !! SS7 ='KNBG' 12958 677.719 -1104.227 6 10 !! SS8 ='BVE ' 12884 741.996 -1153.463 6 10 !! SS9 ='KPTN' 72232 550.88 -1124.295 6 10 !! SS10 ='KMEI' 13865 774.911 -814.225 6 10 !! SS11 ='KPIB' 72234 728.416 -915.165 6 10 !! SS12 ='KGLH' 72235 557.072 -703.097 6 6 !! SS13 ='KHEZ' 11111 540.777 -912.22 6 10 !! SS14 ='KMCB' 11112 622.755 -949.618 6 10 !! SS15 ='KGWO' 11113 640.102 -695.286 6 10 !! SS16 ='KASD' 72236 692.381 -1043.261 6 10 !! SS17 ='KPOE' 72239 363.294 -984.839 6 4 !! SS18 ='KBAZ' 72241 -102.133 -1140.886 6 10 !! SS19 ='KGLS' 72242 215.108 -1185.604 6 8 !! SS20 ='KDWH' 11114 140.413 -1101.174 6 10 !! SS21 ='KIAH' 12960 158.266 -1108.37 6 10 !! SS22 ='KHOU' 72243 167.147 -1147.402 6 10 !! SS23 ='KEFD' 12906 178.551 -1152.782 6 4 !! SS24 ='KCXO' 72244 152.739 -1069.309 6 10 !! SS25 ='KCLL' 11115 60.898 -1044.381 6 8 !! SS26 ='KLFK' 93987 214.643 -969.355 6 8 !! SS27 ='KUTS' 11116 136.056 -1026.773 6 10 !! SS28 ='KTYR' 11117 150.451 -846.207 6 10 !! SS29 ='KCRS' 72246 56.655 -882.642 6 10 !! SS30 ='KGGG' 72247 214.572 -841.163 6 10 !! SS31 ='KGKY' 11118 -9.365 -812.25 6 10 !! SS32 ='KDTN' 72248 304.827 -821.713 6 10 !! SS33 ='KBAD' 11119 312.743 -825.101 6 4 !! SS34 ='KMLU' 11120 465.834 -816.211 6 10 !! SS35 ='KTVR' 11121 561.446 -840.225 6 10 !! SS36 ='KTRL' 11122 68.599 -806.417 6 10 !! SS37 ='KOCH' 72249 216.81 -930.252 6 10 !! SS38 ='KBRO' 12919 -44.167 -1571.387 6 10 !! SS39 ='KALI' 72251 -103.012 -1363.74 6 10 !! SS40 ='KLRD' 12920 -246.548 -1381.603 6 5 !! SS41 ='KSSF' 72252 -143.386 -1183.35 6 10 !! SS42 ='KRKP' 11123 -4.965 -1324.914 6 10 !! SS43 ='KCOT' 11124 -219.097 -1280.964 6 10 !! SS44 ='KLBX' 11125 150.245 -1207.466 6 10 !

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! SS45 ='KSAT' 12921 -143.024 -1160.935 6 10 !! SS46 ='KHDO' 12962 -211.702 -1178.172 6 10 !! SS47 ='KSKF' 72253 -154.625 -1177.555 6 4 !! SS48 ='KHYI' 11126 -84.156 -1122.487 6 10 !! SS49 ='KTKI' 72254 38.788 -754.791 6 10 !! SS50 ='KBMQ' 11127 -118.39 -1027.031 6 10 !! SS51 ='KATT' 11128 -67.587 -1075.97 6 10 !! SS52 ='KSGR' 11129 131.478 -1151.702 6 10 !! SS53 ='KGTU' 11130 -65.624 -1033.173 6 10 !! SS54 ='KVCT' 12912 6.587 -1236.788 6 10 !! SS55 ='KPSX' 72255 73.878 -1253.33 6 10 !! SS56 ='KACT' 13959 -22.12 -929.156 6 10 !! SS57 ='KPWG' 72256 -30.147 -944.073 6 10 !! SS58 ='KILE' 72257 -65.288 -988.507 6 10 !! SS59 ='KGRK' 11131 -79.643 -990.173 6 5 !! SS60 ='KTPL' 11132 -38.203 -981.19 6 10 !! SS61 ='KDAL' 13960 14.014 -791.89 6 10 !! SS62 ='KPRX' 72258 143.317 -703.663 6 10 !! SS63 ='KDTO' 11133 -17.018 -752.974 6 10 !! SS64 ='KAFW' 72259 -29.564 -777.061 6 10 !! SS65 ='KFTW' 11134 -34.302 -795.502 6 8 !! SS66 ='KMWL' 11135 -99.769 -798.767 6 10 !! SS67 ='KRBD' 11136 12.453 -810.467 6 10 !! SS68 ='KDRT' 22010 -384.069 -1170.59 6 7 !! SS69 ='KFST' 72261 -566.418 -988.838 6 10 !! SS70 ='KGDP' 72262 -739.127 -873.302 6 10 !! SS71 ='KSJT' 23034 -333.338 -952.54 6 10 !! SS72 ='KMRF' 72264 -676.265 -1042.616 6 10 !! SS73 ='KMAF' 23023 -489.668 -878.107 6 8 !! SS74 ='KINK' 72265 -586.882 -890.654 6 10 !! SS75 ='KABI' 13962 -252.044 -836.353 6 10 !! SS76 ='KATS' 11137 -696.818 -763.258 7 21 !! SS77 ='KCQC' 11138 -785.757 -515.724 7 10 !! SS78 ='KROW' 23009 -698.822 -712.898 7 8 !! SS79 ='KSRR' 72268 -789.593 -686.226 7 11 !! SS80 ='KCNM' 11139 -682.79 -822.109 7 10 !! SS81 ='KALM' 36870 -838.056 -752.338 7 7 !! SS82 ='KLRU' 72269 -931.527 -804.112 7 8 !! SS83 ='KTCS' 72271 -952.353 -695.469 7 10 !! SS84 ='KSVC' 93063 -1042.029 -752.033 7 10 !! SS85 ='KDMN' 72272 -1006.77 -799.231 7 10 !! SS86 ='KMSL' 72323 854.846 -536.687 6 10 !! SS87 ='KPOF' 72330 578.62 -336.733 6 8 !! SS88 ='KGTR' 11140 779.065 -689.108 6 10 !! SS89 ='KTUP' 93862 753.875 -600.337 6 10 !! SS90 ='KMKL' 72334 727.051 -454.383 6 10 !! SS91 ='KLRF' 72340 440.654 -550.661 6 10 !! SS92 ='KHKA' 11141 643.365 -424.419 6 10 !

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! SS93 ='KHOT' 72341 358.094 -604.603 6 8 !! SS94 ='KTXK' 11142 278.022 -720.623 6 8 !! SS95 ='KLLQ' 72342 488.655 -698.008 6 10 !! SS96 ='KMWT' 72343 254.18 -599.224 6 10 !! SS97 ='KFSM' 13964 237.97 -512.87 6 10 !! SS98 ='KSLG' 72344 224.881 -419.064 6 10 !! SS99 ='KVBT' 11143 248.074 -399.892 6 10 !! SS100='KHRO' 11144 343.525 -405.601 6 8 !! SS101='KFLP' 11145 404.239 -399.142 6 10 !! SS102='KBVX' 11146 480.712 -457.853 6 10 !! SS103='KROG' 11147 258.44 -397.685 6 10 !! SS104='KSPS' 13966 -138.053 -664.886 6 10 !! SS105='KHBR' 72352 -186.121 -551.123 6 10 !! SS106='KCSM' 11148 -198.844 -513.911 6 10 !! SS107='KFDR' 11149 -181.653 -625.205 6 10 !! SS108='KGOK' 72353 -35.905 -458.97 6 10 !! SS109='KTIK' 72354 -34.581 -506.938 6 5 !! SS110='KPWA' 11150 -58.596 -493.951 6 8 !! SS111='KSWO' 11151 -7.42 -425.828 6 10 !! SS112='KMKO' 72355 146.972 -479.879 6 10 !! SS113='KRVS' 72356 91.059 -438.276 6 10 !! SS114='KBVO' 11152 87.136 -357.069 6 9 !! SS115='KMLC' 11153 110.647 -563.566 6 10 !! SS116='KOUN' 72357 -40.731 -527.298 6 10 !! SS117='KLAW' 11154 -129.405 -600.222 6 10 !! SS118='KCDS' 72360 -300.297 -610.668 6 10 !! SS119='KGNT' 72362 -985.117 -475.563 6 10 !! SS120='KGUP' 11155 -1059.475 -427.151 6 10 !! SS121='KAMA' 23047 -425.319 -518.171 6 10 !! SS122='KBGD' 72363 -395.603 -466.083 6 10 !! SS123='KFMN' 72365 -993.449 -297.944 7 10 !! SS124='KSKX' 72366 -770.464 -355.855 7 10 !! SS125='KTCC' 23048 -597.271 -511.241 7 10 !! SS126='KLVS' 23054 -732.565 -448.329 7 10 !! SS127='KEHR' 72423 812.573 -199.695 6 10 !! SS128='KEVV' 93817 822.929 -172.715 6 10 !! SS129='KMVN' 72433 704.666 -154.54 6 7 !! SS130='KMDH' 11156 676.745 -218.041 6 11 !! SS131='KBLV' 11157 617.659 -136.018 6 4 !! SS132='KSUS' 3966 547.898 -130.122 6 10 !! SS133='KPAH' 3816 725.985 -293.319 6 10 !! SS134='KJEF' 72445 419.01 -145.496 6 10 !! SS135='KAIZ' 11158 387.096 -200.609 6 10 !! SS136='KIXD' 72447 182.322 -126.913 6 10 !! SS137='KWLD' 72450 0 -298.57 6 10 !! SS138='KAAO' 11159 -18.976 -248.773 6 10 !! SS139='KIAB' 11160 -23.392 -263.471 6 10 !! SS140='KEWK' 11161 -24.645 -215.58 6 10 !

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! SS141='KGBD' 72451 -161.892 -180.781 6 11 !! SS142='KHYS' 11162 -195.191 -124.723 6 10 !! SS143='KCFV' 11163 126.442 -319.698 6 10 !! SS144='KFOE' 72456 114.618 -115.26 6 10 !! SS145='KEHA' 72460 -432.761 -320.089 6 10 !! SS146='KALS' 72462 -777.592 -245.892 7 10 !! SS147='KDRO' 11164 -945.713 -259.163 7 10 !! SS148='KLHX' 72463 -568.426 -195.178 7 10 !! SS149='KSPD' 2128 -494.076 -285.176 7 10 !! SS150='KCOS' 93037 -664.022 -102.596 7 10 !! SS151='KGUC' 72467 -857.452 -115.301 7 10 !! SS152='KMTJ' 93013 -940.981 -109.358 7 10 !! SS153='KCEZ' 72476 -1020.867 -233.14 7 10 !! SS154='KCPS' 72531 591.652 -136.14 6 10 !! SS155='KLWV' 72534 808.939 -94.46 6 10 !! SS156='KPPF' 74543 130.433 -293.855 6 10 !! SS157='KHOP' 74671 841.751 -324.569 6 3 !! SS158='KBIX' 74768 778.252 -1028.514 6 15 !! SS159='KPQL' 11165 814.599 -1019.583 6 10 !! SS160='MMPG' 76243 -348.007 -1248.779 6 10 !! SS161='MMMV' 76342 -446.576 -1449.334 6 10 !! SS162='MMMY' 76394 -316.664 -1581.176 6 10 !! END !------------------- 1 Four character string for station name (MUST START IN COLUMN 9) 2 Five digit integer for station ID!END!-------------------------------------------------------------------------------INPUT GROUP: 8 -- Upper air meteorological station parameters-------------- UPPER AIR STATION VARIABLES (One record per station -- 2 records in all) 1 2 Name ID X coord. Y coord. Time zone (km) (km)  -----------------------------------------------

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! US1 ='KABQ' 23050 -869.46 -501.713 7 !! US2 ='KAMA' 23047 -425.319 -518.171 6 !! US3 ='KBMX' 53823 951.609 -702.935 6 !! US4 ='KBNA' 13897 920.739 -377.164 6 !! US5 ='KBRO' 12919 -44.167 -1571.387 6 !! US6 ='KCRP' 12924 -51.535 -1360.349 6 !! US7 ='KDDC' 13985 -259.352 -242.681 6 !! US8 ='KDRT' 22010 -384.069 -1170.59 6 !! US9 ='KEPZ' 3020 -914.558 -852.552 7 !! US10 ='KFWD' 3990 -28.034 -793.745 6 !! US11 ='KJAN' 3940 650.105 -826.452 6 !! US12 ='KLCH' 3937 364.461 -1089.145 6 !! US13 ='KLZK' 3952 432.063 -560.441 6 !! US14 ='KMAF' 23023 -489.668 -878.107 6 !! US15 ='KOUN' 3948 -40.731 -527.298 6 !! US16 ='KSHV' 13957 298.869 -831.166 6 !! US17 ='KSIL' 53813 698.079 -1054.027 6 !! END !------------------- 1 Four character string for station name (MUST START IN COLUMN 9) 2 Five digit integer for station ID!END!-------------------------------------------------------------------------------INPUT GROUP: 9 -- Precipitation station parameters-------------- PRECIPITATION STATION VARIABLES (One record per station -- 2 records in all) (NOT INCLUDED IF NPSTA = 0) 1 2 Name Station X coord. Y coord. Code (km) (km) ------------------------------------! PS1 ='ADDI' 10063 901.489 -592.955 !! PS2 ='ALBE' 10140 899.884 -812.458 !! PS3 ='BERR' 10748 867.154 -661.971 !! PS4 ='HALE' 13620 857.62 -594.261 !! PS5 ='HAMT' 13645 826.544 -612.409 !

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! PS6 ='JACK' 14193 860.868 -896.436 !! PS7 ='MBLE' 15478 839.791 -992.343 !! PS8 ='MUSC' 15749 854.937 -537.327 !! PS9 ='PETE' 16370 922.473 -882.847 !! PS10 ='THOM' 18178 864.891 -894.227 !! PS11 ='TUSC' 18385 873.09 -706.684 !! PS12 ='VERN' 18517 817.964 -653.134 !! PS13 ='BEEB' 30530 462.78 -533.08 !! PS14 ='BRIG' 30900 318.637 -553.97 !! PS15 ='CALI' 31140 419.129 -730.939 !! PS16 ='CAMD' 31152 386.263 -700.784 !! PS17 ='DIER' 32020 267.307 -643.487 !! PS18 ='EURE' 32356 285.714 -391.299 !! PS19 ='GILB' 32794 383.775 -434.343 !! PS20 ='GREE' 32978 450.616 -483.139 !! PS21 ='STUT' 36920 510.166 -595.821 !! PS22 ='TEXA' 37048 277.314 -720.245 !! PS23 ='ALAM' 50130 -777.038 -245.291 !! PS24 ='ARAP' 50304 -445.453 -114.1 !! PS25 ='COCH' 51713 -843.702 -126.461 !! PS26 ='CRES' 51959 -856.972 -76.909 !! PS27 ='GRAN' 53477 -462.184 -201.033 !! PS28 ='GUNN' 53662 -860.363 -115.346 !! PS29 ='HUGO' 54172 -556.037 -74.8 !! PS30 ='JOHN' 54388 -515.918 -197.306 !! PS31 ='KIM ' 54538 -554.68 -262.307 !! PS32 ='MESA' 55531 -1009.654 -245.882 !! PS33 ='ORDW' 56136 -579.524 -141.149 !! PS34 ='OURA' 56203 -927.308 -164.38 !! PS35 ='PLEA' 56591 -1029.946 -199.897 !! PS36 ='PUEB' 56740 -650.053 -162.245 !! PS37 ='TYE ' 57320 -690.994 -182.032 !! PS38 ='SAGU' 57337 -793.779 -171.571 !! PS39 ='SANL' 57428 -740.179 -277.141 !! PS40 ='SHEP' 57572 -719.528 -220.042 !! PS41 ='TELL' 58204 -945.961 -170.11 !! PS42 ='TERC' 58220 -710.321 -292.412 !! PS43 ='TRIN' 58429 -659.183 -284.829 !! PS44 ='TRLK' 58436 -665.568 -287.445 !! PS45 ='WALS' 58781 -680.162 -233.45 !! PS46 ='WHIT' 58997 -620.426 -211.536 !! PS47 ='ASHL' 110281 677.366 -155.437 !! PS48 ='CAIR' 111166 689.241 -297.405 !! PS49 ='CARM' 111302 766.305 -175.312 !! PS50 ='CISN' 111664 742.235 -130.227 !! PS51 ='FLOR' 113109 725.194 -108.412 !! PS52 ='HARR' 113879 740.195 -215.267 !! PS53 ='KASK' 114629 613.959 -199.069 !

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01Met01a.inp

! PS54 ='LAWR' 114957 801.433 -99.657 !! PS55 ='MTCA' 115888 799.41 -135.062 !! PS56 ='MURP' 115983 666.735 -219.575 !! PS57 ='NEWT' 116159 762.897 -82.814 !! PS58 ='REND' 117187 696.872 -185.925 !! PS59 ='SMIT' 118020 754.325 -277.976 !! PS60 ='SPAR' 118147 632.989 -182.867 !! PS61 ='VAND' 118781 678.924 -84.301 !! PS62 ='WEST' 119193 775.327 -124.149 !! PS63 ='EVAN' 122738 824.11 -173.364 !! PS64 ='NEWB' 126151 838.034 -184.189 !! PS65 ='PRIN' 127125 814.415 -139.507 !! PS66 ='STEN' 128442 852.345 -145.206 !! PS67 ='JTML' 128967 785.86 -204.812 !! PS68 ='ARLI' 140326 -110.926 -231.799 !! PS69 ='BAZI' 140620 -238.84 -188.104 !! PS70 ='BEAU' 140637 40.693 -259.137 !! PS71 ='BONN' 140957 180.603 -101.448 !! PS72 ='CALD' 141233 -54.366 -327.856 !! PS73 ='CASS' 141351 31.591 -215.278 !! PS74 ='CENT' 141404 167.504 -197.961 !! PS75 ='CHAN' 141427 132.698 -256.506 !! PS76 ='CLIN' 141612 142.776 -115.841 !! PS77 ='COLL' 141730 -267.979 -117.405 !! PS78 ='COLU' 141740 189.045 -311.581 !! PS79 ='CONC' 141867 40.931 -146.37 !! PS80 ='DODG' 142164 -259.414 -242.501 !! PS81 ='ELKH' 142432 -431.524 -319.478 !! PS82 ='ENGL' 142560 -264.379 -322.362 !! PS83 ='ERIE' 142582 153.917 -265.803 !! PS84 ='FALL' 142686 80.834 -259.783 !! PS85 ='GALA' 142938 -170.268 -147.301 !! PS86 ='GARD' 142980 -332.149 -214.978 !! PS87 ='GREN' 143248 48.554 -292 !! PS88 ='HAYS' 143527 -201.021 -123.653 !! PS89 ='HEAL' 143554 -312.756 -148.447 !! PS90 ='HILL' 143686 182.105 -145.591 !! PS91 ='INDE' 143954 114.638 -304.755 !! PS92 ='IOLA' 143984 137.393 -228.466 !! PS93 ='JOHR' 144104 108.586 -192.14 !! PS94 ='KANO' 144178 -82.923 -153.502 !! PS95 ='KIOW' 144341 -131.156 -328.843 !! PS96 ='MARI' 145039 -6.525 -179.369 !! PS97 ='MELV' 145210 112.198 -164.627 !! PS98 ='MILF' 145306 9.466 -102.305 !! PS99 ='MOUD' 145536 136.55 -309.82 !! PS100='OAKL' 145888 -338.36 -90.757 !! PS101='OTTA' 146128 148.524 -151.952 !

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01Met01a.inp

! PS102='POMO' 146498 123.872 -148.785 !! PS103='SALI' 147160 -56.156 -132.792 !! PS104='SMOL' 147551 -57.589 -138.771 !! PS105='STAN' 147756 201.192 -129.364 !! PS106='SUBL' 147922 -337.056 -271.996 !! PS107='TOPE' 148167 116.838 -102.08 !! PS108='TRIB' 148235 -413.288 -158.742 !! PS109='UNIO' 148293 176.609 -236.016 !! PS110='WALL' 148535 -394.195 -111.564 !! PS111='WICH' 148830 -38.795 -259.177 !! PS112='WILS' 148946 -127.991 -113.209 !! PS113='BENT' 150611 765.835 -310.871 !! PS114='CALH' 151227 852.121 -227.267 !! PS115='CLTN' 151631 713.076 -341.509 !! PS116='HERN' 153798 835.039 -324.875 !! PS117='MADI' 155067 831.766 -250.005 !! PS118='PADU' 156110 725.315 -292.67 !! PS119='PCTN' 156580 804.246 -277.545 !! PS120='ALEX' 160103 433.936 -959.371 !! PS121='BATN' 160549 563.036 -1031.572 !! PS122='CALH' 161411 436.36 -818.181 !! PS123='CLNT' 161899 577.635 -999.204 !! PS124='JENA' 164696 455.137 -911.689 !! PS125='LACM' 165078 364.877 -1088.263 !! PS126='MIND' 166244 347.179 -812.044 !! PS127='MONR' 166314 462.55 -814.477 !! PS128='NATC' 166582 369.813 -903.938 !! PS129='SHRE' 168440 298.233 -831.498 !! PS130='WINN' 169803 409.193 -884.925 !! PS131='BROK' 221094 621.134 -914.907 !! PS132='CONE' 221900 725.078 -804.862 !! PS133='JAKS' 224472 650.598 -826.11 !! PS134='LEAK' 224966 805.886 -943.78 !! PS135='MERI' 225776 775.44 -813.985 !! PS136='SARD' 227815 659.252 -594.021 !! PS137='SAUC' 227840 763.366 -1005.558 !! PS138='TUPE' 229003 753.481 -600.441 !! PS139='ADVA' 230022 625.39 -296.764 !! PS140='ALEY' 230088 489.607 -299.884 !! PS141='BOLI' 230789 316.095 -257.265 !! PS142='CASV' 231383 278.848 -363.145 !! PS143='CLER' 231674 548.572 -298.367 !! PS144='CLTT' 231711 279.768 -172.497 !! PS145='COLU' 231791 411.752 -119.977 !! PS146='DREX' 232331 206.841 -165.718 !! PS147='ELM ' 232568 255.182 -120.998 !! PS148='FULT' 233079 436.302 -114.093 !! PS149='HOME' 233999 616.121 -414.248 !

Page 26
01Met01a.inp

! PS150='JEFF' 234271 416.131 -145.612 !! PS151='JOPL' 234315 220.234 -312.505 !! PS152='LEBA' 234825 376.787 -247.055 !! PS153='LICK' 234919 448.45 -257.796 !! PS154='LOCK' 235027 268.099 -284.021 !! PS155='MALD' 235207 622.264 -352.069 !! PS156='MARS' 235298 323.881 -89.005 !! PS157='MAFD' 235307 359.618 -286.265 !! PS158='MCES' 235415 438.31 -103.798 !! PS159='MILL' 235594 279.592 -303.243 !! PS160='MTGV' 235834 417.444 -303.975 !! PS161='NVAD' 235987 229.38 -235.588 !! PS162='OZRK' 236460 332.595 -322.715 !! PS163='PDTD' 236777 321.295 -225.142 !! PS164='POTO' 236826 535.474 -215.124 !! PS165='ROLL' 237263 455.277 -212.788 !! PS166='ROSE' 237300 486.744 -156.257 !! PS167='SALE' 237506 478.319 -247.284 !! PS168='SENE' 237656 212.232 -346.356 !! PS169='SPRC' 237967 217.784 -330.588 !! PS170='SPVL' 237976 317.872 -298.923 !! PS171='STEE' 238043 490.224 -205.375 !! PS172='STOK' 238082 282.366 -249.68 !! PS173='SWSP' 238223 307.988 -108.584 !! PS174='TRKD' 238252 327.995 -369.664 !! PS175='TRUM' 238466 312.604 -186.416 !! PS176='UNIT' 238524 223.807 -113.079 !! PS177='VIBU' 238609 512.995 -236.439 !! PS178='VIEN' 238620 435.914 -186.806 !! PS179='WAPP' 238700 593.558 -318.328 !! PS180='WASG' 238746 520.949 -143.874 !! PS181='WEST' 238880 457.784 -347.238 !! PS182='ALBU' 290234 -871.609 -503.095 !! PS183='ARTE' 290600 -689.914 -774.455 !! PS184='AUGU' 290640 -974.149 -598.824 !! PS185='CARL' 291469 -682.406 -821.637 !! PS186='CARR' 291515 -821.335 -664.892 !! PS187='CLAY' 291887 -547.48 -374.232 !! PS188='CLOV' 291939 -566.944 -597.754 !! PS189='CUBA' 292241 -891.039 -392.352 !! PS190='CUBE' 292250 -951.736 -488.294 !! PS191='DEMI' 292436 -1010.101 -798.493 !! PS192='DURA' 292665 -783.906 -760.939 !! PS193='EANT' 292700 -733.551 -347.353 !! PS194='LAVG' 294862 -731.851 -447.93 !! PS195='PROG' 297094 -812.31 -577.673 !! PS196='RAMO' 297254 -734.136 -615.047 !! PS197='ROSW' 297610 -696.498 -712.285 !

Page 27
01Met01a.inp

! PS198='ROY ' 297638 -644.494 -422.842 !! PS199='SANT' 298085 -806.849 -444.709 !! PS200='SPRI' 298501 -676.057 -373.646 !! PS201='STAY' 298518 -808.857 -493.806 !! PS202='TNMN' 299031 -912.622 -413.503 !! PS203='TUCU' 299156 -604.957 -508.728 !! PS204='WAST' 299569 -638.519 -820.543 !! PS205='WISD' 299686 -856.457 -756.231 !! PS206='AIRS' 340179 -213.107 -595.912 !! PS207='ARDM' 340292 -11.884 -645.109 !! PS208='BENG' 340670 175.595 -567.462 !! PS209='CANE' 341437 72.343 -638.116 !! PS210='CHRT' 341544 203.973 -632.111 !! PS211='CHAN' 341684 10.792 -474.978 !! PS212='CHIK' 341750 -83.1 -547.384 !! PS213='CCTY' 342334 -164.531 -479.853 !! PS214='DUNC' 342654 -87.336 -609.835 !! PS215='ELKC' 342849 -217.232 -508.297 !! PS216='FORT' 343281 -130.039 -541.081 !! PS217='GEAR' 343497 -119.041 -482.918 !! PS218='HENN' 344052 -31.628 -599.42 !! PS219='HOBA' 344202 -189.838 -548.204 !! PS220='KING' 344865 28.421 -670.751 !! PS221='LKEU' 344975 141.785 -519.552 !! PS222='LEHI' 345108 71.833 -611.555 !! PS223='MACI' 345463 -253.239 -466.413 !! PS224='MALL' 345589 -55.647 -425.395 !! PS225='MAYF' 345648 -259.989 -511.519 !! PS226='MUSK' 346130 151.113 -543.185 !! PS227='NOWA' 346485 120.357 -364.978 !! PS228='OKAR' 346620 -88.212 -472.171 !! PS229='OKEM' 346638 62.894 -505.853 !! PS230='OKLA' 346661 -54.219 -509.977 !! PS231='PAOL' 346859 -25.939 -572.797 !! PS232='PAWH' 346935 57.943 -368.158 !! PS233='PAWN' 346944 16.863 -402.936 !! PS234='PONC' 347196 -8.402 -362.214 !! PS235='PRYO' 347309 148.985 -406.842 !! PS236='SHAT' 348101 -258.12 -406.316 !! PS237='STIG' 348497 170.629 -524.268 !! PS238='TULS' 348992 99.361 -419.873 !! PS239='TUSK' 349023 156.947 -594.453 !! PS240='WMWR' 349629 -156.042 -581.407 !! PS241='WOLF' 349748 29.378 -537.437 !! PS242='BOLI' 400876 723.871 -492.235 !! PS243='BROW' 401150 696.499 -458.224 !! PS244='CETR' 401587 858.366 -415.773 !! PS245='DICS' 402489 858.059 -388.772 !

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01Met01a.inp

! PS246='DYER' 402680 681.365 -409.615 !! PS247='GRNF' 403697 732.076 -390.773 !! PS248='JSNN' 404561 734.39 -451.872 !! PS249='LWER' 405089 871.334 -477.677 !! PS250='LEXI' 405210 773.155 -444.948 !! PS251='MASO' 405720 673.594 -479.476 !! PS252='MEMP' 405954 635.711 -522.428 !! PS253='MWFO' 405956 651.601 -513.031 !! PS254='MUNF' 406358 648.045 -477.095 !! PS255='SAMB' 408065 684.448 -363.311 !! PS256='SAVA' 408108 785.195 -498.799 !! PS257='UNCY' 409219 709.079 -367.88 !! PS258='ABIL' 410016 -251.992 -837.072 !! PS259='AMAR' 410211 -425.807 -517.874 !! PS260='AUST' 410428 -73.36 -1073.563 !! PS261='BRWN' 411136 -43.145 -1569.786 !! PS262='COST' 411889 61.112 -1043.691 !! PS263='COCR' 412015 -51.11 -1359.669 !! PS264='CROS' 412131 -203.641 -870.07 !! PS265='DFWT' 412242 -1.764 -786.588 !! PS266='EAST' 412715 -170.74 -840.382 !! PS267='ELPA' 412797 -886.293 -861.789 !! PS268='HICO' 414137 -97.472 -887.436 !! PS269='HUST' 414300 158.985 -1110.596 !! PS270='KRES' 414880 -434.589 -611.633 !! PS271='LKCK' 414975 100.038 -693.147 !! PS272='LNGV' 415348 220.658 -845.053 !! PS273='LUFK' 415424 214.211 -969.019 !! PS274='MATH' 415661 -86.679 -1329.651 !! PS275='MIDR' 415890 -490.426 -878.838 !! PS276='MTLK' 416104 -673.955 -1004.875 !! PS277='NACO' 416177 223.545 -926.17 !! PS278='NAVA' 416210 28.358 -892.028 !! PS279='NEWB' 416270 240.125 -721.264 !! PS280='BPAT' 417174 288.906 -1110.59 !! PS281='RANK' 417431 -471.686 -959.663 !! PS282='SAAG' 417943 -332.751 -952.407 !! PS283='SAAT' 417945 -143.316 -1160.893 !! PS284='SHEF' 418252 -463.535 -1020.511 !! PS285='STEP' 418623 -112.577 -858.48 !! PS286='STER' 418630 -376.93 -896.223 !! PS287='VALE' 419270 -719.824 -1014.032 !! PS288='VICT' 419364 6.856 -1237.418 !! PS289='WACO' 419419 -21.705 -929.783 !! PS290='WATR' 419499 -353.588 -915.496 !! PS291='WHEE' 419665 57.941 -1008.958 !! PS292='WPDM' 419916 262.52 -737.331 !! PS293='DORA' 232302 422.323 -345.052 !

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01Met01a.inp

! PS294='DIXN' 112353 730.842 -249.922 !! PS295='DAUP' 12172 860.103 -1039.592 !! PS296='FREV' 123104 832.766 -80.805 !! PS297='WARR' 18673 856.047 -757.08 !! PS298='MDTN' 235562 478.829 -82.092 !! END !------------------- 1 Four character string for station name (MUST START IN COLUMN 9) 2 Six digit station code composed of state code (first 2 digits) and station ID (last 4 digits)!END!

Page 30
American Electric Power C-1 Trinity Consultants 

Northeastern Power Station 083701.0024 

APPENDIX C – SAMPLE CALPUFF CONTROL FILE
2001_NE_NOx.inp

AEP Northeastern BART Refined Analysis2001---------------- Run title (3 lines) ------------------------------------------ CALPUFF MODEL CONTROL FILE ---------------------------------------------------------------------------------------------------------INPUT GROUP: 0 -- Input and Output File Names--------------Default Name Type File Name------------ ---- ---------CALMET.DAT input * METDAT = * orISCMET.DAT input * ISCDAT = * orPLMMET.DAT input * PLMDAT = * orPROFILE.DAT input * PRFDAT = *SURFACE.DAT input * SFCDAT = *RESTARTB.DAT input * RSTARTB= *--------------------------------------------------------------------------------CALPUFF.LST output ! PUFLST =2001_NE_NOx.LST !CONC.DAT output ! CONDAT =2001_NE_NOx.DAT !DFLX.DAT output * DFDAT = *WFLX.DAT output * WFDAT = *VISB.DAT output ! VISDAT =2001_NE_NOx.VIS !RESTARTE.DAT output * RSTARTE= *--------------------------------------------------------------------------------Emission Files--------------PTEMARB.DAT input * PTDAT = *VOLEMARB.DAT input * VOLDAT = *BAEMARB.DAT input * ARDAT = *LNEMARB.DAT input * LNDAT = *--------------------------------------------------------------------------------Other Files-----------OZONE.DAT input ! OZDAT =ozone_2001.dat!VD.DAT input * VDDAT = *CHEM.DAT input * CHEMDAT= *H2O2.DAT input * H2O2DAT= *HILL.DAT input * HILDAT= *HILLRCT.DAT input * RCTDAT= *

Page 1
2001_NE_NOx.inp

COASTLN.DAT input * CSTDAT= *FLUXBDY.DAT input * BDYDAT= *BCON.DAT input * BCNDAT= *DEBUG.DAT output * DEBUG = *MASSFLX.DAT output * FLXDAT= *MASSBAL.DAT output * BALDAT= *FOG.DAT output * FOGDAT= *--------------------------------------------------------------------------------All file names will be converted to lower case if LCFILES = TOtherwise, if LCFILES = F, file names will be converted to UPPER CASE T = lower case ! LCFILES = F ! F = UPPER CASENOTE: (1) file/path names can be up to 70 characters in lengthProvision for multiple input files---------------------------------- Number of CALMET.DAT files for run (NMETDAT) Default: 1 ! NMETDAT = 36 ! Number of PTEMARB.DAT files for run (NPTDAT) Default: 0 ! NPTDAT = 0 ! Number of BAEMARB.DAT files for run (NARDAT) Default: 0 ! NARDAT = 0 ! Number of VOLEMARB.DAT files for run (NVOLDAT) Default: 0 ! NVOLDAT = 0 !!END!-------------Subgroup (0a)------------- The following CALMET.DAT filenames are processed in sequence if NMETDAT>1Default Name Type File Name------------ ---- --------- none input ! METDAT=D:\2001\01Met01a.met ! !END! none input ! METDAT=D:\2001\01Met01b.met ! !END! none input ! METDAT=D:\2001\01Met01c.met ! !END! none input ! METDAT=D:\2001\01Met02a.met ! !END! none input ! METDAT=D:\2001\01Met02b.met ! !END! none input ! METDAT=D:\2001\01Met02c.met ! !END! none input ! METDAT=D:\2001\01Met03a.met ! !END! none input ! METDAT=D:\2001\01Met03b.met ! !END!

Page 2
2001_NE_NOx.inp

 none input ! METDAT=D:\2001\01Met03c.met ! !END! none input ! METDAT=D:\2001\01Met04a.met ! !END! none input ! METDAT=D:\2001\01Met04b.met ! !END! none input ! METDAT=D:\2001\01Met04c.met ! !END! none input ! METDAT=D:\2001\01Met05a.met ! !END! none input ! METDAT=D:\2001\01Met05b.met ! !END! none input ! METDAT=D:\2001\01Met05c.met ! !END! none input ! METDAT=D:\2001\01Met06a.met ! !END! none input ! METDAT=D:\2001\01Met06b.met ! !END! none input ! METDAT=D:\2001\01Met06c.met ! !END! none input ! METDAT=D:\2001\01Met07a.met ! !END! none input ! METDAT=D:\2001\01Met07b.met ! !END! none input ! METDAT=D:\2001\01Met07c.met ! !END! none input ! METDAT=D:\2001\01Met08a.met ! !END! none input ! METDAT=D:\2001\01Met08b.met ! !END! none input ! METDAT=D:\2001\01Met08c.met ! !END! none input ! METDAT=D:\2001\01Met09a.met ! !END! none input ! METDAT=D:\2001\01Met09b.met ! !END! none input ! METDAT=D:\2001\01Met09c.met ! !END! none input ! METDAT=D:\2001\01Met10a.met ! !END! none input ! METDAT=D:\2001\01Met10b.met ! !END! none input ! METDAT=D:\2001\01Met10c.met ! !END! none input ! METDAT=D:\2001\01Met11a.met ! !END! none input ! METDAT=D:\2001\01Met11b.met ! !END! none input ! METDAT=D:\2001\01Met11c.met ! !END! none input ! METDAT=D:\2001\01Met12a.met ! !END! none input ! METDAT=D:\2001\01Met12b.met ! !END! none input ! METDAT=D:\2001\01Met12c.met ! !END!--------------------------------------------------------------------------------INPUT GROUP: 1 -- General run control parameters-------------- Option to run all periods found in the met. file (METRUN) Default: 0 ! METRUN = 0 ! METRUN = 0 - Run period explicitly defined below METRUN = 1 - Run all periods in met. file Starting date: Year (IBYR) -- No default ! IBYR = 2001 ! (used only if Month (IBMO) -- No default ! IBMO = 1 ! METRUN = 0) Day (IBDY) -- No default ! IBDY = 1 ! Hour (IBHR) -- No default ! IBHR = 0 ! Base time zone (XBTZ) -- No default ! XBTZ = 6.0 ! PST = 8., MST = 7.

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2001_NE_NOx.inp

 CST = 6., EST = 5. Length of run (hours) (IRLG) -- No default ! IRLG = 8760 ! Number of chemical species (NSPEC) Default: 5 ! NSPEC = 10 ! Number of chemical species to be emitted (NSE) Default: 3 ! NSE = 7 ! Flag to stop run after SETUP phase (ITEST) Default: 2 ! ITEST = 2 ! (Used to allow checking of the model inputs, files, etc.) ITEST = 1 - STOPS program after SETUP phase ITEST = 2 - Continues with execution of program after SETUP Restart Configuration: Control flag (MRESTART) Default: 0 ! MRESTART = 0 ! 0 = Do not read or write a restart file 1 = Read a restart file at the beginning of the run 2 = Write a restart file during run 3 = Read a restart file at beginning of run and write a restart file during run Number of periods in Restart output cycle (NRESPD) Default: 0 ! NRESPD = 0 ! 0 = File written only at last period >0 = File updated every NRESPD periods Meteorological Data Format (METFM) Default: 1 ! METFM = 1 ! METFM = 1 - CALMET binary file (CALMET.MET) METFM = 2 - ISC ASCII file (ISCMET.MET) METFM = 3 - AUSPLUME ASCII file (PLMMET.MET) METFM = 4 - CTDM plus tower file (PROFILE.DAT) and surface parameters file (SURFACE.DAT) PG sigma-y is adjusted by the factor (AVET/PGTIME)**0.2 Averaging Time (minutes) (AVET) Default: 60.0 ! AVET = 60. ! PG Averaging Time (minutes) (PGTIME)

Page 4
2001_NE_NOx.inp

 Default: 60.0 ! PGTIME = 60. !!END!-------------------------------------------------------------------------------INPUT GROUP: 2 -- Technical options-------------- Vertical distribution used in the near field (MGAUSS) Default: 1 ! MGAUSS = 1 ! 0 = uniform 1 = Gaussian Terrain adjustment method (MCTADJ) Default: 3 ! MCTADJ = 3 ! 0 = no adjustment 1 = ISC-type of terrain adjustment 2 = simple, CALPUFF-type of terrain adjustment  3 = partial plume path adjustment Subgrid-scale complex terrain flag (MCTSG) Default: 0 ! MCTSG = 0 ! 0 = not modeled 1 = modeled Near-field puffs modeled as elongated 0 (MSLUG) Default: 0 ! MSLUG = 0 ! 0 = no 1 = yes (slug model used) Transitional plume rise modeled ? (MTRANS) Default: 1 ! MTRANS = 1 ! 0 = no (i.e., final rise only) 1 = yes (i.e., transitional rise computed) Stack tip downwash? (MTIP) Default: 1 ! MTIP = 1 ! 0 = no (i.e., no stack tip downwash) 1 = yes (i.e., use stack tip downwash) Method used to simulate building downwash? (MBDW) Default: 1 ! MBDW = 1 ! 1 = ISC method 2 = PRIME method

Page 5
2001_NE_NOx.inp

 Vertical wind shear modeled above stack top? (MSHEAR) Default: 0 ! MSHEAR = 0 ! 0 = no (i.e., vertical wind shear not modeled) 1 = yes (i.e., vertical wind shear modeled) Puff splitting allowed? (MSPLIT) Default: 0 ! MSPLIT = 0 ! 0 = no (i.e., puffs not split) 1 = yes (i.e., puffs are split) Chemical mechanism flag (MCHEM) Default: 1 ! MCHEM = 1 ! 0 = chemical transformation not modeled 1 = transformation rates computed internally (MESOPUFF II scheme) 2 = user-specified transformation rates used 3 = transformation rates computed internally (RIVAD/ARM3 scheme) 4 = secondary organic aerosol formation computed (MESOPUFF II scheme for OH) Aqueous phase transformation flag (MAQCHEM) (Used only if MCHEM = 1, or 3) Default: 0 ! MAQCHEM = 0 ! 0 = aqueous phase transformation not modeled 1 = transformation rates adjusted for aqueous phase reactions Wet removal modeled ? (MWET) Default: 1 ! MWET = 1 ! 0 = no 1 = yes Dry deposition modeled ? (MDRY) Default: 1 ! MDRY = 1 ! 0 = no 1 = yes (dry deposition method specified for each species in Input Group 3) Method used to compute dispersion coefficients (MDISP) Default: 3 ! MDISP = 3 ! 1 = dispersion coefficients computed from measured values of turbulence, sigma v, sigma w 2 = dispersion coefficients from internally calculated  sigma v, sigma w using micrometeorological variables (u*, w*, L, etc.) 3 = PG dispersion coefficients for RURAL areas (computed using

Page 6
2001_NE_NOx.inp

 the ISCST multi-segment approximation) and MP coefficients in urban areas 4 = same as 3 except PG coefficients computed using the MESOPUFF II eqns. 5 = CTDM sigmas used for stable and neutral conditions. For unstable conditions, sigmas are computed as in MDISP = 3, described above. MDISP = 5 assumes that measured values are read Sigma-v/sigma-theta, sigma-w measurements used? (MTURBVW) (Used only if MDISP = 1 or 5) Default: 3 ! MTURBVW = 3 ! 1 = use sigma-v or sigma-theta measurements from PROFILE.DAT to compute sigma-y (valid for METFM = 1, 2, 3, 4) 2 = use sigma-w measurements from PROFILE.DAT to compute sigma-z (valid for METFM = 1, 2, 3, 4) 3 = use both sigma-(v/theta) and sigma-w from PROFILE.DAT to compute sigma-y and sigma-z (valid for METFM = 1, 2, 3, 4) 4 = use sigma-theta measurements from PLMMET.DAT to compute sigma-y (valid only if METFM = 3) Back-up method used to compute dispersion when measured turbulence data are missing (MDISP2) Default: 3 ! MDISP2 = 3 ! (used only if MDISP = 1 or 5) 2 = dispersion coefficients from internally calculated  sigma v, sigma w using micrometeorological variables (u*, w*, L, etc.) 3 = PG dispersion coefficients for RURAL areas (computed using the ISCST multi-segment approximation) and MP coefficients in urban areas 4 = same as 3 except PG coefficients computed using the MESOPUFF II eqns. PG sigma-y,z adj. for roughness? Default: 0 ! MROUGH = 0 ! (MROUGH) 0 = no 1 = yes Partial plume penetration of Default: 1 ! MPARTL = 1 ! elevated inversion? (MPARTL) 0 = no 1 = yes

Page 7
2001_NE_NOx.inp

 Strength of temperature inversion Default: 0 ! MTINV = 0 ! provided in PROFILE.DAT extended records? (MTINV) 0 = no (computed from measured/default gradients) 1 = yes PDF used for dispersion under convective conditions? Default: 0 ! MPDF = 0 ! (MPDF) 0 = no 1 = yes Sub-Grid TIBL module used for shore line? Default: 0 ! MSGTIBL = 0 ! (MSGTIBL) 0 = no 1 = yes Boundary conditions (concentration) modeled? Default: 0 ! MBCON = 0 ! (MBCON) 0 = no 1 = yes, using formatted BCON.DAT file 2 = yes, using unformatted CONC.DAT file Analyses of fogging and icing impacts due to emissions from arrays of mechanically-forced cooling towers can be performed using CALPUFF in conjunction with a cooling tower emissions processor (CTEMISS) and its associated postprocessors. Hourly emissions of water vapor and temperature from each cooling tower cell are computed for the current cell configuration and ambient conditions by CTEMISS. CALPUFF models the dispersion of these emissions and provides cloud information in a specialized format for further analysis. Output to FOG.DAT is provided in either 'plume mode' or 'receptor mode' format. Configure for FOG Model output? Default: 0 ! MFOG = 0 ! (MFOG) 0 = no 1 = yes - report results in PLUME Mode format 2 = yes - report results in RECEPTOR Mode format Test options specified to see if they conform to regulatory values? (MREG) Default: 1 ! MREG = 0 !

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2001_NE_NOx.inp

 0 = NO checks are made 1 = Technical options must conform to USEPA Long Range Transport (LRT) guidance METFM 1 or 2 AVET 60. (min) PGTIME 60. (min) MGAUSS 1 MCTADJ 3 MTRANS 1 MTIP 1 MCHEM 1 or 3 (if modeling SOx, NOx) MWET 1 MDRY 1 MDISP 2 or 3 MPDF 0 if MDISP=3 1 if MDISP=2 MROUGH 0 MPARTL 1 SYTDEP 550. (m) MHFTSZ 0!END!-------------------------------------------------------------------------------INPUT GROUP: 3a, 3b -- Species list-------------------------------Subgroup (3a)------------ The following species are modeled:! CSPEC = SO2 ! !END!! CSPEC = SO4 ! !END!! CSPEC = NOX ! !END!! CSPEC = HNO3 ! !END!! CSPEC = NO3 ! !END!! CSPEC = NH3 ! !END!! CSPEC = PMC ! !END!! CSPEC = PMF ! !END!! CSPEC = EC ! !END!! CSPEC = SOA ! !END!

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 Dry OUTPUT GROUP SPECIES MODELED EMITTED DEPOSITED NUMBER NAME (0=NO, 1=YES) (0=NO, 1=YES) (0=NO, (0=NONE, (Limit: 12 1=COMPUTED-GAS 1=1st CGRUP, Characters 2=COMPUTED-PARTICLE 2=2nd CGRUP, in length) 3=USER-SPECIFIED) 3= etc.)! SO2 = 1, 1, 1, 0 !! SO4 = 1, 1, 2, 0 !! NOX = 1, 1, 1, 0 !! HNO3 = 1, 0, 1, 0 !! NO3 = 1, 0, 2, 0 !! NH3 = 1, 0, 1, 0 !! PMC = 1, 1, 2, 0 !! PMF = 1, 1, 2, 0 !! EC = 1, 1, 2, 0 !! SOA = 1, 1, 2, 0 !!END!-------------Subgroup (3b)------------- The following names are used for Species-Groups in which results for certain species are combined (added) prior to output. The CGRUP name will be used as the species name in output files. Use this feature to model specific particle-size distributions by treating each size-range as a separate species. Order must be consistent with 3(a) above.-------------------------------------------------------------------------------INPUT GROUP: 4 -- Map Projection and Grid control parameters-------------- Projection for all (X,Y): ------------------------- Map projection (PMAP) Default: UTM ! PMAP = LCC ! UTM : Universal Transverse Mercator TTM : Tangential Transverse Mercator LCC : Lambert Conformal Conic PS : Polar Stereographic

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 EM : Equatorial Mercator LAZA : Lambert Azimuthal Equal Area False Easting and Northing (km) at the projection origin (Used only if PMAP= TTM, LCC, or LAZA) (FEAST) Default=0.0 ! FEAST = 0.000 ! (FNORTH) Default=0.0 ! FNORTH = 0.000 ! UTM zone (1 to 60) (Used only if PMAP=UTM) (IUTMZN) No Default ! IUTMZN = 0 ! Hemisphere for UTM projection? (Used only if PMAP=UTM) (UTMHEM) Default: N ! UTMHEM = N ! N : Northern hemisphere projection S : Southern hemisphere projection Latitude and Longitude (decimal degrees) of projection origin (Used only if PMAP= TTM, LCC, PS, EM, or LAZA) (RLAT0) No Default ! RLAT0 = 40N ! (RLON0) No Default ! RLON0 = 97W ! TTM : RLON0 identifies central (true N/S) meridian of projection RLAT0 selected for convenience LCC : RLON0 identifies central (true N/S) meridian of projection RLAT0 selected for convenience PS : RLON0 identifies central (grid N/S) meridian of projection RLAT0 selected for convenience EM : RLON0 identifies central meridian of projection RLAT0 is REPLACED by 0.0N (Equator) LAZA: RLON0 identifies longitude of tangent-point of mapping plane RLAT0 identifies latitude of tangent-point of mapping plane Matching parallel(s) of latitude (decimal degrees) for projection (Used only if PMAP= LCC or PS) (XLAT1) No Default ! XLAT1 = 33N ! (XLAT2) No Default ! XLAT2 = 45N ! LCC : Projection cone slices through Earth's surface at XLAT1 and XLAT2 PS : Projection plane slices through Earth at XLAT1 (XLAT2 is not used) ---------- Note: Latitudes and longitudes should be positive, and include a letter N,S,E, or W indicating north or south latitude, and east or west longitude. For example, 35.9 N Latitude = 35.9N

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 118.7 E Longitude = 118.7E Datum-region ------------ The Datum-Region for the coordinates is identified by a character string. Many mapping products currently available use the model of the Earth known as the World Geodetic System 1984 (WGS-G ). Other local models may be in use, and their selection in CALMET will make its output consistent with local mapping products. The list of Datum-Regions with official transformation parameters is provided by the National Imagery and Mapping Agency (NIMA). NIMA Datum - Regions(Examples) ------------------------------------------------------------------------------ WGS-G WGS-84 GRS 80 Spheroid, Global coverage (WGS84) NAS-C NORTH AMERICAN 1927 Clarke 1866 Spheroid, MEAN FOR CONUS (NAD27) NWS-27 NWS 6370KM Radius, Sphere NWS-84 NWS 6370KM Radius, Sphere ESR-S ESRI REFERENCE 6371KM Radius, Sphere Datum-region for output coordinates (DATUM) Default: WGS-G ! DATUM = WGS-G !METEOROLOGICAL Grid: Rectangular grid defined for projection PMAP, with X the Easting and Y the Northing coordinate No. X grid cells (NX) No default ! NX = 462 ! No. Y grid cells (NY) No default ! NY = 376 ! No. vertical layers (NZ) No default ! NZ = 12 ! Grid spacing (DGRIDKM) No default ! DGRIDKM = 4. ! Units: km Cell face heights (ZFACE(nz+1)) No defaults Units: m ! ZFACE = 0.,20.,40.,60.,80.,100.,150.,200.,250.,500.,1000.,2000.,3500. ! Reference Coordinates of SOUTHWEST corner of grid cell(1, 1):

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 X coordinate (XORIGKM) No default ! XORIGKM = -951.547 ! Y coordinate (YORIGKM) No default ! YORIGKM = -1646.637 ! Units: kmCOMPUTATIONAL Grid: The computational grid is identical to or a subset of the MET. grid. The lower left (LL) corner of the computational grid is at grid point (IBCOMP, JBCOMP) of the MET. grid. The upper right (UR) corner of the computational grid is at grid point (IECOMP, JECOMP) of the MET. grid. The grid spacing of the computational grid is the same as the MET. grid. X index of LL corner (IBCOMP) No default ! IBCOMP = 165 ! (1 <= IBCOMP <= NX) Y index of LL corner (JBCOMP) No default ! JBCOMP = 220 ! (1 <= JBCOMP <= NY) X index of UR corner (IECOMP) No default ! IECOMP = 375 ! (1 <= IECOMP <= NX) Y index of UR corner (JECOMP) No default ! JECOMP = 348 ! (1 <= JECOMP <= NY)SAMPLING Grid (GRIDDED RECEPTORS): The lower left (LL) corner of the sampling grid is at grid point (IBSAMP, JBSAMP) of the MET. grid. The upper right (UR) corner of the sampling grid is at grid point (IESAMP, JESAMP) of the MET. grid. The sampling grid must be identical to or a subset of the computational grid. It may be a nested grid inside the computational grid. The grid spacing of the sampling grid is DGRIDKM/MESHDN. Logical flag indicating if gridded receptors are used (LSAMP) Default: T ! LSAMP = F ! (T=yes, F=no) X index of LL corner (IBSAMP) No default ! IBSAMP = 1 ! (IBCOMP <= IBSAMP <= IECOMP) Y index of LL corner (JBSAMP) No default ! JBSAMP = 1 ! (JBCOMP <= JBSAMP <= JECOMP)

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 X index of UR corner (IESAMP) No default ! IESAMP = 462 ! (IBCOMP <= IESAMP <= IECOMP) Y index of UR corner (JESAMP) No default ! JESAMP = 376 ! (JBCOMP <= JESAMP <= JECOMP) Nesting factor of the sampling grid (MESHDN) Default: 1 ! MESHDN = 1 ! (MESHDN is an integer >= 1)!END!-------------------------------------------------------------------------------INPUT GROUP: 5 -- Output Options-------------- * * FILE DEFAULT VALUE VALUE THIS RUN ---- ------------- -------------- Concentrations (ICON) 1 ! ICON = 1 ! Dry Fluxes (IDRY) 1 ! IDRY = 1 ! Wet Fluxes (IWET) 1 ! IWET = 1 ! Relative Humidity (IVIS) 1 ! IVIS = 1 ! (relative humidity file is required for visibility analysis) Use data compression option in output file? (LCOMPRS) Default: T ! LCOMPRS = T ! * 0 = Do not create file, 1 = create file DIAGNOSTIC MASS FLUX OUTPUT OPTIONS: Mass flux across specified boundaries for selected species reported hourly? (IMFLX) Default: 0 ! IMFLX = 0 ! 0 = no 1 = yes (FLUXBDY.DAT and MASSFLX.DAT filenames are specified in Input Group 0) Mass balance for each species

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 reported hourly? (IMBAL) Default: 0 ! IMBAL = 0 ! 0 = no 1 = yes (MASSBAL.DAT filename is specified in Input Group 0) LINE PRINTER OUTPUT OPTIONS: Print concentrations (ICPRT) Default: 0 ! ICPRT = 0 ! Print dry fluxes (IDPRT) Default: 0 ! IDPRT = 0 ! Print wet fluxes (IWPRT) Default: 0 ! IWPRT = 0 ! (0 = Do not print, 1 = Print) Concentration print interval (ICFRQ) in hours Default: 1 ! ICFRQ = 1 ! Dry flux print interval (IDFRQ) in hours Default: 1 ! IDFRQ = 1 ! Wet flux print interval (IWFRQ) in hours Default: 1 ! IWFRQ = 1 ! Units for Line Printer Output (IPRTU) Default: 1 ! IPRTU = 3 ! for for Concentration Deposition 1 = g/m**3 g/m**2/s 2 = mg/m**3 mg/m**2/s 3 = ug/m**3 ug/m**2/s 4 = ng/m**3 ng/m**2/s 5 = Odour Units Messages tracking progress of run written to the screen ? (IMESG) Default: 2 ! IMESG = 2 ! 0 = no 1 = yes (advection step, puff ID) 2 = yes (YYYYJJJHH, # old puffs, # emitted puffs) SPECIES (or GROUP for combined species) LIST FOR OUTPUT OPTIONS ---- CONCENTRATIONS ---- ------ DRY FLUXES ------ ------ WET FLUXES --FLUX -- SPECIES /GROUP PRINTED? SAVED ON DISK? PRINTED? SAVED ON DISK? PRINTED? SAVED ON DDISK? ------- ------------------------ ------------------------ -----------------------------------

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! SO2 = 0, 1, 0, 1, 0, 1, ! SO4 = 0, 1, 0, 1, 0, 1, ! NOX = 0, 1, 0, 1, 0, 1, ! HNO3 = 0, 1, 0, 1, 0, 1, ! NO3 = 0, 1, 0, 1, 0, 1, ! PMC = 0, 1, 0, 1, 0, 1, ! PMF = 0, 1, 0, 1, 0, 1, ! EC = 0, 1, 0, 1, 0, 1, ! SOA = 0, 1, 0, 1, 0, 1,  OPTIONS FOR PRINTING "DEBUG" QUANTITIES (much output)  Logical for debug output (LDEBUG) Default: F ! LDEBUG = F ! First puff to track (IPFDEB) Default: 1 ! IPFDEB = 1 ! Number of puffs to track (NPFDEB) Default: 1 ! NPFDEB = 1 ! Met. period to start output (NN1) Default: 1 ! NN1 = 1 ! Met. period to end output (NN2) Default: 10 ! NN2 = 10 !!END!-------------------------------------------------------------------------------INPUT GROUP: 6a, 6b, & 6c -- Subgrid scale complex terrain inputs----------------------------------------Subgroup (6a)--------------- Number of terrain features (NHILL) Default: 0 ! NHILL = 0 ! Number of special complex terrain receptors (NCTREC) Default: 0 ! NCTREC = 0 ! Terrain and CTSG Receptor data for  CTSG hills input in CTDM format ? (MHILL) No Default ! MHILL = 2 ! 1 = Hill and Receptor data created

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 by CTDM processors & read from HILL.DAT and HILLRCT.DAT files 2 = Hill data created by OPTHILL & input below in Subgroup (6b); Receptor data in Subgroup (6c) Factor to convert horizontal dimensions Default: 1.0 ! XHILL2M = 1. ! to meters (MHILL=1) Factor to convert vertical dimensions Default: 1.0 ! ZHILL2M = 1. ! to meters (MHILL=1) X-origin of CTDM system relative to No Default ! XCTDMKM = 0.0E00 ! CALPUFF coordinate system, in Kilometers (MHILL=1) Y-origin of CTDM system relative to No Default ! YCTDMKM = 0.0E00 ! CALPUFF coordinate system, in Kilometers (MHILL=1)! END !---------------Subgroup (6b)--------------- 1 ** HILL informationHILL XC YC THETAH ZGRID RELIEF EXPO 1 EXPO 2 SCALE 1 SC AMAX2 NO. (km) (km) (deg.) (m) (m) (m) (m) (m)  (m)---- ---- ---- ------ ----- ------ ------ ------ ------- -- --------------------Subgroup (6c)--------------- COMPLEX TERRAIN RECEPTOR INFORMATION XRCT YRCT ZRCT XHH (km) (km) (m) ------ ----- ------ -----------------------1

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 Description of Complex Terrain Variables: XC, YC = Coordinates of center of hill THETAH = Orientation of major axis of hill (clockwise from North) ZGRID = Height of the 0 of the grid above mean sea level RELIEF = Height of the crest of the hill above the grid elevation EXPO 1 = Hill-shape exponent for the major axis EXPO 2 = Hill-shape exponent for the major axis SCALE 1 = Horizontal length scale along the major axis SCALE 2 = Horizontal length scale along the minor axis AMAX = Maximum allowed axis length for the major axis BMAX = Maximum allowed axis length for the major axis XRCT, YRCT = Coordinates of the complex terrain receptors ZRCT = Height of the ground (MSL) at the complex terrain Receptor XHH = Hill number associated with each complex terrain receptor (NOTE: MUST BE ENTERED AS A REAL NUMBER) ** NOTE: DATA for each hill and CTSG receptor are treated as a separate input subgroup and therefore must end with an input group terminator.-------------------------------------------------------------------------------INPUT GROUP: 7 -- Chemical parameters for dry deposition of gases-------------- SPECIES DIFFUSIVITY ALPHA STAR REACTIVITY MESOPHYLL RESISTANCE HCOEFFICIENT NAME (cm**2/s) (s/cm) (dimensionless) ------- ----------- ---------- ---------- -------------------- -----------------------! SO2 = 0.1509, 1000., 8., 0., ! NOX = 0.1656, 1., 8., 5., ! HNO3 = 0.1628, 1., 18., 0., 0!END!-------------------------------------------------------------------------------INPUT GROUP: 8 -- Size parameters for dry deposition of particles

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-------------- For SINGLE SPECIES, the mean and standard deviation are used to compute a deposition velocity for NINT (see group 9) size-ranges, and these are then averaged to obtain a mean deposition velocity. For GROUPED SPECIES, the size distribution should be explicitly specified (by the 'species' in the group), and the standard deviation for each should be entered as 0. The model will then use the deposition velocity for the stated mean diameter. SPECIES GEOMETRIC MASS MEAN GEOMETRIC STANDARD NAME DIAMETER DEVIATION (microns) (microns) ------- ------------------- ------------------! SO4 = 0.48, 2. !! NO3 = 0.48, 2. !! PMC = 6.00, 2. !! PMF = 0.48, 2. !! EC = 0.48, 2. !! SOA = 0.48, 2. !!END!-------------------------------------------------------------------------------INPUT GROUP: 9 -- Miscellaneous dry deposition parameters-------------- Reference cuticle resistance (s/cm) (RCUTR) Default: 30 ! RCUTR = 30.0 ! Reference ground resistance (s/cm) (RGR) Default: 10 ! RGR = 10.0 ! Reference pollutant reactivity (REACTR) Default: 8 ! REACTR = 8.0 ! Number of particle-size intervals used to  evaluate effective particle deposition velocity (NINT) Default: 9 ! NINT = 9 ! Vegetation state in unirrigated areas (IVEG) Default: 1 ! IVEG = 1 ! IVEG=1 for active and unstressed vegetation IVEG=2 for active and stressed vegetation IVEG=3 for inactive vegetation

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!END!-------------------------------------------------------------------------------INPUT GROUP: 10 -- Wet Deposition Parameters--------------- Scavenging Coefficient -- Units: (sec)**(-1) Pollutant Liquid Precip. Frozen Precip. --------- -------------- --------------! SO2 = 3.21E-05, 0.0E00 !! SO4 = 1.0E-04, 3.0E-05 !! HNO3 = 6.0E-05, 0.0E00 !! NO3 = 1.0E-04, 3.0E-05 !! NH3 = 8.0E-05, 0.0E00 !! PMC = 1.0E-04, 3.0E-05 !! PMF = 1.0E-04, 3.0E-05 !! EC = 1.0E-04, 3.0E-05 !! SOA = 1.0E-04, 3.0E-05 !!END!-------------------------------------------------------------------------------INPUT GROUP: 11 -- Chemistry Parameters--------------- Ozone data input option (MOZ) Default: 1 ! MOZ = 1 ! (Used only if MCHEM = 1, 3, or 4) 0 = use a monthly background ozone value 1 = read hourly ozone concentrations from the OZONE.DAT data file Monthly ozone concentrations (Used only if MCHEM = 1, 3, or 4 and  MOZ = 0 or MOZ = 1 and all hourly O3 data missing) (BCKO3) in ppb Default: 12*80. ! BCKO3 = 40.00, 40.00, 40.00, 40.00, 40.00, 40.00, 40.00, 40.00, 40.00, 40.00, 40.00 Monthly ammonia concentrations (Used only if MCHEM = 1, or 3) (BCKNH3) in ppb Default: 12*10. 

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 ! BCKNH3 = 3.00, 3.00, 3.00, 3.00, 3.00, 3.00, 3.00, 3.00, 3.00, 3.00, 3.00, 3.00 ! Nighttime SO2 loss rate (RNITE1) in percent/hour Default: 0.2 ! RNITE1 = .2 ! Nighttime NOx loss rate (RNITE2) in percent/hour Default: 2.0 ! RNITE2 = 2.0 ! Nighttime HNO3 formation rate (RNITE3) in percent/hour Default: 2.0 ! RNITE3 = 2.0 ! H2O2 data input option (MH2O2) Default: 1 ! MH2O2 = 0 ! (Used only if MAQCHEM = 1) 0 = use a monthly background H2O2 value 1 = read hourly H2O2 concentrations from the H2O2.DAT data file Monthly H2O2 concentrations (Used only if MQACHEM = 1 and MH2O2 = 0 or MH2O2 = 1 and all hourly H2O2 data missing) (BCKH2O2) in ppb Default: 12*1.  ! BCKH2O2 = 1.00, 1.00, 1.00, 1.00, 1.00, 1.00, 1.00, 1.00, 1.00, 1.00, 1.00, 1.00 ! --- Data for SECONDARY ORGANIC AEROSOL (SOA) Option (used only if MCHEM = 4) The SOA module uses monthly values of: Fine particulate concentration in ug/m^3 (BCKPMF) Organic fraction of fine particulate (OFRAC) VOC / NOX ratio (after reaction) (VCNX) to characterize the air mass when computing the formation of SOA from VOC emissions. Typical values for several distinct air mass types are: Month 1 2 3 4 5 6 7 8 9 10 11 12 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Clean Continental BCKPMF 1. 1. 1. 1. 1. 1. 1. 1. 1. 1. 1. 1. OFRAC .15 .15 .20 .20 .20 .20 .20 .20 .20 .20 .20 .15 VCNX 50. 50. 50. 50. 50. 50. 50. 50. 50. 50. 50. 50. Clean Marine (surface) BCKPMF .5 .5 .5 .5 .5 .5 .5 .5 .5 .5 .5 .5 OFRAC .25 .25 .30 .30 .30 .30 .30 .30 .30 .30 .30 .25 VCNX 50. 50. 50. 50. 50. 50. 50. 50. 50. 50. 50. 50.

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 Urban - low biogenic (controls present) BCKPMF 30. 30. 30. 30. 30. 30. 30. 30. 30. 30. 30. 30. OFRAC .20 .20 .25 .25 .25 .25 .25 .25 .20 .20 .20 .20 VCNX 4. 4. 4. 4. 4. 4. 4. 4. 4. 4. 4. 4. Urban - high biogenic (controls present) BCKPMF 60. 60. 60. 60. 60. 60. 60. 60. 60. 60. 60. 60. OFRAC .25 .25 .30 .30 .30 .55 .55 .55 .35 .35 .35 .25 VCNX 15. 15. 15. 15. 15. 15. 15. 15. 15. 15. 15. 15. Regional Plume BCKPMF 20. 20. 20. 20. 20. 20. 20. 20. 20. 20. 20. 20. OFRAC .20 .20 .25 .35 .25 .40 .40 .40 .30 .30 .30 .20 VCNX 15. 15. 15. 15. 15. 15. 15. 15. 15. 15. 15. 15. Urban - no controls present BCKPMF 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. OFRAC .30 .30 .35 .35 .35 .55 .55 .55 .35 .35 .35 .30 VCNX 2. 2. 2. 2. 2. 2. 2. 2. 2. 2. 2. 2. Default: Clean Continental ! BCKPMF = 1.00, 1.00, 1.00, 1.00, 1.00, 1.00, 1.00, 1.00, 1.00, 1.00, 1.00, 1.00 ! ! OFRAC = 0.15, 0.15, 0.20, 0.20, 0.20, 0.20, 0.20, 0.20, 0.20, 0.20, 0.20, 0.15 ! ! VCNX = 50.00, 50.00, 50.00, 50.00, 50.00, 50.00, 50.00, 50.00, 50.00, 50.00, 50.0!END!-------------------------------------------------------------------------------INPUT GROUP: 12 -- Misc. Dispersion and Computational Parameters--------------- Horizontal size of puff (m) beyond which time-dependent dispersion equations (Heffter) are used to determine sigma-y and sigma-z (SYTDEP) Default: 550. ! SYTDEP = 5.5E02 ! Switch for using Heffter equation for sigma z  as above (0 = Not use Heffter; 1 = use Heffter (MHFTSZ) Default: 0 ! MHFTSZ = 0 ! Stability class used to determine plume growth rates for puffs above the boundary layer (JSUP) Default: 5 ! JSUP = 5 !

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 Vertical dispersion constant for stable conditions (k1 in Eqn. 2.7-3) (CONK1) Default: 0.01 ! CONK1 = .01 ! Vertical dispersion constant for neutral/ unstable conditions (k2 in Eqn. 2.7-4) (CONK2) Default: 0.1 ! CONK2 = .1 ! Factor for determining Transition-point from Schulman-Scire to Huber-Snyder Building Downwash scheme (SS used for Hs < Hb + TBD * HL) (TBD) Default: 0.5 ! TBD = .5 ! TBD < 0 ==> always use Huber-Snyder TBD = 1.5 ==> always use Schulman-Scire TBD = 0.5 ==> ISC Transition-point Range of land use categories for which urban dispersion is assumed (IURB1, IURB2) Default: 10 ! IURB1 = 10 ! 19 ! IURB2 = 19 ! Site characterization parameters for single-point Met data files --------- (needed for METFM = 2,3,4) Land use category for modeling domain (ILANDUIN) Default: 20 ! ILANDUIN = 20 ! Roughness length (m) for modeling domain (Z0IN) Default: 0.25 ! Z0IN = .25 ! Leaf area index for modeling domain (XLAIIN) Default: 3.0 ! XLAIIN = 3.0 ! Elevation above sea level (m) (ELEVIN) Default: 0.0 ! ELEVIN = .0 ! Latitude (degrees) for met location (XLATIN) Default: -999. ! XLATIN = -999.0 ! Longitude (degrees) for met location (XLONIN) Default: -999. ! XLONIN = -999.0 ! Specialized information for interpreting single-point Met data files ----- Anemometer height (m) (Used only if METFM = 2,3) (ANEMHT) Default: 10. ! ANEMHT = 10.0 ! Form of lateral turbulance data in PROFILE.DAT file (Used only if METFM = 4 or MTURBVW = 1 or 3)

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 (ISIGMAV) Default: 1 ! ISIGMAV = 1 ! 0 = read sigma-theta 1 = read sigma-v Choice of mixing heights (Used only if METFM = 4) (IMIXCTDM) Default: 0 ! IMIXCTDM = 0 ! 0 = read PREDICTED mixing heights 1 = read OBSERVED mixing heights Maximum length of a slug (met. grid units) (XMXLEN) Default: 1.0 ! XMXLEN = 1.0 ! Maximum travel distance of a puff/slug (in grid units) during one sampling step (XSAMLEN) Default: 1.0 ! XSAMLEN = 10 ! Maximum Number of slugs/puffs release from one source during one time step  (MXNEW) Default: 99 ! MXNEW = 60 ! Maximum Number of sampling steps for  one puff/slug during one time step  (MXSAM) Default: 99 ! MXSAM = 60 ! Number of iterations used when computing the transport wind for a sampling step that includes gradual rise (for CALMET and PROFILE winds) (NCOUNT) Default: 2 ! NCOUNT = 2 ! Minimum sigma y for a new puff/slug (m)  (SYMIN) Default: 1.0 ! SYMIN = 1.0 ! Minimum sigma z for a new puff/slug (m)  (SZMIN) Default: 1.0 ! SZMIN = 1.0 ! Default minimum turbulence velocities sigma-v and sigma-w for each stability class (m/s) (SVMIN(6) and SWMIN(6)) Default SVMIN : .50, .50, .50, .50, .50, .50 Default SWMIN : .20, .12, .08, .06, .03, .016 Stability Class : A B C D E F --- --- --- --- --- --- ! SVMIN = 0.500, 0.500, 0.500, 0.500, 0.500, 0.500! ! SWMIN = 0.200, 0.120, 0.080, 0.060, 0.030, 0.016! Divergence criterion for dw/dz across puff

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 used to initiate adjustment for horizontal convergence (1/s) Partial adjustment starts at CDIV(1), and full adjustment is reached at CDIV(2) (CDIV(2)) Default: 0.0,0.0 ! CDIV = 0.01, 0.01 ! Minimum wind speed (m/s) allowed for non-calm conditions. Also used as minimum speed returned when using power-law  extrapolation toward surface (WSCALM) Default: 0.5 ! WSCALM = .5 ! Maximum mixing height (m)  (XMAXZI) Default: 3000. ! XMAXZI = 3000.0 ! Minimum mixing height (m)  (XMINZI) Default: 50. ! XMINZI = 20.0 ! Default wind speed classes -- 5 upper bounds (m/s) are entered; the 6th class has no upper limit (WSCAT(5)) Default :  ISC RURAL : 1.54, 3.09, 5.14, 8.23, 10.8 (10.8+) Wind Speed Class : 1 2 3 4 5  --- --- --- --- ---  ! WSCAT = 1.54, 3.09, 5.14, 8.23, 10.80 ! Default wind speed profile power-law exponents for stabilities 1-6 (PLX0(6)) Default : ISC RURAL values ISC RURAL : .07, .07, .10, .15, .35, .55 ISC URBAN : .15, .15, .20, .25, .30, .30 Stability Class : A B C D E F --- --- --- --- --- --- ! PLX0 = 0.07, 0.07, 0.10, 0.15, 0.35, 0.55 ! Default potential temperature gradient for stable classes E, F (degK/m) (PTG0(2)) Default: 0.020, 0.035 ! PTG0 = 0.020, 0.035 ! Default plume path coefficients for each stability class (used when option for partial plume height terrain adjustment is selected -- MCTADJ=3) (PPC(6)) Stability Class : A B C D E F

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 Default PPC : .50, .50, .50, .50, .35, .35 --- --- --- --- --- --- ! PPC = 0.50, 0.50, 0.50, 0.50, 0.35, 0.35 ! Slug-to-puff transition criterion factor equal to sigma-y/length of slug (SL2PF) Default: 10. ! SL2PF = 10.0 ! Puff-splitting control variables ------------------------ VERTICAL SPLIT -------------- Number of puffs that result every time a puff is split - nsplit=2 means that 1 puff splits into 2 (NSPLIT) Default: 3 ! NSPLIT = 3 ! Time(s) of a day when split puffs are eligible to be split once again; this is typically set once per day, around sunset before nocturnal shear develops. 24 values: 0 is midnight (00:00) and 23 is 11 PM (23:00) 0=do not re-split 1=eligible for re-split (IRESPLIT(24)) Default: Hour 17 = 1 ! IRESPLIT = 0,0,0,0,0,0,0,0,0,0,0,0,0,0,0,0,1,0,0,0,0,0,0,0 ! Split is allowed only if last hour's mixing height (m) exceeds a minimum value (ZISPLIT) Default: 100. ! ZISPLIT = 100.0 ! Split is allowed only if ratio of last hour's mixing ht to the maximum mixing ht experienced by the puff is less than a maximum value (this postpones a split until a nocturnal layer develops) (ROLDMAX) Default: 0.25 ! ROLDMAX = 0.25 ! HORIZONTAL SPLIT ---------------- Number of puffs that result every time a puff is split - nsplith=5 means that 1 puff splits into 5 (NSPLITH) Default: 5 ! NSPLITH = 5 ! Minimum sigma-y (Grid Cells Units) of puff before it may be split (SYSPLITH) Default: 1.0 ! SYSPLITH = 1.0 !

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 Minimum puff elongation rate (SYSPLITH/hr) due to wind shear, before it may be split (SHSPLITH) Default: 2. ! SHSPLITH = 2.0 ! Minimum concentration (g/m^3) of each species in puff before it may be split Enter array of NSPEC values; if a single value is entered, it will be used for ALL species (CNSPLITH) Default: 1.0E-07 ! CNSPLITH = 1.0E-07 ! Integration control variables ------------------------ Fractional convergence criterion for numerical SLUG sampling integration (EPSSLUG) Default: 1.0e-04 ! EPSSLUG = 1.0E-04 ! Fractional convergence criterion for numerical AREA source integration (EPSAREA) Default: 1.0e-06 ! EPSAREA = 1.0E-06 ! Trajectory step-length (m) used for numerical rise integration (DSRISE) Default: 1.0 ! DSRISE = 1.0 ! Boundary Condition (BC) Puff control variables ------------------------ Minimum height (m) to which BC puffs are mixed as they are emitted (MBCON=2 ONLY). Actual height is reset to the current mixing height at the release point if greater than this minimum. (HTMINBC) Default: 500. ! HTMINBC = 500.0 ! Search radius (in BC segment lengths) about a receptor for sampling nearest BC puff. BC puffs are emitted with a spacing of one segment length, so the search radius should be greater than 1. (RSAMPBC) Default: 4. ! RSAMPBC = 10.0 ! Near-Surface depletion adjustment to concentration profile used when sampling BC puffs? (MDEPBC) Default: 1 ! MDEPBC = 1 ! 0 = Concentration is NOT adjusted for depletion 1 = Adjust Concentration for depletion!END!-------------------------------------------------------------------------------

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INPUT GROUPS: 13a, 13b, 13c, 13d -- Point source parameters-----------------------------------------------Subgroup (13a)--------------- Number of point sources with parameters provided below (NPT1) No default ! NPT1 = 2 ! Units used for point source emissions below (IPTU) Default: 1 ! IPTU = 3 ! 1 = g/s 2 = kg/hr 3 = lb/hr 4 = tons/yr 5 = Odour Unit * m**3/s (vol. flux of odour compound) 6 = Odour Unit * m**3/min 7 = metric tons/yr Number of source-species combinations with variable emissions scaling factors provided below in (13d) (NSPT1) Default: 0 ! NSPT1 = 0 ! Number of point sources with variable emission parameters provided in external file (NPT2) No default ! NPT2 = 0 ! (If NPT2 > 0, these point source emissions are read from the file: PTEMARB.DAT)!END!---------------Subgroup (13b)--------------- a POINT SOURCE: CONSTANT DATA ----------------------------- b c Source X Y Stack Base Stack Exit Exit Bldg. Emission No. Coordinate Coordinate Height Elevation Diameter Vel. Temp. Dwash Rates (km) (km) (m) (m) (m) (m/s) (deg. K)  ------ ---------- ---------- ------ ------ -------- ----- -------- ----- -------- 1 ! SRCNAM = NE3 ! Northeastern Unit 3

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 1 ! X = 115.656, -394.267, 183, 195, 8.23, 18.97, 424, 0, 0,0,3115.5,0,0,0,0,0,0,0! 1 ! FMFAC = 1 ! 1 ! END ! 2 ! SRCNAM = NE4 ! Northeastern Unit 4 2 ! X = 115.656, -394.267, 183, 195, 8.23, 17.46, 415, 0, 0,0,2746.6,0,0,0,0,0,0,0! 2 ! FMFAC = 1 ! 2 ! END !-------- a Data for each source are treated as a separate input subgroup and therefore must end with an input group terminator. SRCNAM is a 12-character name for a source (No default) X is an array holding the source data listed by the column headings (No default) SIGYZI is an array holding the initial sigma-y and sigma-z (m) (Default: 0.,0.) FMFAC is a vertical momentum flux factor (0. or 1.0) used to represent the effect of rain-caps or other physical configurations that reduce momentum rise associated with the actual exit velocity. (Default: 1.0 -- full momentum used) b 0. = No building downwash modeled, 1. = downwash modeled NOTE: must be entered as a REAL number (i.e., with decimal point) c An emission rate must be entered for every pollutant modeled. Enter emission rate of zero for secondary pollutants that are modeled, but not emitted. Units are specified by IPTU (e.g. 1 for g/s).---------------Subgroup (13c)--------------- BUILDING DIMENSION DATA FOR SOURCES SUBJECT TO DOWNWASH -------------------------------------------------------Source a No. Effective building height, width, length and X/Y offset (in meters) every 10 degrees. LENGTH, XBADJ, and YBADJ are only needed for MBDW=2 (PRIME downwash option)------ --------------------------------------------------------------------

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-------- a Building height, width, length, and X/Y offset from the source are treated as a separate input subgroup for each source and therefore must end with an input group terminator. The X/Y offset is the position, relative to the stack, of the center of the upwind face of the projected building, with the x-axis pointing along the flow direction.---------------Subgroup (13d)--------------- a POINT SOURCE: VARIABLE EMISSIONS DATA --------------------------------------- Use this subgroup to describe temporal variations in the emission rates given in 13b. Factors entered multiply the rates in 13b. Skip sources here that have constant emissions. For more elaborate variation in source parameters, use PTEMARB.DAT and NPT2 > 0. IVARY determines the type of variation, and is source-specific: (IVARY) Default: 0 0 = Constant 1 = Diurnal cycle (24 scaling factors: hours 1-24) 2 = Monthly cycle (12 scaling factors: months 1-12) 3 = Hour & Season (4 groups of 24 hourly scaling factors, where first group is DEC-JAN-FEB) 4 = Speed & Stab. (6 groups of 6 scaling factors, where first group is Stability Class A, and the speed classes have upper bounds (m/s) defined in Group 12 5 = Temperature (12 scaling factors, where temperature classes have upper bounds (C) of: 0, 5, 10, 15, 20, 25, 30, 35, 40, 45, 50, 50+)-------- a Data for each species are treated as a separate input subgroup and therefore must end with an input group terminator.-------------------------------------------------------------------------------

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INPUT GROUPS: 14a, 14b, 14c, 14d -- Area source parameters-----------------------------------------------Subgroup (14a)--------------- Number of polygon area sources with parameters specified below (NAR1) No default ! NAR1 = 0 ! Units used for area source emissions below (IARU) Default: 1 ! IARU = 1 ! 1 = g/m**2/s 2 = kg/m**2/hr 3 = lb/m**2/hr 4 = tons/m**2/yr 5 = Odour Unit * m/s (vol. flux/m**2 of odour compound) 6 = Odour Unit * m/min 7 = metric tons/m**2/yr Number of source-species combinations with variable emissions scaling factors provided below in (14d) (NSAR1) Default: 0 ! NSAR1 = 0 ! Number of buoyant polygon area sources with variable location and emission parameters (NAR2) No default ! NAR2 = 0 ! (If NAR2 > 0, ALL parameter data for these sources are read from the file: BAEMARB.DAT)!END!---------------Subgroup (14b)--------------- a AREA SOURCE: CONSTANT DATA ---------------------------- bSource Effect. Base Initial Emission No. Height Elevation Sigma z Rates (m) (m) (m) ------- ------ ------ -------- -----------------

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 a Data for each source are treated as a separate input subgroup and therefore must end with an input group terminator. b An emission rate must be entered for every pollutant modeled. Enter emission rate of zero for secondary pollutants that are modeled, but not emitted. Units are specified by IARU  (e.g. 1 for g/m**2/s).---------------Subgroup (14c)--------------- COORDINATES (km) FOR EACH VERTEX(4) OF EACH POLYGON --------------------------------------------------------Source a No. Ordered list of X followed by list of Y, grouped by source------ -------------------------------------------------------------------- a Data for each source are treated as a separate input subgroup and therefore must end with an input group terminator.---------------Subgroup (14d)--------------- a AREA SOURCE: VARIABLE EMISSIONS DATA -------------------------------------- Use this subgroup to describe temporal variations in the emission rates given in 14b. Factors entered multiply the rates in 14b. Skip sources here that have constant emissions. For more elaborate variation in source parameters, use BAEMARB.DAT and NAR2 > 0. IVARY determines the type of variation, and is source-specific: (IVARY) Default: 0 0 = Constant 1 = Diurnal cycle (24 scaling factors: hours 1-24) 2 = Monthly cycle (12 scaling factors: months 1-12) 3 = Hour & Season (4 groups of 24 hourly scaling factors, where first group is DEC-JAN-FEB) 4 = Speed & Stab. (6 groups of 6 scaling factors, where first group is Stability Class A, and the speed classes have upper

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 bounds (m/s) defined in Group 12 5 = Temperature (12 scaling factors, where temperature classes have upper bounds (C) of: 0, 5, 10, 15, 20, 25, 30, 35, 40, 45, 50, 50+)-------- a Data for each species are treated as a separate input subgroup and therefore must end with an input group terminator.-------------------------------------------------------------------------------INPUT GROUPS: 15a, 15b, 15c -- Line source parameters------------------------------------------Subgroup (15a)--------------- Number of buoyant line sources with variable location and emission parameters (NLN2) No default ! NLN2 = 0 ! (If NLN2 > 0, ALL parameter data for these sources are read from the file: LNEMARB.DAT) Number of buoyant line sources (NLINES) No default ! NLINES = 0 ! Units used for line source emissions below (ILNU) Default: 1 ! ILNU = 3 ! 1 = g/s 2 = kg/hr 3 = lb/hr 4 = tons/yr 5 = Odour Unit * m**3/s (vol. flux of odour compound) 6 = Odour Unit * m**3/min 7 = metric tons/yr Number of source-species combinations with variable emissions scaling factors provided below in (15c) (NSLN1) Default: 0 ! NSLN1 = 0 ! Maximum number of segments used to model

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 each line (MXNSEG) Default: 7 ! MXNSEG = 7 ! The following variables are required only if NLINES > 0. They are used in the buoyant line source plume rise calculations. Number of distances at which Default: 6 ! NLRISE = 6 ! transitional rise is computed Average building length (XL) No default ! XL = .0 ! (in meters) Average building height (HBL) No default ! HBL = .0 ! (in meters) Average building width (WBL) No default ! WBL = .0 ! (in meters) Average line source width (WML) No default ! WML = .0 ! (in meters) Average separation between buildings (DXL) No default ! DXL = .0 ! (in meters) Average buoyancy parameter (FPRIMEL) No default ! FPRIMEL = .0 ! (in m**4/s**3)!END!---------------Subgroup (15b)--------------- BUOYANT LINE SOURCE: CONSTANT DATA ---------------------------------- aSource Beg. X Beg. Y End. X End. Y Release Base Emission No. Coordinate Coordinate Coordinate Coordinate Height Elevation Rates (km) (km) (km) (km) (m) (m) ------ ---------- ---------- --------- ---------- ------- --------- ----------------- a Data for each source are treated as a separate input subgroup and therefore must end with an input group terminator. b An emission rate must be entered for every pollutant modeled.

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 Enter emission rate of zero for secondary pollutants that are modeled, but not emitted. Units are specified by ILNTU  (e.g. 1 for g/s).---------------Subgroup (15c)--------------- a BUOYANT LINE SOURCE: VARIABLE EMISSIONS DATA ---------------------------------------------- Use this subgroup to describe temporal variations in the emission rates given in 15b. Factors entered multiply the rates in 15b. Skip sources here that have constant emissions. IVARY determines the type of variation, and is source-specific: (IVARY) Default: 0 0 = Constant 1 = Diurnal cycle (24 scaling factors: hours 1-24) 2 = Monthly cycle (12 scaling factors: months 1-12) 3 = Hour & Season (4 groups of 24 hourly scaling factors, where first group is DEC-JAN-FEB) 4 = Speed & Stab. (6 groups of 6 scaling factors, where first group is Stability Class A, and the speed classes have upper bounds (m/s) defined in Group 12 5 = Temperature (12 scaling factors, where temperature classes have upper bounds (C) of: 0, 5, 10, 15, 20, 25, 30, 35, 40, 45, 50, 50+)-------- a Data for each species are treated as a separate input subgroup and therefore must end with an input group terminator.-------------------------------------------------------------------------------INPUT GROUPS: 16a, 16b, 16c -- Volume source parameters------------------------------------------Subgroup (16a)---------------

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 Number of volume sources with parameters provided in 16b,c (NVL1) No default ! NVL1 = 0 ! Units used for volume source emissions below in 16b (IVLU) Default: 1 ! IVLU = 3 ! 1 = g/s 2 = kg/hr 3 = lb/hr 4 = tons/yr 5 = Odour Unit * m**3/s (vol. flux of odour compound) 6 = Odour Unit * m**3/min 7 = metric tons/yr Number of source-species combinations with variable emissions scaling factors provided below in (16c) (NSVL1) Default: 0 ! NSVL1 = 0 ! Number of volume sources with variable location and emission parameters (NVL2) No default ! NVL2 = 0 ! (If NVL2 > 0, ALL parameter data for these sources are read from the VOLEMARB.DAT file(s) )!END!---------------Subgroup (16b)--------------- a VOLUME SOURCE: CONSTANT DATA ------------------------------ b X Y Effect. Base Initial Initial Emission Coordinate Coordinate Height Elevation Sigma y Sigma z Rates (km) (km) (m) (m) (m) (m)  ---------- ---------- ------ ------ -------- -------- ---------------- a Data for each source are treated as a separate input subgroup and therefore must end with an input group terminator. b An emission rate must be entered for every pollutant modeled.

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 Enter emission rate of zero for secondary pollutants that are modeled, but not emitted. Units are specified by IVLU  (e.g. 1 for g/s).---------------Subgroup (16c)--------------- a VOLUME SOURCE: VARIABLE EMISSIONS DATA ---------------------------------------- Use this subgroup to describe temporal variations in the emission rates given in 16b. Factors entered multiply the rates in 16b. Skip sources here that have constant emissions. For more elaborate variation in source parameters, use VOLEMARB.DAT and NVL2 > 0. IVARY determines the type of variation, and is source-specific: (IVARY) Default: 0 0 = Constant 1 = Diurnal cycle (24 scaling factors: hours 1-24) 2 = Monthly cycle (12 scaling factors: months 1-12) 3 = Hour & Season (4 groups of 24 hourly scaling factors, where first group is DEC-JAN-FEB) 4 = Speed & Stab. (6 groups of 6 scaling factors, where first group is Stability Class A, and the speed classes have upper bounds (m/s) defined in Group 12 5 = Temperature (12 scaling factors, where temperature classes have upper bounds (C) of: 0, 5, 10, 15, 20, 25, 30, 35, 40, 45, 50, 50+)-------- a Data for each species are treated as a separate input subgroup and therefore must end with an input group terminator.-------------------------------------------------------------------------------INPUT GROUPS: 17a & 17b -- Non-gridded (discrete) receptor information--------------------------------------Subgroup (17a)---------------

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 Number of non-gridded receptors (NREC) No default ! NREC = 291 !!END!---------------Subgroup (17b)--------------- a NON-GRIDDED (DISCRETE) RECEPTOR DATA ------------------------------------ X Y Ground Height bReceptor Coordinate Coordinate Elevation Above Ground No. (km) (km) (m) (m)-------- ---------- ---------- --------- ------------ 1 ! X = 359.836, -362.005, 274, 0 ! !END! HG1 2 ! X = 360.575, -361.972, 299, 0 ! !END! HG2 3 ! X = 361.314, -361.939, 328, 0 ! !END! HG3 4 ! X = 362.053, -361.906, 365, 0 ! !END! HG4 5 ! X = 358.316, -361.150, 250, 0 ! !END! HG5 6 ! X = 359.055, -361.117, 278, 0 ! !END! HG6 7 ! X = 359.794, -361.084, 335, 0 ! !END! HG7 8 ! X = 360.533, -361.051, 307, 0 ! !END! HG8 9 ! X = 361.272, -361.018, 345, 0 ! !END! HG9 10 ! X = 357.537, -360.261, 261, 0 ! !END! HG10 11 ! X = 358.275, -360.228, 271, 0 ! !END! HG11 12 ! X = 359.014, -360.195, 274, 0 ! !END! HG12 13 ! X = 359.753, -360.162, 331, 0 ! !END! HG13 14 ! X = 360.492, -360.129, 327, 0 ! !END! HG14 15 ! X = 361.231, -360.096, 304, 0 ! !END! HG15 16 ! X = 361.970, -360.063, 335, 0 ! !END! HG16 17 ! X = 362.709, -360.030, 312, 0 ! !END! HG17 18 ! X = 363.448, -359.997, 340, 0 ! !END! HG18 19 ! X = 364.187, -359.963, 361, 0 ! !END! HG19 20 ! X = 364.926, -359.930, 382, 0 ! !END! HG20 21 ! X = 357.496, -359.340, 274, 0 ! !END! HG21 22 ! X = 358.235, -359.307, 274, 0 ! !END! HG22 23 ! X = 358.973, -359.274, 335, 0 ! !END! HG23 24 ! X = 359.712, -359.241, 294, 0 ! !END! HG24 25 ! X = 360.451, -359.208, 304, 0 ! !END! HG25 26 ! X = 361.190, -359.175, 279, 0 ! !END! HG26 27 ! X = 361.929, -359.142, 304, 0 ! !END! HG27 28 ! X = 362.668, -359.109, 318, 0 ! !END! HG28 29 ! X = 363.406, -359.075, 335, 0 ! !END! HG29 30 ! X = 364.145, -359.042, 347, 0 ! !END! HG30 31 ! X = 364.884, -359.008, 340, 0 ! !END! HG31 32 ! X = 358.932, -358.353, 247, 0 ! !END! HG32

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 33 ! X = 359.671, -358.320, 271, 0 ! !END! HG33 34 ! X = 360.410, -358.287, 275, 0 ! !END! HG34 35 ! X = 361.149, -358.254, 274, 0 ! !END! HG35 36 ! X = 361.887, -358.220, 277, 0 ! !END! HG36 37 ! X = 362.626, -358.187, 304, 0 ! !END! HG37 38 ! X = 363.365, -358.154, 330, 0 ! !END! HG38 39 ! X = 364.104, -358.121, 357, 0 ! !END! HG39 40 ! X = 364.842, -358.087, 384, 0 ! !END! HG40 41 ! X = 365.581, -358.054, 372, 0 ! !END! HG41 42 ! X = 356.675, -357.530, 274, 0 ! !END! HG42 43 ! X = 357.414, -357.497, 293, 0 ! !END! HG43 44 ! X = 358.153, -357.464, 272, 0 ! !END! HG44 45 ! X = 358.891, -357.431, 271, 0 ! !END! HG45 46 ! X = 359.630, -357.398, 274, 0 ! !END! HG46 47 ! X = 360.369, -357.365, 327, 0 ! !END! HG47 48 ! X = 361.107, -357.332, 316, 0 ! !END! HG48 49 ! X = 361.846, -357.299, 304, 0 ! !END! HG49 50 ! X = 362.585, -357.266, 354, 0 ! !END! HG50 51 ! X = 363.323, -357.233, 346, 0 ! !END! HG51 52 ! X = 364.062, -357.199, 335, 0 ! !END! HG52 53 ! X = 364.801, -357.166, 344, 0 ! !END! HG53 54 ! X = 365.539, -357.132, 364, 0 ! !END! HG54 55 ! X = 357.373, -356.576, 243, 0 ! !END! HG55 56 ! X = 358.112, -356.543, 335, 0 ! !END! HG56 57 ! X = 358.850, -356.510, 324, 0 ! !END! HG57 58 ! X = 359.589, -356.477, 335, 0 ! !END! HG58 59 ! X = 360.327, -356.444, 341, 0 ! !END! HG59 60 ! X = 361.066, -356.411, 333, 0 ! !END! HG60 61 ! X = 361.805, -356.378, 306, 0 ! !END! HG61 62 ! X = 362.543, -356.345, 304, 0 ! !END! HG62 63 ! X = 363.282, -356.311, 365, 0 ! !END! HG63 64 ! X = 364.020, -356.278, 304, 0 ! !END! HG64 65 ! X = 364.759, -356.245, 309, 0 ! !END! HG65 66 ! X = 365.497, -356.211, 307, 0 ! !END! HG66 67 ! X = 357.332, -355.654, 270, 0 ! !END! HG67 68 ! X = 358.071, -355.622, 274, 0 ! !END! HG68 69 ! X = 358.809, -355.589, 301, 0 ! !END! HG69 70 ! X = 359.548, -355.556, 274, 0 ! !END! HG70 71 ! X = 360.286, -355.523, 274, 0 ! !END! HG71 72 ! X = 361.025, -355.490, 312, 0 ! !END! HG72 73 ! X = 361.763, -355.457, 274, 0 ! !END! HG73 74 ! X = 362.502, -355.423, 322, 0 ! !END! HG74 75 ! X = 363.240, -355.390, 304, 0 ! !END! HG75 76 ! X = 363.979, -355.357, 275, 0 ! !END! HG76 77 ! X = 364.717, -355.323, 304, 0 ! !END! HG77 78 ! X = 365.456, -355.290, 290, 0 ! !END! HG78 79 ! X = 362.460, -354.502, 249, 0 ! !END! HG79 80 ! X = 363.199, -354.469, 274, 0 ! !END! HG80

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 81 ! X = -159.867, -584.484, 454, 0 ! !END! WM1 82 ! X = -159.108, -584.499, 486, 0 ! !END! WM2 83 ! X = -158.348, -584.513, 487, 0 ! !END! WM3 84 ! X = -157.589, -584.528, 478, 0 ! !END! WM4 85 ! X = -156.829, -584.542, 518, 0 ! !END! WM5 86 ! X = -156.070, -584.557, 518, 0 ! !END! WM6 87 ! X = -161.368, -583.531, 510, 0 ! !END! WM7 88 ! X = -160.609, -583.546, 493, 0 ! !END! WM8 89 ! X = -159.849, -583.560, 488, 0 ! !END! WM9 90 ! X = -159.090, -583.575, 615, 0 ! !END! WM10 91 ! X = -158.331, -583.589, 522, 0 ! !END! WM11 92 ! X = -157.571, -583.604, 494, 0 ! !END! WM12 93 ! X = -156.812, -583.618, 609, 0 ! !END! WM13 94 ! X = -156.052, -583.633, 518, 0 ! !END! WM14 95 ! X = -162.110, -582.592, 487, 0 ! !END! WM15 96 ! X = -161.350, -582.607, 518, 0 ! !END! WM16 97 ! X = -160.591, -582.622, 609, 0 ! !END! WM17 98 ! X = -159.832, -582.636, 554, 0 ! !END! WM18 99 ! X = -159.072, -582.651, 578, 0 ! !END! WM19 100 ! X = -158.313, -582.666, 557, 0 ! !END! WM20 101 ! X = -157.554, -582.680, 571, 0 ! !END! WM21 102 ! X = -156.794, -582.694, 670, 0 ! !END! WM22 103 ! X = -156.035, -582.709, 518, 0 ! !END! WM23 104 ! X = -160.573, -581.698, 518, 0 ! !END! WM24 105 ! X = -159.814, -581.712, 548, 0 ! !END! WM25 106 ! X = -159.054, -581.727, 548, 0 ! !END! WM26 107 ! X = -158.295, -581.742, 518, 0 ! !END! WM27 108 ! X = -160.555, -580.774, 517, 0 ! !END! WM28 109 ! X = -159.796, -580.789, 579, 0 ! !END! WM29 110 ! X = -159.037, -580.803, 613, 0 ! !END! WM30 111 ! X = -158.278, -580.818, 548, 0 ! !END! WM31 112 ! X = -157.518, -580.832, 523, 0 ! !END! WM32 113 ! X = -161.296, -579.835, 542, 0 ! !END! WM33 114 ! X = -160.537, -579.850, 545, 0 ! !END! WM34 115 ! X = -159.778, -579.865, 552, 0 ! !END! WM35 116 ! X = -152.895, -577.222, 579, 0 ! !END! WM36 117 ! X = -155.913, -576.242, 609, 0 ! !END! WM37 118 ! X = -155.154, -576.256, 654, 0 ! !END! WM38 119 ! X = -154.396, -576.270, 621, 0 ! !END! WM39 120 ! X = -153.637, -576.284, 629, 0 ! !END! WM40 121 ! X = -152.878, -576.298, 579, 0 ! !END! WM41 122 ! X = -152.119, -576.312, 560, 0 ! !END! WM42 123 ! X = -156.654, -575.304, 615, 0 ! !END! WM43 124 ! X = -155.896, -575.318, 641, 0 ! !END! WM44 125 ! X = -155.137, -575.332, 640, 0 ! !END! WM45 126 ! X = -154.378, -575.346, 662, 0 ! !END! WM46 127 ! X = -153.620, -575.361, 618, 0 ! !END! WM47 128 ! X = -152.861, -575.375, 630, 0 ! !END! WM48

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 129 ! X = -152.102, -575.389, 534, 0 ! !END! WM49 130 ! X = -156.637, -574.380, 606, 0 ! !END! WM50 131 ! X = -155.878, -574.394, 566, 0 ! !END! WM51 132 ! X = -155.120, -574.408, 633, 0 ! !END! WM52 133 ! X = -154.361, -574.423, 670, 0 ! !END! WM53 134 ! X = -153.603, -574.437, 609, 0 ! !END! WM54 135 ! X = -152.844, -574.451, 579, 0 ! !END! WM55 136 ! X = -152.085, -574.465, 535, 0 ! !END! WM56 137 ! X = -155.102, -573.485, 548, 0 ! !END! WM57 138 ! X = -154.344, -573.499, 518, 0 ! !END! WM58 139 ! X = -153.585, -573.513, 506, 0 ! !END! WM59 140 ! X = 318.344, -456.077, 555, 0 ! !END! UB1 141 ! X = 319.091, -456.047, 589, 0 ! !END! UB2 142 ! X = 321.334, -455.959, 563, 0 ! !END! UB3 143 ! X = 318.308, -455.154, 549, 0 ! !END! UB4 144 ! X = 319.055, -455.125, 487, 0 ! !END! UB5 145 ! X = 319.803, -455.096, 487, 0 ! !END! UB6 146 ! X = 320.551, -455.067, 490, 0 ! !END! UB7 147 ! X = 318.272, -454.232, 650, 0 ! !END! UB8 148 ! X = 319.019, -454.203, 563, 0 ! !END! UB9 149 ! X = 319.767, -454.174, 540, 0 ! !END! UB10 150 ! X = 320.514, -454.144, 502, 0 ! !END! UB11 151 ! X = 321.262, -454.115, 526, 0 ! !END! UB12 152 ! X = 322.757, -454.056, 534, 0 ! !END! UB13 153 ! X = 323.504, -454.026, 563, 0 ! !END! UB14 154 ! X = 318.236, -453.310, 548, 0 ! !END! UB15 155 ! X = 318.983, -453.281, 628, 0 ! !END! UB16 156 ! X = 319.731, -453.252, 623, 0 ! !END! UB17 157 ! X = 320.478, -453.222, 579, 0 ! !END! UB18 158 ! X = 321.225, -453.193, 469, 0 ! !END! UB19 159 ! X = 321.973, -453.163, 457, 0 ! !END! UB20 160 ! X = 322.720, -453.134, 573, 0 ! !END! UB21 161 ! X = 323.468, -453.104, 605, 0 ! !END! UB22 162 ! X = 324.215, -453.074, 588, 0 ! !END! UB23 163 ! X = 318.200, -452.388, 608, 0 ! !END! UB24 164 ! X = 318.947, -452.359, 660, 0 ! !END! UB25 165 ! X = 319.694, -452.329, 598, 0 ! !END! UB26 166 ! X = 320.442, -452.300, 599, 0 ! !END! UB27 167 ! X = 321.189, -452.271, 639, 0 ! !END! UB28 168 ! X = 321.937, -452.241, 457, 0 ! !END! UB29 169 ! X = 322.684, -452.212, 568, 0 ! !END! UB30 170 ! X = 318.164, -451.466, 730, 0 ! !END! UB31 171 ! X = 318.911, -451.437, 681, 0 ! !END! UB32 172 ! X = 319.658, -451.407, 640, 0 ! !END! UB33 173 ! X = 320.406, -451.378, 625, 0 ! !END! UB34 174 ! X = 321.153, -451.348, 426, 0 ! !END! UB35 175 ! X = 321.900, -451.319, 555, 0 ! !END! UB36 176 ! X = 322.647, -451.289, 612, 0 ! !END! UB37

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 177 ! X = 317.380, -450.573, 667, 0 ! !END! UB38 178 ! X = 318.128, -450.544, 580, 0 ! !END! UB39 179 ! X = 318.875, -450.514, 656, 0 ! !END! UB40 180 ! X = 319.622, -450.485, 640, 0 ! !END! UB41 181 ! X = 320.369, -450.456, 487, 0 ! !END! UB42 182 ! X = 321.116, -450.426, 457, 0 ! !END! UB43 183 ! X = 321.864, -450.397, 654, 0 ! !END! UB44 184 ! X = 322.611, -450.367, 548, 0 ! !END! UB45 185 ! X = 323.358, -450.338, 622, 0 ! !END! UB46 186 ! X = 324.105, -450.308, 683, 0 ! !END! UB47 187 ! X = 317.345, -449.651, 579, 0 ! !END! UB48 188 ! X = 318.092, -449.621, 554, 0 ! !END! UB49 189 ! X = 318.839, -449.592, 609, 0 ! !END! UB50 190 ! X = 319.586, -449.563, 622, 0 ! !END! UB51 191 ! X = 320.333, -449.534, 427, 0 ! !END! UB52 192 ! X = 321.080, -449.504, 555, 0 ! !END! UB53 193 ! X = 321.827, -449.475, 502, 0 ! !END! UB54 194 ! X = 322.574, -449.445, 639, 0 ! !END! UB55 195 ! X = 323.322, -449.416, 580, 0 ! !END! UB56 196 ! X = 324.069, -449.386, 639, 0 ! !END! UB57 197 ! X = 318.803, -448.670, 548, 0 ! !END! UB58 198 ! X = 319.550, -448.641, 548, 0 ! !END! UB59 199 ! X = 320.297, -448.612, 438, 0 ! !END! UB60 200 ! X = 321.044, -448.582, 579, 0 ! !END! UB61 201 ! X = 322.538, -448.523, 620, 0 ! !END! UB62 202 ! X = 320.261, -447.689, 579, 0 ! !END! UB63 203 ! X = 321.007, -447.660, 426, 0 ! !END! UB64 204 ! X = 321.754, -447.631, 611, 0 ! !END! UB65 205 ! X = 318.731, -446.826, 604, 0 ! !END! UB66 206 ! X = 319.477, -446.797, 548, 0 ! !END! UB67 207 ! X = 320.224, -446.767, 488, 0 ! !END! UB68 208 ! X = 320.971, -446.738, 402, 0 ! !END! UB69 209 ! X = 321.718, -446.708, 579, 0 ! !END! UB70 210 ! X = 322.465, -446.679, 573, 0 ! !END! UB71 211 ! X = 323.212, -446.649, 609, 0 ! !END! UB72 212 ! X = 269.710, -618.629, 365, 0 ! !END! CC1 213 ! X = 270.473, -618.605, 365, 0 ! !END! CC2 214 ! X = 271.235, -618.580, 368, 0 ! !END! CC3 215 ! X = 268.155, -617.755, 411, 0 ! !END! CC4 216 ! X = 268.917, -617.730, 462, 0 ! !END! CC5 217 ! X = 269.680, -617.705, 431, 0 ! !END! CC6 218 ! X = 270.443, -617.681, 518, 0 ! !END! CC7 219 ! X = 271.205, -617.656, 487, 0 ! !END! CC8 220 ! X = 271.968, -617.631, 396, 0 ! !END! CC9 221 ! X = 265.075, -616.929, 518, 0 ! !END! CC10 222 ! X = 265.838, -616.904, 523, 0 ! !END! CC11 223 ! X = 266.600, -616.880, 548, 0 ! !END! CC12 224 ! X = 267.363, -616.855, 579, 0 ! !END! CC13

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 225 ! X = 268.125, -616.831, 547, 0 ! !END! CC14 226 ! X = 268.888, -616.806, 538, 0 ! !END! CC15 227 ! X = 269.650, -616.781, 640, 0 ! !END! CC16 228 ! X = 270.412, -616.757, 608, 0 ! !END! CC17 229 ! X = 259.709, -616.173, 335, 0 ! !END! CC18 230 ! X = 260.472, -616.149, 431, 0 ! !END! CC19 231 ! X = 261.234, -616.125, 457, 0 ! !END! CC20 232 ! X = 261.996, -616.101, 414, 0 ! !END! CC21 233 ! X = 262.759, -616.077, 426, 0 ! !END! CC22 234 ! X = 263.521, -616.053, 426, 0 ! !END! CC23 235 ! X = 264.283, -616.029, 388, 0 ! !END! CC24 236 ! X = 265.046, -616.005, 388, 0 ! !END! CC25 237 ! X = 265.808, -615.980, 365, 0 ! !END! CC26 238 ! X = 266.571, -615.956, 386, 0 ! !END! CC27 239 ! X = 267.333, -615.931, 396, 0 ! !END! CC28 240 ! X = 268.095, -615.907, 426, 0 ! !END! CC29 241 ! X = 268.858, -615.882, 446, 0 ! !END! CC30 242 ! X = 269.620, -615.857, 441, 0 ! !END! CC31 243 ! X = 270.382, -615.833, 457, 0 ! !END! CC32 244 ! X = 271.145, -615.808, 465, 0 ! !END! CC33 245 ! X = 271.907, -615.783, 442, 0 ! !END! CC34 246 ! X = 272.670, -615.758, 426, 0 ! !END! CC35 247 ! X = 259.680, -615.249, 304, 0 ! !END! CC36 248 ! X = 260.443, -615.225, 304, 0 ! !END! CC37 249 ! X = 261.205, -615.201, 319, 0 ! !END! CC38 250 ! X = 261.967, -615.177, 334, 0 ! !END! CC39 251 ! X = 262.730, -615.153, 370, 0 ! !END! CC40 252 ! X = 263.492, -615.129, 405, 0 ! !END! CC41 253 ! X = 264.254, -615.105, 409, 0 ! !END! CC42 254 ! X = 265.016, -615.081, 450, 0 ! !END! CC43 255 ! X = 265.779, -615.056, 518, 0 ! !END! CC44 256 ! X = 266.541, -615.032, 609, 0 ! !END! CC45 257 ! X = 267.303, -615.007, 534, 0 ! !END! CC46 258 ! X = 268.066, -614.983, 517, 0 ! !END! CC47 259 ! X = 268.828, -614.958, 575, 0 ! !END! CC48 260 ! X = 269.590, -614.933, 600, 0 ! !END! CC49 261 ! X = 270.352, -614.909, 609, 0 ! !END! CC50 262 ! X = 271.115, -614.884, 609, 0 ! !END! CC51 263 ! X = 271.877, -614.859, 561, 0 ! !END! CC52 264 ! X = 260.414, -614.301, 335, 0 ! !END! CC53 265 ! X = 261.176, -614.277, 432, 0 ! !END! CC54 266 ! X = 261.938, -614.253, 487, 0 ! !END! CC55 267 ! X = 262.700, -614.229, 499, 0 ! !END! CC56 268 ! X = 263.463, -614.205, 514, 0 ! !END! CC57 269 ! X = 264.225, -614.181, 442, 0 ! !END! CC58 270 ! X = 264.987, -614.157, 439, 0 ! !END! CC59 271 ! X = 265.749, -614.132, 395, 0 ! !END! CC60 272 ! X = 266.511, -614.108, 400, 0 ! !END! CC61

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 273 ! X = 267.274, -614.083, 426, 0 ! !END! CC62 274 ! X = 268.036, -614.059, 487, 0 ! !END! CC63 275 ! X = 268.798, -614.034, 548, 0 ! !END! CC64 276 ! X = 269.560, -614.010, 548, 0 ! !END! CC65 277 ! X = 270.322, -613.985, 548, 0 ! !END! CC66 278 ! X = 271.085, -613.960, 535, 0 ! !END! CC67 279 ! X = 261.147, -613.353, 304, 0 ! !END! CC68 280 ! X = 261.909, -613.329, 334, 0 ! !END! CC69 281 ! X = 262.671, -613.305, 396, 0 ! !END! CC70 282 ! X = 263.433, -613.281, 457, 0 ! !END! CC71 283 ! X = 264.195, -613.257, 457, 0 ! !END! CC72 284 ! X = 264.958, -613.233, 426, 0 ! !END! CC73 285 ! X = 265.720, -613.208, 411, 0 ! !END! CC74 286 ! X = 266.482, -613.184, 406, 0 ! !END! CC75 287 ! X = 267.244, -613.159, 396, 0 ! !END! CC76 288 ! X = 268.006, -613.135, 401, 0 ! !END! CC77 289 ! X = 268.768, -613.110, 397, 0 ! !END! CC78 290 ! X = 261.118, -612.429, 322, 0 ! !END! CC79 291 ! X = 261.880, -612.405, 334, 0 ! !END! CC80------------- a Data for each receptor are treated as a separate input subgroup and therefore must end with an input group terminator. b Receptor height above ground is optional. If no value is entered, the receptor is placed on the ground.

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American Electric Power D-1 Trinity Consultants 

Northeastern Power Station 083701.0024 

APPENDIX D – SAMPLE CALPOST CONTROL FILE
01_CC_vis.INP

AEP Northeastern Station - BART DeterminationVisibility Impact---------------- Run title (3 lines) ------------------------------------------ CALPOST MODEL CONTROL FILE ---------------------------------------------------------------------------------------------------------INPUT GROUP: 0 -- Input and Output File Names--------------Input Files-----------File Default File Name---- -----------------Conc/Dep Flux File MODEL.DAT ! MODDAT =..\2001_NE_NOX.DAT !Relative Humidity File VISB.DAT ! VISDAT =..\2001_NE_NOX.VIS ! Background Data File BACK.DAT *BACKDAT = *Transmissometer/ VSRN.DAT *VSRDAT = *Nephelometer Data FileOutput Files------------File Default File Name---- -----------------List File CALPOST.LST ! PSTLST =01_CC_vis.lst !Pathname for Timeseries Files (blank) * TSPATH = *(activate with exclamation points only ifproviding NON-BLANK character string)Pathname for Plot Files (blank) * PLPATH = *(activate with exclamation points only if providing NON-BLANK character string)User Character String (U) to augment default filenames(activate with exclamation points only if providing NON-BLANK character string)Timeseries TSttUUUU.DAT * TSUNAM = *Top Nth Rank Plot RttUUUUU.DAT or RttiiUUU.GRD * TUNAM = *

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01_CC_vis.INP

Exceedance Plot XttUUUUU.DAT or XttUUUUU.GRD * XUNAM = *Echo Plot jjjtthhU.DAT(Specific Days) or jjjtthhU.GRD * EUNAM = *Visibility Plot V24UUUUU.DAT * VUNAM = *(Daily Peak Summary) --------------------------------------------------------------------------------All file names will be converted to lower case if LCFILES = TOtherwise, if LCFILES = F, file names will be converted to UPPER CASE T = lower case ! LCFILES = T ! F = UPPER CASENOTE: (1) file/path names can be up to 70 characters in lengthNOTE: (2) Filenames for ALL PLOT and TIMESERIES FILES are constructed using a template that includes a pathname, user-supplied  character(s), and fixed strings (tt,ii,jjj, and hh), where tt = Averaging Period (e.g. 03) ii = Rank (e.g. 02) jjj= Julian Day hh = Hour(ending) are determined internally based on selections made below. If a path or user-supplied character(s) are supplied, each must contain at least 1 non-blank character.!END!--------------------------------------------------------------------------------INPUT GROUP: 1 -- General run control parameters-------------- Option to run all periods found in the met. file(s) (METRUN) Default: 0 ! METRUN = 0 ! METRUN = 0 - Run period explicitly defined below METRUN = 1 - Run all periods in CALPUFF data file(s) Starting date: Year (ISYR) -- No default ! ISYR = 2001 ! (used only if Month (ISMO) -- No default ! ISMO = 1 ! METRUN = 0) Day (ISDY) -- No default ! ISDY = 1 ! Hour (ISHR) -- No default ! ISHR = 0 ! Number of hours to process (NHRS) -- No default ! NHRS = 8753 ! Process every hour of data?(NREP) -- Default: 1 ! NREP = 1 ! (1 = every hour processed, 2 = every 2nd hour processed,

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01_CC_vis.INP

 5 = every 5th hour processed, etc.)Species & Concentration/Deposition Information---------------------------------------------- Species to process (ASPEC) -- No default ! ASPEC = VISIB ! (ASPEC = VISIB for visibility processing) Layer/deposition code (ILAYER) -- Default: 1 ! ILAYER = 1 ! '1' for CALPUFF concentrations, '-1' for dry deposition fluxes, '-2' for wet deposition fluxes, '-3' for wet+dry deposition fluxes. Scaling factors of the form: -- Defaults: ! A = 0.0 ! X(new) = X(old) * A + B A = 0.0 ! B = 0.0 ! (NOT applied if A = B = 0.0) B = 0.0 Add Hourly Background Concentrations/Fluxes? (LBACK) -- Default: F ! LBACK = F !Receptor information-------------------- Gridded receptors processed? (LG) -- Default: F ! LG = F ! Discrete receptors processed? (LD) -- Default: F ! LD = T ! CTSG Complex terrain receptors processed? (LCT) -- Default: F ! LCT = F !--Report results by DISCRETE receptor RING? (only used when LD = T) (LDRING) -- Default: F ! LDRING = F !--Select range of DISCRETE receptors (only used when LD = T): Select ALL DISCRETE receptors by setting NDRECP flag to -1; OR Select SPECIFIC DISCRETE receptors by entering a flag (0,1) for each 0 = discrete receptor not processed 1 = discrete receptor processed using repeated value notation to select blocks of receptors: 416*0, 1048*1, 1482*0 Flag for all receptors after the last one assigned is set to 0 (NDRECP) -- Default: -1 ! NDRECP = 80*0, 59*0, 72*0, 80*1!--Select range of GRIDDED receptors (only used when LG = T):

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01_CC_vis.INP

 X index of LL corner (IBGRID) -- Default: -1 ! IBGRID = -1 ! (-1 OR 1 <= IBGRID <= NX) Y index of LL corner (JBGRID) -- Default: -1 ! JBGRID = -1 ! (-1 OR 1 <= JBGRID <= NY) X index of UR corner (IEGRID) -- Default: -1 ! IEGRID = -1 ! (-1 OR 1 <= IEGRID <= NX) Y index of UR corner (JEGRID) -- Default: -1 ! JEGRID = -1 ! (-1 OR 1 <= JEGRID <= NY) Note: Entire grid is processed if IBGRID=JBGRID=IEGRID=JEGRID=-1--Specific gridded receptors can also be excluded from CALPOST processing by filling a processing grid array with 0s and 1s. If the processing flag for receptor index (i,j) is 1 (ON), that receptor will be processed if it lies within the range delineated by IBGRID, JBGRID,IEGRID,JEGRID and if LG=T. If it is 0 (OFF), it will not be processed in the run. By default, all array values are set to 1 (ON). Number of gridded receptor rows provided in Subgroup (1a) to identify specific gridded receptors to process (NGONOFF) -- Default: 0 ! NGONOFF = 0 !!END!--------------Subgroup (1a) -- Specific gridded receptors included/excluded-------------- Specific gridded receptors are excluded from CALPOST processing by filling a processing grid array with 0s and 1s. A total of NGONOFF lines are read here. Each line corresponds to one 'row' in the sampling grid, starting with the NORTHERNMOST row that contains receptors that you wish to exclude, and finishing with row 1 to the SOUTH (no intervening rows may be skipped). Within a row, each receptor position is assigned either a 0 or 1, starting with the westernmost receptor. 0 = gridded receptor not processed 1 = gridded receptor processed Repeated value notation may be used to select blocks of receptors: 23*1, 15*0, 12*1 Because all values are initially set to 1, any receptors north of

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01_CC_vis.INP

 the first row entered, or east of the last value provided in a row, remain ON. (NGXRECP) -- Default: 1-------------------------------------------------------------------------------INPUT GROUP: 2 -- Visibility Parameters (ASPEC = VISIB)-------------- Maximum relative humidity (%) used in particle growth curve (RHMAX) -- Default: 98 ! RHMAX = 95.0 ! Modeled species to be included in computing the light extinction Include SULFATE? (LVSO4) -- Default: T ! LVSO4 = T ! Include NITRATE? (LVNO3) -- Default: T ! LVNO3 = T ! Include ORGANIC CARBON? (LVOC) -- Default: T ! LVOC = T ! Include COARSE PARTICLES? (LVPMC) -- Default: T ! LVPMC = T ! Include FINE PARTICLES? (LVPMF) -- Default: T ! LVPMF = T ! Include ELEMENTAL CARBON? (LVEC) -- Default: T ! LVEC = T ! And, when ranking for TOP-N, TOP-50, and Exceedance tables, Include BACKGROUND? (LVBK) -- Default: T ! LVBK = T ! Species name used for particulates in MODEL.DAT file COARSE (SPECPMC) -- Default: PMC ! SPECPMC = PMC ! FINE (SPECPMF) -- Default: PMF ! SPECPMF = PMF !Extinction Efficiency (1/Mm per ug/m**3)---------------------------------------- MODELED particulate species: PM COARSE (EEPMC) -- Default: 0.6 ! EEPMC = 0.6 ! PM FINE (EEPMF) -- Default: 1.0 ! EEPMF = 1.0 ! BACKGROUND particulate species: PM COARSE (EEPMCBK) -- Default: 0.6 ! EEPMCBK = 0.6 ! Other species: AMMONIUM SULFATE (EESO4) -- Default: 3.0 ! EESO4 = 3.0 ! AMMONIUM NITRATE (EENO3) -- Default: 3.0 ! EENO3 = 3.0 ! ORGANIC CARBON (EEOC) -- Default: 4.0 ! EEOC = 4.0 ! SOIL (EESOIL)-- Default: 1.0 ! EESOIL = 1.0 ! ELEMENTAL CARBON (EEEC) -- Default: 10. ! EEEC = 10.0 !Background Extinction Computation--------------------------------- Method used for background light extinction (MVISBK) -- Default: 2 ! MVISBK = 6 !

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01_CC_vis.INP

 1 = Supply single light extinction and hygroscopic fraction - IWAQM (1993) RH adjustment applied to hygroscopic background and modeled sulfate and nitrate 2 = Compute extinction from speciated PM measurements (A) - Hourly RH adjustment applied to observed and modeled sulfate and nitrate - RH factor is capped at RHMAX 3 = Compute extinction from speciated PM measurements (B) - Hourly RH adjustment applied to observed and modeled sulfate and nitrate - Receptor-hour excluded if RH>RHMAX - Receptor-day excluded if fewer than 6 valid receptor-hours 4 = Read hourly transmissometer background extinction measurements - Hourly RH adjustment applied to modeled sulfate and nitrate - Hour excluded if measurement invalid (missing, interference, or large RH) - Receptor-hour excluded if RH>RHMAX - Receptor-day excluded if fewer than 6 valid receptor-hours 5 = Read hourly nephelometer background extinction measurements - Rayleigh extinction value (BEXTRAY) added to measurement - Hourly RH adjustment applied to modeled sulfate and nitrate - Hour excluded if measurement invalid (missing, interference, or large RH) - Receptor-hour excluded if RH>RHMAX - Receptor-day excluded if fewer than 6 valid receptor-hours 6 = Compute extinction from speciated PM measurements - FLAG RH adjustment factor applied to observed and modeled sulfate and nitrate Additional inputs used for MVISBK = 1: -------------------------------------- Background light extinction (1/Mm) (BEXTBK) -- No default ! BEXTBK = 12.0 ! Percentage of particles affected by relative humidity (RHFRAC) -- No default ! RHFRAC = 10.0 ! Additional inputs used for MVISBK = 6: -------------------------------------- Extinction coefficients for hygroscopic species (modeled and background) are computed using a monthly RH adjustment factor in place of an hourly RH factor (VISB.DAT file is NOT needed). Enter the 12 monthly factors here (RHFAC). Month 1 is January. (RHFAC) -- No default ! RHFAC = 3.4,3.1,2.9,3.0,3.6,3.6,3.4,3.4,3.6,3.5,3.4,3.5! Additional inputs used for MVISBK = 2,3,6: ----------------------------------------

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01_CC_vis.INP

 Background extinction coefficients are computed from monthly CONCENTRATIONS of ammonium sulfate (BKSO4), ammonium nitrate (BKNO3), coarse particulates (BKPMC), organic carbon (BKOC), soil (BKSOIL), and elemental carbon (BKEC). Month 1 is January. (ug/m**3) (BKSO4) -- No default ! BKSO4 = 0.12, 0.12, 0.12, 0.12,  0.12, 0.12, 0.12, 0.12,  0.12, 0.12, 0.12, 0.12! (BKNO3) -- No default ! BKNO3 = 0.10, 0.10, 0.10, 0.10,  0.10, 0.10, 0.10, 0.10,  0.10, 0.10, 0.10, 0.10 ! (BKPMC) -- No default ! BKPMC = 3.0, 3.0, 3.0, 3.0,  3.0, 3.0, 3.0, 3.0,  3.0, 3.0, 3.0, 3.0 ! (BKOC) -- No default ! BKOC = 0.47, 0.47, 0.47, 0.47,  0.47, 0.47, 0.47, 0.47,  0.47, 0.47, 0.47, 0.47! (BKSOIL) -- No default ! BKSOIL= 0.50, 0.50, 0.50, 0.50,  0.50, 0.50, 0.50, 0.50,  0.50, 0.50, 0.50, 0.50 ! (BKEC) -- No default ! BKEC = 0.02, 0.02, 0.02, 0.02,  0.02, 0.02, 0.02, 0.02,  0.02, 0.02, 0.02, 0.02 ! Additional inputs used for MVISBK = 2,3,5,6: ------------------------------------------ Extinction due to Rayleigh scattering is added (1/Mm) (BEXTRAY) -- Default: 10.0 ! BEXTRAY = 10.0!!END!-------------------------------------------------------------------------------INPUT GROUP: 3 -- Output options--------------Documentation------------- Documentation records contained in the header of the CALPUFF output file may be written to the list file. Print documentation image? (LDOC) -- Default: F ! LDOC = F !Output Units------------ Units for All Output (IPRTU) -- Default: 1 ! IPRTU = 3 ! for for

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01_CC_vis.INP

 Concentration Deposition 1 = g/m**3 g/m**2/s 2 = mg/m**3 mg/m**2/s 3 = ug/m**3 ug/m**2/s 4 = ng/m**3 ng/m**2/s 5 = Odour Units Visibility: extinction expressed in 1/Mega-meters (IPRTU is ignored)Averaging time(s) reported-------------------------- 1-hr averages (L1HR) -- Default: T ! L1HR = F ! 3-hr averages (L3HR) -- Default: T ! L3HR = F ! 24-hr averages (L24HR) -- Default: T ! L24HR = T ! Run-length averages (LRUNL) -- Default: T ! LRUNL = F ! User-specified averaging time in hours - results for an averaging time of NAVG hours are reported for NAVG greater than 0: (NAVG) -- Default: 0 ! NAVG = 0 !Types of tabulations reported------------------------------ 1) Visibility: daily visibility tabulations are always reported for the selected receptors when ASPEC = VISIB. In addition, any of the other tabulations listed below may be chosen to characterize the light extinction coefficients. [List file or Plot/Analysis File] 2) Top 50 table for each averaging time selected [List file only] (LT50) -- Default: T ! LT50 = T ! 3) Top 'N' table for each averaging time selected [List file or Plot file] (LTOPN) -- Default: F ! LTOPN = F ! -- Number of 'Top-N' values at each receptor selected (NTOP must be <= 4)

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01_CC_vis.INP

 (NTOP) -- Default: 4 ! NTOP = 4 ! -- Specific ranks of 'Top-N' values reported (NTOP values must be entered) (ITOP(4) array) -- Default: ! ITOP = 1, 2, 3, 4 ! 1,2,3,4 4) Threshold exceedance counts for each receptor and each averaging time selected [List file or Plot file] (LEXCD) -- Default: F ! LEXCD = F ! -- Identify the threshold for each averaging time by assigning a non-negative value (output units). -- Default: -1.0 Threshold for 1-hr averages (THRESH1) ! THRESH1 = -1.0 ! Threshold for 3-hr averages (THRESH3) ! THRESH3 = -1.0 ! Threshold for 24-hr averages (THRESH24) ! THRESH24 = -1.0 ! Threshold for NAVG-hr averages (THRESHN) ! THRESHN = -1.0 ! -- Counts for the shortest averaging period selected can be tallied daily, and receptors that experience more than NCOUNT counts over any NDAY period will be reported. This type of exceedance violation output is triggered only if NDAY > 0. Accumulation period(Days) (NDAY) -- Default: 0 ! NDAY = 0 ! Number of exceedances allowed (NCOUNT) -- Default: 1 ! NCOUNT = 1 ! 5) Selected day table(s) Echo Option -- Many records are written each averaging period selected and output is grouped by day [List file or Plot file] (LECHO) -- Default: F ! LECHO = F ! Timeseries Option -- Averages at all selected receptors for each selected averaging period are written to timeseries files. Each file contains one averaging period, and all receptors are written to a single record each averaging time. [TSttUUUU.DAT files] (LTIME) -- Default: F ! LTIME = F !

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01_CC_vis.INP

 -- Days selected for output (IECHO(366)) -- Default: 366*0 ! IECHO = 366*0 ! (366 values must be entered)Plot output options------------------- Plot files can be created for the Top-N, Exceedance, and Echo tables selected above. Two formats for these files are available, DATA and GRID. In the DATA format, results at all receptors are listed along with the receptor location [x,y,val1,val2,...]. In the GRID format, results at only gridded receptors are written, using a compact representation. The gridded values are written in rows (x varies), starting with the most southern row of the grid. The GRID format is given the .GRD extension, and includes headers compatible with the SURFER(R) plotting software. A plotting and analysis file can also be created for the daily peak visibility summary output, in DATA format only. Generate Plot file output in addition to writing tables to List file? (LPLT) -- Default: F ! LPLT = F ! Use GRID format rather than DATA format, when available? (LGRD) -- Default: F ! LGRD = F !Additional Debug Output----------------------- Output selected information to List file for debugging? (LDEBUG) -- Default: F ! LDEBUG = F !!END!

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American Electric Power E-1 Trinity Consultants 

Northeastern Power Station 083701.0024 

APPENDIX E – CONTROL SCENARIO EMISSION ESTIMATES
Northeastern Power Plant

BART Modeling Source Parameters

Stack Parameters

Stack parameters (English) Unit 3 Unit 4 Unit 3 Unit 4 Unit 3 Unit 4 Unit 3 Unit 4 Unit 3 Heat Input (MMBtu/hr)1 5,812 5,594 5,812 5,594 5,812 5,594 5,812 5,594 5,812 

Exit Velocity (ft/sec) 62 57 62 57 62 57 62 57 51 Stack Diameter (feet) 27 27 27 27 27 27 27 27 27 Stack Flow (acfm) 2,137,884 1,967,458 2,137,884 1,967,458 2,137,884 1,967,458 2,137,884 1,967,458 1,758,239 Stack Temp. (°F)2 304 288 304 288 304 288 304 288 168 Stack Temp. (°R) 764 748 764 748 764 748 764 748 628 Stack Height (feet) 600 600 600 600 600 600 600 600 600 Base Elevation (feet)3 640 640 640 640 640 640 640 640 640 Stack parameters (Metric)Heat Input (MMBtu/hr)1 5,812 5,594 5,812 5,594 5,812 5,594 5,812 5,594 5,812 Exit Velocity (m/sec) 18.97 17.46 18.97 17.46 18.97 17.46 18.97 17.46 15.60 Stack Diameter (meters) 8.23 8.23 8.23 8.23 8.23 8.23 8.23 8.23 8.23 Stack Temp. (K) 424 415 424 415 424 415 424 415 349 Stack Height (meters) 183 183 183 183 183 183 183 183 183 Base Elevation (meters)3 195 195 195 195 195 195 195 195 195 1 Maximum 24-hour average heat input and emission rates between 2002 and 2005 occurred in 2002.

2 Stack temperature for DFGD & WFGD controls provided by AEP (Dharma) in phone conversation on April 22, 2008.3 Base elevations obtained from visual inspection of USGS topographic maps from Terraserver and Topozone websites: http://terraserver.microsoft.com/ http://www.topozone.com/

Baseline Case LNB & OFA SNCR SCR D

American Electric PowerNortheastern Power Station Source Parameters
Northeastern Power Plant

BART Emissions Modeling Inputs

Northeastern Unit 3

PM1

lb/mmBtu lb/hr lb/mmBtu lb/hr ppm lb/mmBtu lb/hr lb/mmBtu lb/hr lb/h

Case 1 Baseline Case -- 0.536 3,115.5 0.900 5,231.2 3.0 0.011 66.3 0.038 220.3 147Case 2 SNCR 25% 0.402 2,336.6 0.900 5,231.2 3.0 0.011 66.3 0.038 220.3 147Case 3 LNB & OFA 72% 0.150 871.9 0.900 5,231.2 3.0 0.011 66.3 0.038 220.3 147Case 4 SCR 90% 0.054 311.5 0.900 5,231.2 3.0 0.011 66.3 0.038 220.3 147Case 5 DFGD 83% 0.536 3,115.5 0.150 871.9 3.0 0.002 11.0 0.038 220.3 147Case 6 WFGD 93% 0.536 3,115.5 0.063 366.2 3.0 0.001 4.6 0.038 220.3 147Case 7 ESP & FF 78% 0.536 3,115.5 0.900 5,231.2 3.0 0.011 66.3 0.009 49.4 33.

Northeastern Unit 4

PM1

lb/mmBtu lb/hr lb/mmBtu lb/hr ppm lb/mmBtu lb/hr lb/mmBtu lb/hr lb/h

Case 1 Baseline Case -- 0.491 2,746.6 0.900 5,034.5 3.0 0.011 62.3 0.059 330.6 221Case 2 SNCR 25% 0.368 2,060.0 0.900 5,034.5 3.0 0.011 62.3 0.059 330.6 221Case 3 LNB & OFA 69% 0.150 839.1 0.900 5,034.5 3.0 0.011 62.3 0.059 330.6 221Case 4 SCR 90% 0.049 274.7 0.900 5,034.5 3.0 0.011 62.3 0.059 330.6 221Case 5 DFGD 83% 0.491 2,746.6 0.150 839.1 3.0 0.002 10.4 0.059 330.6 221Case 6 WFGD 93% 0.491 2,746.6 0.063 352.4 3.0 0.001 4.4 0.059 330.6 221Case 7 ESP & FF 87% 0.491 2,746.6 0.900 5,034.5 3.0 0.011 62.3 0.008 44.2 29.1 Coal sulfur content conversion to SO4 provided by AEP (Dharma) in phone conversation on April 22, 2008.

Sample Calculation: 2137884 acf 520 Rankine 60 min lbmol S lbmol SO4 96 lb SO4 66.3 lb

min 764 Rankine hour 379.7 SCF lbmol S lbmol SO4 hour

2 Represents fraction of test results less than or equal to PM10. Per AP-42 (9/98) particle size distribution, 67% of total PM considered PM10.

3 Condensible/filterable PM speciation were based on the following profiles:  For Coal, National Park Service guidance for PC Dry Bottom ESP. http://www2.nature.nps.gov/air/Permits/ect/ectCoalFiredBoiler.cfm

Coarse 15.46%

Fine Soil 11.91% Fine soil included in model as PM (fine)

Fine EC 0.46%

CPM IOR 57.73% Inorganic condensible PM considered sulfates per NPS guidance

CPM OR 14.43% Organic condensible PM considered secondary organic aerosols per NPS

3 parts S

1,000,000 parts coal

=

H2SO4 (as SO4 from SO2)1

H2SO4 (as SO4 from SO2)1

Percent 

Reduction

Percent 

Reduction

PM

NOx SO2 PM

NOx SO2

American Electric PowerNortheastern Power Station Model Inputs
American Electric Power F-1 Trinity Consultants 

Northeastern Power Station 083701.0024 

APPENDIX F – CONTROL COST CALCULATIONS
Printed: 5/27/2008

BART Economic Analysis for SNCR (NOX)

Capital Cost Summary Capital Cost

TOTAL CAPITAL INVESTMENT (TCI) a TCI = $11,500,000

Annual Cost Summary Annual Cost

TOTAL DIRECT COSTS (DC) DC = $13,142,120

INDIRECT OPERATING COSTS

Administrative Charges (2% of TCI) b $230,000

Insurance (1% of TCI) b $115,000

Property Taxes (1% of TCI) b $115,000

Capital Recovery (CRF x TCI)

20 years @ 8.00% interest CRF = 0.1019 $1,171,300

TOTAL INDIRECT COSTS (IC) IC = $1,631,300

TOTAL ANNUALIZED COST (TAC = DC + IC) TAC= $14,773,420

Cost Effectiveness Summary

Annual Control Cost: $14,773,420

NOx to be Removed (tpy): c 5,370

CONTROL COST EFFECTIVENESS ($/ton): $2,751

a Cost data provided by AEP.

b Indirect operation cost factors taken from OAQPS CCM, Section 4.2, Chapter 1, Sixth Edition, January 2002.

c Based on 25% reduction in emissions from baseline conditions

American Electric Power

Northeastern Power Station BART (SNCR - NOx)

Trinity Consultants

083701.0024
Printed: 5/27/2008

BART Economic Analysis for LNB & OFA (NOX)

Capital Cost Summary Capital Cost

TOTAL CAPITAL INVESTMENT (TCI) a TCI = $17,000,000

Annual Cost Summary Annual Cost

TOTAL DIRECT COSTS (DC) DC = $0

INDIRECT OPERATING COSTS

Administrative Charges (2% of TCI) b $340,000

Insurance (1% of TCI) b $170,000

Property Taxes (1% of TCI) b $170,000

Capital Recovery (CRF x TCI)

20 years @ 8.00% interest CRF = 0.1019 $1,731,488

TOTAL INDIRECT COSTS (IC) IC = $2,411,488

TOTAL ANNUALIZED COST (TAC = DC + IC) TAC= $2,411,488

Cost Effectiveness Summary

Annual Control Cost: $2,411,488

NOx to be Removed (tpy): c 15,205

CONTROL COST EFFECTIVENESS ($/ton): $159

a Cost data provided by AEP.

b Indirect operation cost factors taken from OAQPS CCM, Sixth Edition, January 2002.

c Based on an emission factor of 0.150 lb/MMBtu.

American Electric Power

Northeastern Power Station BART (LNB & OFA - NOx)

Trinity Consultants

083701.0024
Printed: 5/27/2008

BART Economic Analysis for SCR (NOX)

Capital Cost Summary Capital Cost

TOTAL CAPITAL INVESTMENT (TCI) a TCI = $290,000,000

Annual Cost Summary Annual Cost

TOTAL DIRECT COSTS (DC) DC = $6,648,660

INDIRECT OPERATING COSTS

Administrative Charges (2% of TCI) b $5,800,000

Insurance (1% of TCI) b $2,900,000

Property Taxes (1% of TCI) b $2,900,000

Capital Recovery (CRF x TCI)

20 years @ 8.00% interest CRF = 0.1019 $29,537,141

TOTAL INDIRECT COSTS (IC) IC = $41,137,141

TOTAL ANNUALIZED COST (TAC = DC + IC) TAC= $47,785,801

Cost Effectiveness Summary

Annual Control Cost: $47,785,801

NOx to be Removed (tpy): c 19,331

CONTROL COST EFFECTIVENESS ($/ton): $2,472

a Cost data provided by AEP.

b Indirect operation cost factors taken from OAQPS CCM, Section 4.2, Chapter 2, Sixth Edition, January 2002.

c Based on 90% reduction in emissions from baseline conditions

American Electric Power

Northeastern Power Station BART (SCR - NOx)

Trinity Consultants

083701.0024
Printed: 5/27/2008

BART Economic Analysis for DFGD (SO2)

Capital Cost Summary Capital Cost

Purchased Equipment Costs (PEC) a $521,700,000

Landfill Contruction a $25,000,000

TOTAL CAPITAL INVESTMENT (TCI) TCI = $546,700,000

Annual Cost Summary Annual Cost

DIRECT OPERATING COSTS

Lime Injection $6,180,000

Operating Electricity $3,022,200

TOTAL DIRECT COSTS (DC) DC = $9,202,200

INDIRECT OPERATING COSTS

Administrative Charges (2% of TCI) d $10,934,000

Insurance (1% of TCI) d $5,467,000

Property Taxes (1% of TCI) d $5,467,000

Capital Recovery (CRF x TCI)

20 years @ 8.00% interest CRF = 0.1019 $55,682,603

TOTAL INDIRECT COSTS (IC) IC = $77,550,603

TOTAL ANNUALIZED COST (TAC = DC + IC) TAC= $86,752,803

Cost Effectiveness Summary

Annual Control Cost: $86,752,803

SO2 to be Removed (tpy): e 26,559

CONTROL COST EFFECTIVENESS ($/ton): $3,266

a Based upon the following cost estimates:

DFGD Capital Cost = 555 $/kW

Net Rating of Affected Units = 940 MW (includes NE3 and NE4)

Landfill Costs estimated based upon AEP experience

b Estimated Lime Usage = 30,893 tons/yr, based upon 83% control efficiency from 0.90 lb/MMBtu baseline emission rate

Lime Cost = 200 $/ton

c Estimated Electricity Usage = 6900 kW/yr, based upon scale up from Welsh unit

Cost of electricity = 0.05 $/kW

d Indirect operation cost factors taken from OAQPS Cost Control Manual, Sixth Edition, January 2002.

e Estimate includes both NE3 and NE4

DFGD SO2 Removal Rate = 0.83

Annual Capacity Factor = 0.85

Baseline (pre-BART) emission factor = 0.9 lb/MMBtu, based upon emission data review performed by AEP

Annual Average Firing Rate = 4775 MMBtu/hr, as listed in Permit No. 96-288-TV.

0.9 lb 4775 MMBtu 8760 hrs ton 0.85 capacity factor 0.83 SO2 Removal Rate = 26,559 tons SO2

MMBtu hr yr 2000 lb year

American Electric Power

Northeastern Power Station BART (DFGD - SO2)

Trinity Consultants

083701.0024
Printed: 5/27/2008

BART Economic Analysis for WFGD (SO2)

Capital Cost Summary Capital Cost

Purchased Equipment Costs (PEC) a $678,680,000

Landfill Contruction a $25,000,000

TOTAL CAPITAL INVESTMENT (TCI) a TCI = $703,680,000

Annual Cost Summary Annual Cost

DIRECT OPERATING COSTS

Limestone Injection $4,250,000

Operating Electricity $3,022,200

TOTAL DIRECT COSTS (DC) DC = $7,272,200

INDIRECT OPERATING COSTS

Administrative Charges (2% of TCI) d $14,073,600

Insurance (1% of TCI) d $7,036,800

Property Taxes (1% of TCI) d $7,036,800

Capital Recovery (CRF x TCI)

20 years @ 8.00% interest CRF = 0.1019 $71,671,362

TOTAL INDIRECT COSTS (IC) IC = $99,818,562

TOTAL ANNUALIZED COST (TAC = DC + IC) TAC= $107,090,762

Cost Effectiveness Summary

Annual Control Cost: $107,090,762

SO2 to be Removed (tpy): e 29,759

CONTROL COST EFFECTIVENESS ($/ton): $3,599

a Cost data provided by AEP.

WFGD Capital Cost = 722 $/kW

Net Rating of Affected Units = 940 MW (includes NE3 and NE4)

Landfill Costs estimated based upon AEP experience

b Estimated Limestone Usage = 36,934 tons/yr, based upon 93% control efficiency from 0.90 lb/MMBtu baseline emission rate

Lime Cost = 115 $/ton

c Estimated Electricity Usage = 6900 kW/yr, based upon scale up from Welsh unit

Cost of electricity = 0.05 $/kW

d Indirect operation cost factors taken from OAQPS CCM, Sixth Edition, January 2002.

e Estimate includes both NE3 and NE4

WFGD SO2 Removal Rate = 0.93

Annual Capacity Factor = 0.85

Baseline (pre-BART) emission factor = 0.9 lb/MMBtu, based upon emission data review performed by AEP

Annual Average Firing Rate = 4775 MMBtu/hr, as listed in Permit No. 96-288-TV.

0.9 lb 4775 MMBtu 8760 hrs ton 0.85 capacity factor 0.93 SO2 Removal Rate = 29,759 tons SO2 

MMBtu hr yr 2000 lb year

American Electric Power

Northeastern Power Station BART (WFGD - SO2)

Trinity Consultants

083701.0024
American Electric Power G-1 Trinity Consultants 

Northeastern Power Station 083701.0024 

APPENDIX G – CALPUFF SYSTEM MODEL FILES

Control Scenario Description Model Run Number 

 NOx SO2

Case 1 Baseline Case Run 1 Run 1 

Case 2 SNCR Run 2 -- 

Case 3 LNB & OFA Run3 -- 

Case 4 SCR Run4 -- 

Case 5 DFGD -- Run 4 

Case 6 WFGD -- Run 3