## B EST 

## A VAILABLE 

## R ETROFIT 

## T ECHNOLOGY 

## (BART) D ETERMINATION 

## A MERICAN 

## E LECTRIC 

## P OWER  

## N ORTHEASTERN 

## P OWER 

## P LANT

Prepared by:

N.N. Dharmarajan  AEP

Eugene Chen, P.E.  Senior Consultant Jeremy Townley  Consultant

T RINITY 

### C ONSULTANTS 

### 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 

## T ABLE OF 

## C ONTENTS



## 1. E XECUTIVE 

## S UMMARY 

## ........................................................................................ 1-1

2. B ACKGROUND 

## ...................................................................................................... 2-1
2.1 B EST 

## A VAILABLE 

## R ETROFIT 

## T ECHNOLOGY 

## R ULE 

## ................................................. 2-1
2.2 M ODELING 

## P ROTOCOL 

## B ACKGROUND 

## .................................................................. 2-1
2.3 L OCATION OF 

## S OURCES AND 

## R ELEVANT 

## C LASS 

## I A REAS 

## ...................................... 2-2

3. CALPUFF M ODEL 

## S YSTEM 

## ............................................................................... 3-1
3.1 M ODEL 

## V ERSIONS 

## ................................................................................................. 3-1
3.2 M ODELING 

## D OMAIN 

## ............................................................................................. 3-1

4. CALMET............................................................................................................ 4-1
4.1 G EOPHYSICAL 

## D ATA 

## ............................................................................................. 4-1

4.1.1 T ERRAIN 

### D ATA 

### ...................................................................................................4-1

4.1.2 L AND 

### U SE 

### D ATA 

### .................................................................................................4-2

4.1.3 C OMPILING 

### T ERRAIN AND LAND 

### U SE 

### D ATA 

### .......................................................4-3 

## 4.2 M ETEOROLOGICAL 

## D ATA 

## ..................................................................................... 4-3

4.2.1 M ESOSCALE 

### M ODEL 

### M ETEOROLOGICAL 

### D ATA 

### .................................................4-3

4.2.2 S URFACE 

### M ETEOROLOGICAL 

### D ATA 

### ...................................................................4-4

4.2.3 U PPER 

### A IR 

### M ETEOROLOGICAL 

### D ATA 

### .................................................................4-5

4.2.4 P RECIPITATION 

### M ETEOROLOGICAL 

### D ATA 

### ..........................................................4-6

4.2.5 B UOY 

### M ETEOROLOGICAL 

### D ATA 

### .........................................................................4-7 

## 4.3 CALMET C ONTROL 

## P ARAMETERS 

## ....................................................................... 4-8

4.3.1 V ERTICAL 

### M ETEOROLOGICAL 

### P ROFILE 

### ..............................................................4-8

4.3.2 I NFLUENCES OF 

### O BSERVATIONS 

### .........................................................................4-9



## 5. CALPUFF........................................................................................................... 5-1
5.1 S OURCE 

## E MISSIONS 

## ............................................................................................... 5-1
5.2 R ECEPTOR 

## L OCATIONS 

## .......................................................................................... 5-1
5.3 B ACKGROUND 

## O ZONE AND 

## A MMONIA 

## .................................................................. 5-1
5.4 CALPUFF M ODEL 

## C ONTROL 

## P ARAMETERS 

## ......................................................... 5-1

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

– L IGHT 

## E XTINCTION 

## A LGORITHM 

## ..................................................... 6-1
6.2 CALPOST P ROCESSING METHOD 

## ......................................................................... 6-2
6.3 N ATURAL 

## B ACKGROUND 

## ...................................................................................... 6-2
6.4 E VALUATING 

## V ISIBILITY 

## R ESULTS 

## ....................................................................... 6-2
6.5 S UMMARY OF 

## CALPOST C ONTROL 

## P ARAMETERS 

## ............................................... 6-2

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 ii 

## 7. BART-E LIGIBLE 

## E MISSION 

## U NITS 

## ..................................................................... 7-1
7.1 D ESCRIPTION OF 

## B ART 

## -E LIGIBLE 

## S OURCES 

## .......................................................... 7-1
7.2 M ODELED 

## S TACK 

## P ARAMETERS 

## ........................................................................... 7-2

8. BART D ETERMINATION 

## A NALYSIS FOR 

## NO X 

## .................................................... 8-1
8.1 S TEP 

## 1

- I DENTIFY 

## A LL 

## A VAILABLE 

## R ETROFIT 

## C ONTROL 

## T ECHNOLOGIES 

## ............ 8-1

8.1.1 C OMBUSTION 

### M ODIFICATIONS 

### ...........................................................................8-2

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

8.1.1.2 Low NO X 

### Burners and Overfire Air....................................................8-3

8.1.1.3 Reburning / Methane de-NO X 

### .............................................................8-3

8.1.2 P OST 

### -C OMBUSTION 

### C ONTROLS 

### ..........................................................................8-4

8.1.2.1 Selective Non-Cataly tic Reduction .....................................................8-4

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

## 8.2 S TEP 

## 2

– E LIMINATE 

## T ECHNICALLY 

## I NFEASIBLE 

## O PTIONS 

## .................................... 8-7

8.2.1 F LUE 

### G AS 

### R ECIRCULATION 

### ................................................................................8-8

8.2.2 R EBURNING 

### / M ETHANE DE 

### -NO X 

### .......................................................................8-8 

## 8.3 S TEP 

## 3

– E VALUATE 

## C ONTROL 

## E FFECTIVENESS OF 

## R EMAINING 

## C ONTROL 

## T ECHNOLOGIES 

## ..................................................................................................... 8-8
8.4 S TEP 

## 4

– E VALUATE 

## I MPACTS AND 

## D OCUMENT 

## R ESULTS 

## ..................................... 8-9

8.4.1 C OSTS OF 

### C OMPLIANCE 

### ......................................................................................8-9

8.4.2 E NERGY 

### I MPACTS 

### & N ON 

### -A IR 

### I MPACTS 

### ..........................................................8-10

8.4.3 R EMAINING 

### U SEFUL 

### L IFE 

### .................................................................................8-11 

## 8.5 S TEP 

## 5

– E VALUATE 

## V ISIBILITY 

## I MPACTS 

## ........................................................... 8-11
8.6 BART D ETERMINATION FOR 

## NO X 

## ...................................................................... 8-12

9. BART D ETERMINATION 

## A NALYSIS FOR 

## SO 2 

## ..................................................... 9-1
9.1 S TEP 

## 1

- I DENTIFY 

## A LL 

## A VAILABLE 

## R ETROFIT 

## C ONTROL 

## T ECHNOLOGIES 

## ............ 9-1

9.1.1 D RY 

### F LUE 

### G AS 

### D ESULFURIZATION 

### ....................................................................9-1

9.1.2 W ET 

### F LUE 

### G AS 

### D ESULFURIZATION 

### ....................................................................9-1 

## 9.2 S TEP 

## 2

– E LIMINATE 

## T ECHNICALLY 

## I NFEASIBLE 

## O PTIONS 

## .................................... 9-2
9.3 S TEP 

## 3

– E VALUATE 

## C ONTROL 

## E FFECTIVENESS OF 

## R EMAINING 

## C ONTROL 

## T ECHNOLOGIES 

## ..................................................................................................... 9-2
9.4 S TEP 

## 4

– E VALUATE 

## I MPACTS AND 

## D OCUMENT 

## R ESULTS 

## ..................................... 9-2

9.4.1 C OST OF 

### C OMPLIANCE 

### ........................................................................................9-3

9.4.2 E NERGY 

### I MPACTS AND 

### N ON 

### -A IR 

### Q UALITY 

### I MPACTS 

### .........................................9-3

9.4.3 R EMAINING 

### U SEFUL 

### L IFE 

### ...................................................................................9-3 

## 9.5 S TEP 

## 5

– E VALUATE 

## V ISIBILITY 

## I MPACTS 

## ............................................................. 9-3
9.6 BART D ETERMINATION FOR 

## SO 2 

## ......................................................................... 9-4

A PPENDIX 

## A- M ETEOROLOGICAL 

## S TATIONS



## A PPENDIX 

## B

– S AMPLE 

## CALMET C ONTROL 

## F ILE

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 iii 

## A PPENDIX 

## C

– S AMPLE 

## CALPUFF C ONTROL 

## F ILE



## A PPENDIX 

## D

– S AMPLE 

## CALPOST C ONTROL 

## F ILE



## A PPENDIX 

## E

– C ONTROL 

## S CENARIO 

## E MISSION 

## E STIMATES



## A PPENDIX 

## F

– C ONTROL 

## C OST 

## C ALCULATIONS



## A PPENDIX 

## G

– CALPUFF S YSTEM 

## M ODEL 

## F ILES

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 iv 

## L IST OF 

## T ABLES

T ABLE 

### 1-1. N ORTHEASTERN 

### S TATION 

### BART D ETERMINATION 

### S UMMARY 

### ......................................1-2

T ABLE 

### 2-1. BART-E LIGIBLE 

### S OURCES 

### ...............................................................................................2-2

T ABLE 

### 2-2. D ISTANCE 

### ( KM 

### ) F ROM 

### S TATION TO 

### S URROUNDING 

### C LASS 

### I A REAS 

### ..............................2-2

T ABLE 

### 3-1 CALPUFF M ODELING 

### S YSTEM 

### V ERSIONS 

### ......................................................................3-1

T ABLE 

### 4-1. V ERTICAL 

### L AYERS OF THE 

### CALMET M ETEOROLOGICAL 

### D OMAIN 

### ................................4-9

T ABLE 

### 6-1. M ONTHLY 

### H UMIDITY 

### F ACTORS 

### .......................................................................................6-2

T ABLE 

### 6-2. D EFAULT 

### A VERAGE 

### A NNUAL 

### N ATURAL 

### B ACKGROUND 

### L EVELS 

### ...................................6-2

T ABLE 

### 7-1. S UMMARY OF 

### BART- ELIGIBLE 

### E MISSION 

### U NITS 

### ............................................................7-1

T ABLE 

### 7-2. S TACK 

### P ARAMETERS 

### .......................................................................................................7-2

T ABLE 

### 8-1. A VAILABLE 

### NO X 

### C ONTROL 

### T ECHNOLOGIES 

### ...................................................................8-8

T ABLE 

### 8-2. R ANKING OF 

### C ONTROL 

### T ECHNOLOGIES 

### ..........................................................................8-9

T ABLE 

### 8-3. NO X 

### C ONTROL 

### C OSTS 

### S UMMARY 

### .................................................................................8-10

T ABLE 

### 8-4. NE S TATION 

### NO X 

### V ISIBILITY 

### R ESULTS 

### .........................................................................8-11

T ABLE 

### 9-1. R ANKING OF 

### C ONTROL 

### S TRATEGIES 

### ...............................................................................9-2

T ABLE 

### 9-2. SO 2 

### C ONTROLS 

### C OSTS 

### S UMMARY 

### ...................................................................................9-3

T ABLE 

### 9-3. NE S TATION 

### SO 2 

### V ISIBILITY 

### R ESULTS 

### ............................................................................9-4

T ABLE 

### A-1. L IST OF 

### S URFACE METEOROLOGICAL 

### S TATIONS 

### ............................................................... 1

T ABLE 

### A-2. L IST OF 

### U PPER 

### A IR METEOROLOGICAL 

### S TATIONS 

### ............................................................. 5

T ABLE 

### A-3. L IST OF 

### P RECIPITATION METEOROLOGICAL 

### S TATIONS 

### ...................................................... 6

T ABLE 

### A-4. L IST OF 

### O VER 

### W ATER METEOROLOGICAL 

### S TATIONS 

### ...................................................... 14

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 v 

## L IST OF 

## F IGURES

F IGURE 

### 2-1. P LOT OF 

### S OURCES AND 

### N EAREST 

### C LASS 

### I A REAS 

### .........................................................2-3

F IGURE 

### 3-1. R EFINED 

### M ETEOROLOGICAL 

### M ODELING 

### D OMAIN 

### .........................................................3-2

F IGURE 

### 4-1. P LOT OF 

### L AND 

### E LEVATION 

### U SING 

### USGS T ERRAIN 

### D ATA 

### ............................................4-2

F IGURE 

### 4-2. P LOT OF 

### L AND 

### U SE 

### U SING 

### USGS LULC D ATA 

### .............................................................4-3

F IGURE 

### 4-3. P LOT OF 

### S URFACE 

### S TATION 

### L OCATIONS 

### ........................................................................4-5

F IGURE 

### 4-4. P LOT OF 

### U PPER 

### A IR 

### S TATIONS 

### L OCATIONS 

### ...................................................................4-6

F IGURE 

### 4-5. P LOT OF 

### P RECIPITATION METEOROLOGICAL 

### S TATIONS 

### .................................................4-7

F IGURE 

### 4-6. P LOT OF 

### B UOY 

### M ETEOROLOGICAL 

### S TATIONS 

### ................................................................4-8

F IGURE 

### 8-1. P RIMARY 

### SNCR R EACTION 

### S EQUENCES 

### ........................................................................8-5

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 1-1 

## 1. E XECUTIVE 

## S UMMARY

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 SO 2 

### and NOx (as applicable to plants greater than 75 0 MW for the type of fuel and boiler), in
accordance with the same 40CFR Part 51 rules cited above. For SO 2 

### 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 usi ng Low NOx burners/Overfire air.

S 

### The electrostatic precipitators would be BART for PM based on the modeling and engineering analysis performed a nd 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 perform ed in order to determine BART for NO X 

### and SO 2 

### for NE units 3

& 4.

This report summarizes the result of the five factor analysis performed for SO 2 

### 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 implem entation costs to gain emissions reductions with
minimal 98 th 

### 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 SO 2 

### . As summarized in Table 1-1 below, AEP proposes the following measures as BART:

1 40 CFR 51 Appendix Y, Guidelines for BART Determinati ons Under the Regional Haze Rule

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 1-2 T ABLE 

### 1-1. N ORTHEASTERN 

### S TATION 

### BART D ETERMINATION 

### S UMMARY



### Unit ID NO X 

### BART

Determination SO 2 

### BART

Determination

Northeastern Unit 3 Low-NO X 

### Burners Low Sulfur coal
Northeastern Unit 4 Low- NO X 

### Burners Low Sulfur coal

The five factors considered in determin ing 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 visibilit y 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 – NO X 

### BART Determination
▲ Section 9 – SO 2 

### 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 Appe ndices) have not been reviewed by the state but adhere, where practical, to the modeling setti ngs and procedures established in CENRAP’s BART Modeling Guidelines

. 2



### Sections 7-9 address the five-factor analysis for NO X 

### and SO 2 

### , and include an analysis of compliance costs and visibility impacts of various control technologies:

2 Released December 2005.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 2-1 

## 2. B ACKGROUND



## 2.1 B EST 

## A VAILABLE 

## R ETROFIT 

## T ECHNOLOGY 

## R ULE

On July 1, 1999, the U.S. Environmental EPA pub lished 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, acro ss the United States. The Clean Air Act defines Class I areas as certain national parks (over 6000 acr es), 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-specifi c Best Available Retrofit Technology (BART)

determinations. The BART rule defines BART-e ligible 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 an ticipated 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 impa irment 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 dete rmine a source’s visibility impacts. States have the authority to exempt certain BART-eligible sources fro m 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 M ODELING 

## P ROTOCOL 

## B ACKGROUND

To promote consistency between States in the de velopment of BART modeling protocols and to harmonize the approaches between adjacent RPOs, the Central States Regional Air Planning (CENRAP) organization developed BART Modeling Gu idelines (December 15, 2005). The intent of the guidelines was to assist CENRAP States and sour ce operators in the development of statewide and source-specific modeling protocols.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 2-2 

## 2.3 L OCATION OF 

## S OURCES AND 

## R ELEVANT 

## C LASS 

## I A REAS

The sources listed in Table 2-1. BART-Eligible Sour ces are the sources that have been identified by
AEP as sources that meet the three criteria fo r BART-eligible sources at the NE Station.

T ABLE 

### 2-1. BART-E LIGIBLE 

### S OURCES



### 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 th is 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.

T ABLE 

### 2-2. D ISTANCE 

### ( KM 

### ) F ROM 

### S TATION TO 

### S URROUNDING 

### C LASS 

### I A REAS



### 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.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 2-3 F IGURE 

### 2-1. P LOT OF 

### S OURCES AND 

### N EAREST 

### C LASS 

### I A REAS

-800 -600 -400 -200 0 200 400 600 800
LCC Easting (km) -1600 -1400 -1200 -1000

-800 -600 -400 -200LCC Northing (km) Northeastern Station

WIMO CACR UPBU HEGL

Class I Areas

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 3-1 

## 3. CALPUFF M ODEL 

## S YSTEM

The main components of the CALPUFF modeling system are CALMET, CALPUFF, and CALPOST. CALMET is the meteorological model that generat es hourly three-dimensional meteorological fields such as wind and temperature. CALPUFF simulates the non-steady state transport, dispersion, and chemical transformation of air pollutants emitte d from a source in “puffs.” CALPUFF calculates hourly concentrations of visibility affecting po llutants at each specified receptor in a modeling domain. CALPOST is the post-processor for CA LPUFF that computes visibility impacts from a source based on the visibility affecting pollutant concentrations that were output by CALPUFF.



## 3.1 M ODEL 

## V ERSIONS

The versions of the CALPUFF modeling system programs that were used for conducting AEP’s BART modeling are listed in Table 3-1.

T ABLE 

### 3-1 CALPUFF M ODELING 

### S YSTEM 

### V ERSIONS



### 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 M ODELING 

## D OMAIN

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 ar e advected and tracked only while within the computational grid. The meteorological grid is de fined 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

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 3-2 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 Worl d Geodetic System 84 (WGS-84). The reference point for the modeling domain is Latitude 40oN, Long itude 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.

F IGURE 

### 3-1. R EFINED 

### M ETEOROLOGICAL 

### M ODELING 

### D OMAIN

-800 -600 -400 -200 0 200 400 600 800
LCC Easting (km) -1600 -1400 -1200 -1000

-800 -600 -400 -200LCC Northing (km) Northeastern Station

WIMO CACR UPBU HEGL

Class I Areas Meteorological Modeling Domain

Computational Modeling Domain 1

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 4-1 

## 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, gr idded data set for input into CALPUFF. CALMET

was used to assimilate data for 2001- 2003 us ing National Weather Service (NWS) surface station observations, upper air station observations, preci pitation station observations, buoy station observations (for overwater areas), and mesoscale mode l output to develop the meteorological field.



## 4.1 G EOPHYSICAL 

## D ATA

CALMET requires geophysical data to characteri ze the terrain and land use parameters that potentially affect dispersion. Terrain features affe ct flows and create turbulence in the atmosphere and are potentially subjected to hi gher concentrations of elevated puffs. Different land uses exhibit variable characteristics such as surface roughness, al bedo, Bowen ratio, and leaf-area index that also effect turbulence and dispersion.



## 4.1.1 T ERRAIN 

## D ATA



### 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 th e 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.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 4-2 F IGURE 

### 4-1. P LOT OF 

### L AND 

### E LEVATION 

### U SING 

### USGS T ERRAIN 

### D ATA

-800 -600 -400 -200 0 200 400 600 800
LCC Easting(km) -1600 -1400 -1200 -1000

-800 -600 -400 -200LCCNorthing (km) Northeastern Station

0 982 1960 2950 3930

Terrain Elevation (m)



## 4.1.2 L AND 

## U SE 

## D ATA



### 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 th e 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.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 4-3 F IGURE 

### 4-2. P LOT OF 

### L AND 

### U SE 

### U SING 

### USGS LULC D ATA



## 4.1.3 C OMPILING 

## T ERRAIN AND LAND 

## U SE 

## D ATA



### 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 M ETEOROLOGICAL 

## D ATA

CALMET was used to assimilate data for 2001, 20 02, and 2003 using meso scale model output and National Weather Service (NWS) surface stati on observations, upper air station observations, precipitation station observations, and National O ceanic and Atmosphere Administrations (NOAA) buoy station observations to develop the meteorological field.



## 4.2.1 M ESOSCALE 

## M ODEL 

## M ETEOROLOGICAL 

## D ATA



### Hourly mesoscale data was also used as th e initial guess field in developing the CALMET meteorological data. It is AEP’s intent to use the following 5 th 

### 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

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 4-4 • 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 thr ee 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 wh ich 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 H our 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 behi nd 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 S URFACE 

## M ETEOROLOGICAL 

## D ATA



### Parameters affecting turbulent dispersion that are observed hourly at surface stations include wind speed and direction, temperatur e, cloud cover and ceiling, relative humidity, and precipitation type. AEP used the surface st ations 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 th e 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.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 4-5 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.

F IGURE 

### 4-3. P LOT OF 

### S URFACE 

### S TATION 

### L OCATIONS

-800 -600 -400 -200 0 200 400 600 800
LCC Easting (km) -1600 -1400 -1200 -1000

-800 -600 -400 -200LCC Northing (km) Northeastern Station

WIMO CACR UPBU HEGL

Class I Areas Surface Stations



## 4.2.3 U PPER 

## A IR 

## M ETEOROLOGICAL 

## D ATA



### 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 pa rameters) as the balloon rises through the

3 “Procedures for Substituting Values for Missing NWS Me teorological Data for Use in Regulatory Air Quality Models”, Dennis Atkinson and Russe ll F. Lee, July 7, 1992, http://www. epa.gov/scram001/surfa ce/missdata.txt

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 4-6 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 st ations 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 sp atial coverage and representati on 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 persiste nce 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.

F IGURE 

### 4-4. P LOT OF 

### U PPER 

### A IR 

### S TATIONS 

### L OCATIONS

-800 -600 -400 -200 0 200 400 600 800
LCC Easting (km) -1600 -1400 -1200 -1000

-800 -600 -400 -200LCC Northing (km) Northeastern Station

WIMO CACR UPBU HEGL

Class I Areas

Upper Air Station s



## 4.2.4 P RECIPITATION 

## M ETEOROLOGICAL 

## D ATA



### The effects of chemical transformation and deposition processes on ambient pollutant

concentrations were considered in this anal ysis. Therefore, it was necessary to include observations of precipitation in the CALMET anal ysis. 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

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 4-7 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.

F IGURE 

### 4-5. P LOT OF 

### P RECIPITATION METEOROLOGICAL 

### S TATIONS

-800 -600 -400 -200 0 200 400 600 800
LCC Easting (km) -1600 -1400 -1200 -1000

-800 -600 -400 -200LCC Northing (km) Northeastern Station

WIMO CACR UPBU HEGL

Class I Areas Precipitation Stations



## 4.2.5 B UOY 

## M ETEOROLOGICAL 

## D ATA



### The effects of land/sea breeze on ambient pollutant concentrations were considered in this analysis. Therefore, it is necessary to incl ude 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 sta tions were selected from the available data inventory to optimize spatial coverage and representation of the domain along the coastline. Data from the stations was prep ared by filling missing hour records with the CALMET missing parameter value (9999). No adjustments to the data occurred.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 4-8 F IGURE 

### 4-6. P LOT OF 

### B UOY 

### M ETEOROLOGICAL 

### S TATIONS

-800 -600 -400 -200 0 200 400 600 800
LCC Easting (km) -1600 -1400 -1200 -1000

-800 -600 -400 -200LCC Northing (km) Northeastern Station

WIMO CACR UPBU HEGL



### Class I Areas Buoy Stations



## 4.3 CALMET C ONTROL 

## P ARAMETERS

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 V ERTICAL 

## M ETEOROLOGICAL 

## P ROFILE



### 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 divide d 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 us ing a somewhat coarser resolution for the layers aloft.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 4-9 T ABLE 

### 4-1. V ERTICAL 

### L AYERS OF THE 

### CALMET M ETEOROLOGICAL 

### D OMAIN



### 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 th e 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/r 2 

### ) 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/r 2 

### interpolations used to initialize the vertical wind fields. Conversely, a bias of +1 eliminates the surface observations in the interpola tions 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/r 2 

### 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 IEXT RP 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 simila rity 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 I NFLUENCES OF 

## O BSERVATIONS



### 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 inver se 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

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 4-10 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 observa tion 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 va lues 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 observa tion 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 se ttings of radius of influence allowed for adequate weighting of the MM5 data and th e observation data across the modeling domain
due to the vast domain to be modeled. RAMX 3 was set to 500 km.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 5-1 

## 5. CALPUFF

The CALPUFF model uses the output file from CA LMET together with source, receptor, and chemical reaction information to predict hourly concentration impacts. A three-year CALPUFF analysis was conducted using data and m odel settings as described below.



## 5.1 S OURCE 

## E MISSIONS

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 NO X 

### , and SO 2 

### 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 in tent to apply any applicable final selected control technology on each of the affected units at the facility.



## 5.2 R ECEPTOR 

## L OCATIONS

The National Park Service (NPS) has electronic f iles 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 B ACKGROUND 

## O ZONE AND 

## A MMONIA

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

SO 2 

### and NO X 

### to sulfates (SO 4 

### ) and nitrates (NO 3 

### ). CALPUFF can use either a single background value representative of an area or hourly ozone da ta from one or more ozone monitoring stations. Hourly ozone data files were used in the CALPU FF 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 M ODEL 

## C ONTROL 

## P ARAMETERS

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.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 5-2 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 anal ysis and it was felt that it was not necessary to obtain representative concentrations at the individual Class I areas.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 6-1 

## 6. CALPOST

A three-year CALPOST analysis was conducted to dete rmine the visibility change in deciview (dv) caused by AEP’s BART-eligible sources when compared to a natural background.



## 6.1 CALPOST

– L IGHT 

## E XTINCTION 

## A LGORITHM

The algorithm was used to calculate the daily light extinction attributable to AEP’s BART-eligible sources and light extinction attributable to a natura l 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 lig ht extinction and the u pdated light extinction calculation algorithms developed by the Interagency Monitoring of Protected Visual Environments (IMPROVE) workgroup were used to assess vi sibility impacts from the NE Station.

The background extinction coefficient b ext, background 

### is affected by various chemical species and the Rayleigh scattering phenomenon. The original equati on for the background extinction coefficient in the FLM’s FLAG guidance is as follows: 

# ( )

Ray ap Coarse Soil OC NO SO background ext 

### b b b b b b b Mm b + + + + + + = −
3 4 1

,



### where,



## ( ) 

# [ ] ( ) 

## [ ] ( ) 

## [ ] [ ] [ ] [ ] 

# ( ) ( ) 

## [ ] 3 1 3 4 3 4 2 4 4



### m μg in ion Concentrat Function Humidity Relative default by Mm 10 Scattering Rayleigh

EC 10 Mass Coarse 6

. 0 Soil 1 OC 4 NO NH 3 SO

NH 3

= =

= = = = = = =

−



### RH f b b b b b RH f b RH f b

Ray

ap Coarse Soil OC NO SO 

## ( ) 

## [ ] [ ] [ ] [ ] [ ] [ ]

molecules air to due scattering is Scattering Rayleigh carbon elemental of ion concentrat the denotes EC dusts coarse of ion concentrat the denotes Mass Coarse soils fine of ion concentrat the denotes Soil carbon organic of ion concentrat the denotes OC ion concentrat nitrate ammonium the denotes NO NH ion concentrat sulfate ammonium the denotes SO NH

3 4 4

2 4

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 6-2 

## 6.2 CALPOST P ROCESSING METHOD

CALPOST Method 6, which calculates hourly light ex tinction impacts for the source and background using monthly average relative humidity adjustment f actors was used in the refined BART analysis. Monthly Class I area-specific relative humidity adjust ment 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 th e Class I areas listed that were evaluated in the analysis are provided in Table 6-1.

T ABLE 

### 6-1. M ONTHLY 

### H UMIDITY 

### F ACTORS



### 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 N ATURAL 

## B ACKGROUND

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

T ABLE 

### 6-2. D EFAULT 

### A VERAGE 

### A NNUAL 

### N ATURAL 

### B ACKGROUND 

### L EVELS



### Class I Area Region SO 4 

### NO 3 

### 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 E VALUATING 

## V ISIBILITY 

## R ESULTS

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

### 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 S UMMARY OF 

## CALPOST C ONTROL 

## P ARAMETERS

Appendix E provides a sample CALPOST input file that was used for the modeling analysis. Variable values that differ from the CENRAP protoc ol are generally the result of data input/output handling issues (e.g., types of output, receptor numbers, etc.).

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 7-1 

## 7. BART-E LIGIBLE 

## E MISSION 

## U NITS

The BART Guidelines define the following three st eps 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 cat egories 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 NO X 

### , SO 2 

### , and PM 10 

### emissions greater than 250 tpy. A CALPUFF dispersion model was run to determine the visib ility impact associated with emissions from these units. A summary of the parameters used in th e BART modeling eligibility criteria for each emission unit is provided in Table 7-1.

T ABLE 

### 7-1. S UMMARY OF 

### BART- ELIGIBLE 

### E MISSION 

### U NITS



### Emission

Unit BART

Source Category Year of Completion of

Construction or

Reconstruction Maximum (24-hr average)

SO 2 

### Emissions (lb/hr) Maximum (24-hr average)

NO X 

### Emissions (lb/hr) Maximum (24-hr average)

PM/PM 10 

### 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 D ESCRIPTION OF 

## B ART 

## -E LIGIBLE 

## S OURCES

NE Units 3 and 4 are tangentially-fired steam ge nerating boilers burning western sub-bituminous coal, with natural gas or Number 2 fuel oil, u sed 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 controlle d by electrostatic precipitators (ESP) with 99.7% and 99.5% efficiencies for Units 3 and 4 respectivel y. 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 sta ndards with the electrostatic precipitator

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 7-2 

## 7.2 M ODELED 

## S TACK 

## P ARAMETERS

Actual stack parameters were input to the CALPU FF 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 modele d for the BART-eligible emission units at AEP’s
NE Station.

T ABLE 

### 7-2. S TACK 

### P ARAMETERS



### 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 retrof it control technologies were evaluated for these two units. Many of these technologies have the potentia l to alter source parameters from their existing profile. A summary of source parameters associat ed with each control technology are included in Appendix E.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 8-1 

## 8. BART D ETERMINATION 

## A NALYSIS FOR 

## NO X



### 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 effectiven ess of remaining control technologies, Step 4 – Evaluate impacts and document the results, and Step 5 – Evaluate visibility impacts.

The BART determinations for each visibility impa iring 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 NO X 

### from Unit 3 and Unit 4 is presented below. Whichever control is selec ted in the following BART determination will be applied to both units at the station.



## 8.1 S TEP 

## 1

- I DENTIFY 

## A LL 

## A VAILABLE 

## R ETROFIT 

## C ONTROL 

## T ECHNOLOGIES

The BART Guidelines require the consideration of all “control technologies with a practical potential for application to the emissions unit and the regul ated 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 permuta tions of available control levels that exist for a given technology – the list is complete if it includ es the maximum level of control each technology is capable of achieving.”

Per the BART Guidelines, the BART determinati on analysis must “take into account technology transfer of controls that have been applied to si milar source categories and gas streams [in addition to] existing controls for the source category in ques tion.” 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.” Th e 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.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 8-2 Potential NO X 

### control technologies and resulting emission c ontrol 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 applica tions, and technical literature published by the U.S. EPA, and the Regional Planning Organizations (RPOs). Each NO X 

### 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 NO X 

### Burners (LNB) and Over-fire Air (OFA)

S 

### Selective Catalytic Reduction (SCR)

S 

### Reburning / Methane de-NO X 

### (MdN)

S 

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

Combustion-related NO X 

### emissions are formed by two mechanisms. NO X 

### formed from oxidation of molecular nitrogen (N 2 

### ) in combustion air is referred to as “thermal NO X 

### ” and is dependent on high temperatures (approximately 2,800 °F) and an excess of combustion air. NO X 

### formed by oxidation of nitrogen compounds in fuel is referred to as “fuel NO X 

### .” The NO X 

### formed from coal combustion is primarily fuel NO X


### . 5



### The possible NO X 

### emissions control technologies generally f it 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 NO X 

### have shown little promise. 6 

### Combustion modifications are the most common, commercially available means of controlling NO X 

### emissions from fossil fuel-fired boilers. 7



## 8.1.1 C OMBUSTION 

## M ODIFICATIONS



## 8.1.1.1 F LUE 

## G AS 

## R ECIRCULATION



### Generally, FGR involves extracting a portion (15 to 30 percent) of the flue gas and readmitting it to the furnace through the bur ner 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 se tup 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 fl ue 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 NO X 

### formation is inhibited. 8 

### The
onset of thermal NO X 

### occurs around 2,800 °F, and NO X 

### generation increases exponentially with temperatures beyond 2,800 °F. As only thermal NO X 

### can be

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

6 NCASI, NO X

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 (NO X ), Why and How They Are Controlled . Research Triangle Park, North Carolina, EPA-456/F-99-006R, November 1999.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 8-3 controlled by this technique, it is especial ly effective only in oil and gas-fired

units. 9



## 8.1.1.2 L OW 

## NO X 

## B URNERS AND 

## O VERFIRE 

## A IR



### LNB technology utilizes advanced burner design to reduce NO X 

### 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 fi rst region is a lean primary combustion region where the total quantity of combusti on air is supplied with a fraction of the fuel. Combustion in the primary region (fi rst 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 remaini ng 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 tur bulently), which maximizes the reducing conditions. This technique inhib its the formation of thermal NO X 

### , but has little
effect on fuel NO X 

### . By increasing residence times staged air LNB provide reducing conditions, which have a greater impact on fuel NO X 

### than staged fuel
burners. The estimated NO X 

### 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 enhanc ing the combustion staging effect and theoretically reducing NO X 

### 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 R EBURNING 

## / M ETHANE DE 

## -NO X



### 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, NO X

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, NO X

Control in Forest Products Industry Boilers: A Review of Technologies, Costs and Industry Experience , Special Report 03-04.

12 Ibid.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 8-4 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 N 2 

### . Low nitrogen-containing fuels such as natural gas and distillate oil are typically used for reburning to minimize further NO X 

### 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 gro und, which requires additional pulverizing equipment. 13



### Methande de- NO X 

### (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 inject ed at a higher furnace elevation to burn out the combustibles. This process is cl aimed to yield between 50 and 70 percent

NO X 

### reduction and to be suitable for all so lid 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 NO X 

### reductions of 40 to 50 percent reported. 14



## 8.1.2 P OST 

## -C OMBUSTION 

## C ONTROLS



## 8.1.2.1 S ELECTIVE 

## N ON 

## -C ATALYTIC 

## R EDUCTION



### SNCR is a post-combustion NO X 

### control technology based on the reaction of urea or ammonia (NH 3 

### ) and NO X 

### . In the SNCR chemical reaction, urea or ammoniabased chemicals are injected into th e combustion gas path to reduce the NO X 

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

8-1. 15

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

, March 2006.

14 NCASI, NO X

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-fir ed high performance power systems – Phase II topical report , Selective Non-Catalytic Reduction System De velopment Subcontract to United Technologies Research Center, Contract No. DE-AC22-95PC95144, February 24, 1997 (reprinted in NCASI’s Special Report No. 03-04).

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 8-5 F IGURE 

### 8-1. P RIMARY 

### SNCR R EACTION 

### S EQUENCES



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

NO X 

### 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 implem enting SNCR is the operating temperature range. The optimum temperature range is approximately 1,600 to 2,000 °F. 17


### Operation at temperatures below this ra nge results in ammonia slip. Operation above this range results in oxidatio n of ammonia, forming additional NO X 

### . In addition, the urea must have sufficient r esidence time, about 3 to 5 seconds, at the optimum operating temperatures for efficient NO X 

### 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 NO X



### level, b) temperature, c) mixing, d) residence time, e) reagent-to- NO X



### ratio, and f) fuel sulfur content. Lower inlet NO X 

### concentrations reduce the reaction kinetics and hence the achievable NO X 

### emissions reductions. As mentioned above, temperatures below the desired window result in ammonia emissions (slip), and temperatures above the
desired window result in NH 3 

### being oxidized to NO X



### . Mixing becomes an important consideration in regions dist ant 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 al low 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 (NO X ), Why and How They Are Controlled

. Research Triangle Park, North Carolina, EPA-456/F-99-006R, November 1999.

18 U.S. EPA. Summary of NO X

Control Technologies and their Avai lability and Extent of Application . Research Triangle Park, North Carolina. EPA-450/3-92-004, February 1992.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 8-6 completion. Small, packaged, wat er tube boilers and boilers with varying steam loads are therefore difficult applic ations for SNCR. As higher than the
theoretical NH 3 

### to NO X



### ratios are generally requi red to achieve desired NO X 

### emission reductions, a trade-off exists between NO X



### control and the presence of NH 3 

### in the flue gas. The main disadvantage of SNCR is the low NO X 

### reduction that is experienced when the allowable ammonia slip is low. Finally, in the case of high sulfur fuels, excess NH 3 

### can react with sulfur trioxide to form ammonium sulfa te 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 th at the use of SNCR systems on coal-fired boilers is still in the development stage. 21



### The NO X 

### OUT 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 + NH 2 

### CONH 2 

### + 1/2 O 2 

### → 2 N 2 

### + CO 2 

### + 2 H 2 

### O

The problems with typical SNCR systems (e.g., ammonia slippage and heat transfer surface fouling with byproduct formation) also exist with the NO X 

### OUT

process.



## 8.1.2.2 S ELECTIVE 

## C ATALYTIC 

## R EDUCTION



### SCR is a post-combustion gas treatment process in which NH 3 

### 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 NO X 

### decomposition. 22 

### On the catalyst surface, NH 3 

### and nitric oxide (NO) react to form diatomic nitrogen and water. The overall chemical reaction can be expressed as:

4NO + 4NH 3 

### + O 2 

### → 4N 2 

### + 6H 2 

### O

When operated within the optimum temp erature 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 NO X

19 U.S. EPA, New source performance standards, subpart Db – t echnical support for proposed revisions to NO X

, EPA-453-/R-95-012 (republished in NCASI’s Special Report 03-04).

20 NCASI, NO X

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.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 8-7 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 fluctuati ng temperature conditions (usually ± 50 ° F), although fluctuation in exhaust gas temp erature reduces removal efficiency by disturbing the chemical kinetics (speed) of the NO X 

### -removal reaction.

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

These are a) NO X



### level at SCR inlet, b) flue gas temperature, c) NH 3 

### -to-NOx ratio, d) fuel sulfur content, e) gas flow rate, and f) catalyst condition. For SCR, when inlet NO X



### concentrations fall below 150 ppm, the reduction efficiencies decrease with decreasing NO X



### concentrations. Each type of catalyst has an optimum operating temperature range. Temperatures below this range result in ammonia emissi ons (slip), and temperatures above the desired range result in NH 3 

### being oxidized to NO X



### . For up to about 80 percent NO X



### reduction efficiencies, a 1:1 NH 3 

### :NO X



### ratio is sufficient. For higher efficiencies, higher reagent to NO X



### ratios are required which may result in higher NH 3 

### slip. In the case of high sulfur fuels, excess NH 3 

### 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 S TEP 

## 2

– E LIMINATE 

## T ECHNICALLY 

## I NFEASIBLE 

## O PTIONS

Step 1 of the BART determination is the identification of all available retrofit NO X 

### 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 litera ture published by the U.S. EPA and the RPOs.

The available retrofit NO X 

### 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 – t echnical support for proposed revisions to NO X

, EPA-453-/R-95-012 (republished in NCASI’s Special Report 03-04).

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 8-8 T ABLE 

### 8-1. A VAILABLE 

### NO X 

### C ONTROL 

### T ECHNOLOGIES



### NO X 

### Control Technologies



### Flue Gas Recirculation (FGR)

Low NO X 

### Burners (LNB) Overfire Air (OFA) Combustion Controls

Reburning Methane, De- NO X 

### (MdN) Selective Catalytic Reduction (SCR) Post-Combustion Controls Selective Non-Catalytic Reduction (SNCR)



## 8.2.1 F LUE 

## G AS 

## R ECIRCULATION



### FGR is used to reduce thermal NO X 

### formation. Emissions due to fuel-bound NO X 

### , which are significant for coal-fired boilers, are not meaningf ully affected by FGR. Therefore, FGR is not technically feasible to control NO X 

### emissions from coal-fired boilers. 26



## 8.2.2 R EBURNING 

## / M ETHANE DE 

## -NO X



### 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 S TEP 

## 3

– E VALUATE 

## C ONTROL 

## E FFECTIVENESS OF 

## R EMAINING 

## C ONTROL 

## T ECHNOLOGIES

Table 8-2. Ranking of Control presents a ranking of the technically feasible control strategies in order of their effectiveness (i.e., potential contro l 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 woul d 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: NO X

Emissions from Utility Boilers. (EPA-453/R-94- 023).

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 8-9 T ABLE 

### 8-2. R ANKING OF 

### C ONTROL 

### T ECHNOLOGIES



### 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 Appe ndix E. Short-term controlled emission rates (lb/hr) were modeled in CALPUFF in or der to evaluate visibility impacts. These

controlled emission rates were calculated usi ng the maximum 24-hr emission rate (in lb/hr) observed over the 2002-05 period as a baseline emi ssion rate. This baseline emission rate (as described in Section 7.1) was then adjus ting 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 calculat ed 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 S TEP 

## 4

– E VALUATE 

## I MPACTS AND 

## D OCUMENT 

## R ESULTS

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 C OSTS OF 

## C OMPLIANCE



### Per the BART Guidelines, the costs of complianc e analysis for each cont rol option consists of comparisons of the average cost effectiveness and the incremental cost effectiveness, which
are defined in Section IV.D.4 as follows:

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 8-10 Average cost effectiveness means the total an nualized costs of control divided by the annual emissions reduction (the differen ce between baseline annual emissions and the estimate of emissions after controls), using the following formula:

Average cost effectiveness (dollars per t on removed) = Control option annualized cost ÷ (Baseline annual emissions – Annual emissions with Control option)

...the incremental cost effectiveness calcul ation compares the costs of performance level of a control option to those of the n ext 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, a nd 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 re ductions for the evaluated control technologies are included in Appendix E.

The average and incremental cost effectiveness for each feasible cont rol option for the NE
Station’s Unit 3 and Unit 4 are summarized in Table 8-3.

T ABLE 

### 8-3. NO X 

### C ONTROL 

### C OSTS 

### S UMMARY



### 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 E NERGY 

## I MPACTS 

## & N ON 

## -A IR 

## I MPACTS



### SCR systems will require additional electricity to prime blowers and pumps and the extra fan horsepower needed to overcome the hi gh pressure drop in the systems. These electricity needs will deter from the net pl ant output and represents a sizable energy penalty.

SCR can potentially cause significant environm ental impacts related to the usage and storage of ammonia. Storage of aqueous am monia 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 th e vicinity of the release. Ammonia can also

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 8-11 be emitted in the exhaust of boilers th at operate with SCR or SNCR for NO X 

### 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 NO x 

### , leading to an excess of unreacted ammonia, or from over-injection of reagent l eading 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 R EMAINING 

## U SEFUL 

## L IFE



### 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 S TEP 

## 5

– E VALUATE 

## V ISIBILITY 

## I MPACTS

A summary of visibility impacts from each NO X 

### control technology is summarized below. A comparison of all the modeled emission ra tes is provided in Table 8-4 below.

T ABLE 

### 8-4. NE S TATION 

### NO X 

### V ISIBILITY 

### R ESULTS



### Peak Impact 98th Percentile

Pollutant Class I Area Control Technology ( ∆ dv) % Reduction

from previous % Reduction

from

Baseline ( ∆ dv) % Reduction

from previous % Reduction

from

Baseline

NO X 

### 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%

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 8-12 

## 8.6 BART D ETERMINATION FOR 

## NO X



### In the BART guidelines, EPA calculated that for a ll 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 NO X 

### limits at a cost of $100 to $1,000 per ton of NO X 

### removed based on the use of combus tion 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 presump tive 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 com bustion 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 ov er the combustion control system is greater than nearly $10,000 per ton of NO X 

### removed for the Northeastern Units.

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 9-1 

## 9. BART D ETERMINATION 

## A NALYSIS FOR 

## SO 2



## 9.1 S TEP 

## 1

- I DENTIFY 

## A LL 

## A VAILABLE 

## R ETROFIT 

## C ONTROL 

## T ECHNOLOGIES

SO 2 

### emissions are a function of the sulfur content in th e fuel combusted. Thus, the type of coal being combusted is important in defining comparable controls/limits.

H 2 

### SO 4 

### is also a function of the fuel sulfur content. It is formed when the fuel sulfur is oxidized beyond SO 2 

### to sulfur trioxide (SO 3 

### ), which, for practical purposes, immediately becomes H 2 

### SO 4 

### in the presence of water vapor. Units with SCR may experience some additional H 2 

### SO 4 

### generation because the SCR catalyst will oxidize some additional portion of SO 2 

### to SO 3



### .



## 9.1.1 D RY 

## F LUE 

## G AS 

## D ESULFURIZATION 

## (DFGD)

In a DFGD system (which uses a spray dryer ab sorber [SDA]), an alka line reagent (usually lime), in the form of a slurry, is atomized in to the flue gas stream, where it reacts with and
collects the SO 2



### . 27 

### As with wet scrubbing, DFGD, when followed by a particulate control device, also removes significant amounts of H 2 

### SO 4 

### mist emissions. DFGD does not require the installation of a wastewater treatment plant si nce 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 SO 2 

### and H 2 

### SO 4 

### 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 d ecreases), the pollutant and the reagent have greater contact resulting in a higher SO 2 

### and H 2 

### SO 4 

### removal rates. The residence time of the pollutant and reagent mixture also dictates the amount of SO 2 

### and H 2 

### SO 4 

### mist removed. A particulate matter control is then used to remove the reacted dust (i.e., CaSO 4 

### ) from the flue
gas stream.



## 9.1.2 W ET 

## F LUE 

## G AS 

## D ESULFURIZATION 

## (WFGD)

WFGD, also known as wet scrubbing, is sometimes used to control SO 2 

### emissions from combustion sources. In a WFGD system, the combustion exhaust gas is typically contacted with an aqueous alkaline liquid inside a spray tower. SO 2 

### 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 SO 2 

### 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).

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 9-2 

## 9.2 S TEP 

## 2

– E LIMINATE 

## T ECHNICALLY 

## I NFEASIBLE 

## O PTIONS

Both control scenarios discussed above are considered technically feasible.



## 9.3 S TEP 

## 3

– E VALUATE 

## C ONTROL 

## E FFECTIVENESS OF 

## R EMAINING 

## C ONTROL 

## T ECHNOLOGIES

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

T ABLE 

### 9-1. R ANKING OF 

### C ONTROL 

### S TRATEGIES



### Control Strategy Applicability Potential Control Efficiency a



### 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 Appe ndix E. Short-term controlled emission rates (lb/hr) were modeled in CALPUFF in or der to evaluate visibility impacts. These
controlled emission rates were calculated usi ng the maximum 24-hr emission rate (in lb/hr) observed over the 2002-05 period as a baseline emi ssion rate. This baseline emission rate (as described in Section 7.1) was then adjus ting 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), calcu lated as discussed below, were used in compliance cost determinations. These emission rates were calculated using a baseline lb/MMBtu emission factor (as observed ove r 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 S TEP 

## 4

– E VALUATE 

## I MPACTS AND 

## D OCUMENT 

## R ESULTS

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

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 9-3 Each of the first four factors are addressed in Step 4. The fifth factor, visibility impacts, is evaluated in Step 5.



## 9.4.1 C OST OF 

## C OMPLIANCE



### 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 equipmen t modeled in this BART determination. A detailed summary of those costs is included in Appendix F.

T ABLE 

### 9-2. SO 2 

### C ONTROLS 

### C OSTS 

### S UMMARY



### 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 E NERGY 

## I MPACTS AND 

## N ON 

## -A IR 

## Q UALITY 

## I MPACTS



### FGD systems require electricity to prim e pumps and additiona l fan horsepower to overcome the high pressure drop in the system s. 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, c ontrol costs will be significantly higher because additional equipment is required in e ither waste disposal practices..

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



## 9.4.3 R EMAINING 

## U SEFUL 

## L IFE



### The remaining useful life of Unit 3 and Unit 4 do not impact the annualized capital costs
because the useful lives of the un its are anticipated to be at least as long as the capital cost recovery period, which is 20 years.



## 9.5 S TEP 

## 5

– E VALUATE 

## V ISIBILITY 

## I MPACTS

The final impact analysis was conducted to assess the visibility improvement for existing emission rates when compared to the presumptive BART em ission 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

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 9-4 CENRAP modeling guidleines. The BART ra tes 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 presumptiv e 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 ra tes is provided in Table 9-3 below.

T ABLE 

### 9-3. NE S TATION 

### SO 2 

### V ISIBILITY 

### R ESULTS



### Peak Impact 98th Percentile

Pollutant Class I Area Control Technology ( ∆ dv) % Reduction

from previous % Reduction

from Baseline ( ∆ dv) % Reduction

from previous % Reduction

from

Baseline

SO 2 

### 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 D ETERMINATION FOR 

## SO 2



### The average cost effectiveness for the DFGD and WFGD are $3,266 a nd $3,599, respectively. The incremental costs of installing a WFGD system ar e 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

### American Electric Power Trinity Consultants Northeastern Power Station 083701.0024 9-5 approximately 10%, or 0.49 

## dv (peak impact, Wichita Mountains). AEP notes that the incremental cost of a WFGD system is excessive when bala nced against the limited visibility gains and wastewater management issues inherent to WGFD.

### American Electric Power A-1 Trinity Consultants Northeastern Power Station 083701.0024 

## A PPENDIX 

## A- M ETEOROLOGICAL 

## S TATIONS

T ABLE 

### A-1. L IST OF 

### S URFACE METEOROLOGICAL 

### S TATIONS



### 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

### American Electric Power A-2 Trinity Consultants Northeastern Power Station 083701.0024 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 T ABLE 

### A-2. L IST OF 

### U PPER 

### A IR METEOROLOGICAL 

### S TATIONS



### 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 T ABLE 

### A-3. L IST OF 

### P RECIPITATION METEOROLOGICAL 

### S TATIONS



### 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 T ABLE 

### A-4. L IST OF 

### O VER 

### W ATER METEOROLOGICAL 

### S TATIONS



### 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 

## A PPENDIX 

## B

– S AMPLE 

## CALMET C ONTROL 

## F ILE01Met01a.inp2001 - 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 CASET = 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 101Met01a.inpUP1.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 201Met01a.inpTEST.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 bydelimiters) at the end of the group(3) Subgroups (b) and (c) must have an 'END' (surround bydelimiters) 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 = 07CST = 06, EST = 05Length of run (hours) (IRLG) -- No default ! IRLG= 240 !Run type (IRTYPE) -- Default: 1 ! IRTYPE= 1 !0 = Computes wind fields only1 = Computes wind fields and micrometeorological variables(u*, w*, L, zi, etc.)(IRTYPE must be 1 to run CALPUFF or CALGRID)Compute special data fields requiredby CALGRID (i.e., 3-D fields of W windcomponents and temperature)in additional to regular Default: T ! LCALGRD = T !fields ? (LCALGRD)(LCALGRD must be T to run CALGRID)Flag to stop run afterPage 301Met01a.inpSETUP phase (ITEST) Default: 2 ! ITEST= 2 !(Used to allow checkingof the model inputs, files, etc.)ITEST = 1 - STOPS program after SETUP phaseITEST = 2 - Continues with execution ofCOMPUTATIONAL 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 MercatorTTM : Tangential Transverse MercatorLCC : Lambert Conformal ConicPS : Polar StereographicEM : Equatorial MercatorLAZA : Lambert Azimuthal Equal AreaFalse 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 projectionS : Southern hemisphere projectionLatitude 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 projectionPage 401Met01a.inpRLAT0 selected for convenienceLCC : RLON0 identifies central (true N/S) meridian of projectionRLAT0 selected for conveniencePS : RLON0 identifies central (grid N/S) meridian of projectionRLAT0 selected for convenienceEM : RLON0 identifies central meridian of projectionRLAT0 is REPLACED by 0.0N (Equator)LAZA: RLON0 identifies longitude of tangent-point of mapping planeRLAT0 identifies latitude of tangent-point of mapping planeMatching 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 XLAT2PS : Projection plane slices through Earth at XLAT1(XLAT2 is not used)----------Note: Latitudes and longitudes should be positive, and include aletter N,S,E, or W indicating north or south latitude, andeast or west longitude. For example,35.9 N Latitude = 35.9N118.7 E Longitude = 118.7EDatum-region------------The Datum-Region for the coordinates is identified by a characterstring. Many mapping products currently available use the model of theEarth known as the World Geodetic System 1984 (WGS-G ). Other localmodels may be in use, and their selection in CALMET will make its outputconsistent with local mapping products. The list of Datum-Regions withofficial transformation parameters is provided by the National Imagery andMapping 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, SphereNWS-84 NWS 6370KM Radius, SphereESR-S ESRI REFERENCE 6371KM Radius, SphereDatum-region for output coordinates(DATUM) Default: WGS-G ! DATUM = WGS-G !Page 501Met01a.inpHorizontal grid definition:---------------------------Rectangular grid defined for projection PMAP,with X the Easting and Y the Northing coordinateNo. 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: kmReference grid coordinate ofSOUTHWEST corner of grid cell (1,1)X coordinate (XORIGKM) No default ! XORIGKM = -951.547 !Y coordinate (YORIGKM) No default ! YORIGKM = -1646.637 !Units: kmVertical grid definition:-------------------------No. of vertical layers (NZ) No default ! NZ = 12 !Cell face heights in arbitraryvertical grid (ZFACE(NZ+1)) No defaultsUnits: m! ZFACE = 0.,20.,40.,60.,80.,100.,150.,200.,250.,500.,1000.,2000.,3500. !!END!-------------------------------------------------------------------------------INPUT GROUP: 3 -- Output Options--------------DISK OUTPUT OPTIONSave met. fields in an unformattedoutput file ? (LSAVE) Default: T ! LSAVE = T !(F = Do not save, T = Save)Type of unformatted output file:Page 601Met01a.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 whichmet. variables are printed)Print interval(IPRINF) in hours Default: 1 ! IPRINF = 1 !(Meteorological fields are printedevery 1 hours)Specify which layers of U, V wind componentto 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 fieldsto print(used only if LPRINT=T) Defaults: 0 (all variables)Page 701Met01a.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 modulePrint input meteorological data andinternal 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 dataare printed (NN1) Default: 1 ! NN1 = 1 !Last time step for which debug dataare printed (NN2) Default: 1 ! NN2 = 1 !Testing and debug print options for wind field module(all of the following print options control output towind field module's output files: TEST.PRT, TEST.OUT,TEST.KIN, TEST.FRD, and TEST.SLP)Control variable for writing the test/debugwind 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 windPage 801Met01a.inpcomponents ?(IPR1) (0=no, 1=yes) Default: 0 ! IPR1 = 0 !Print the SMOOTHED wind components andthe INITIAL DIVERGENCE fields ?(IPR2) (0=no, 1=yes) Default: 0 ! IPR2 = 0 !Print the FINAL wind speed and directionfields ?(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 effectsare added ?(IPR5) (0=no, 1=yes) Default: 0 ! IPR5 = 0 !Print the winds after the FROUDE NUMBERadjustment is made ?(IPR6) (0=no, 1=yes) Default: 0 ! IPR6 = 0 !Print the winds after SLOPE FLOWSare 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 stations1 = Use surface and overwater stations (no upper air observations)Use MM5 for upper air data2 = No surface, overwater, or upper air observationsUse MM5 for surface, overwater, and upper air dataNUMBER OF SURFACE & PRECIP. METEOROLOGICAL STATIONSNumber of surface stations (NSSTA) No default ! NSSTA = 162 !Page 901Met01a.inpNumber of precipitation stations(NPSTA=-1: flag for use of MM5 precip data)(NPSTA) No default ! NPSTA = 298 !CLOUD DATA OPTIONSGridded cloud fields:(ICLOUD) Default: 0 ! ICLOUD = 0 !ICLOUD = 0 - Gridded clouds not usedICLOUD = 1 - Gridded CLOUD.DAT generated as OUTPUTICLOUD = 2 - Gridded CLOUD.DAT read as INPUTICLOUD = 3 - Gridded cloud cover from Prognostic Rel. HumidityFILE FORMATSSurface 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 OPTIONSModel selection variable (IWFCOD) Default: 1 ! IWFCOD = 1 !0 = Objective analysis only1 = Diagnostic wind moduleCompute Froude number adjustmenteffects ? (IFRADJ) Default: 1 ! IFRADJ = 1 !(0 = NO, 1 = YES)Compute kinematic effects ? (IKINE) Default: 0 ! IKINE = 0 !Page 1001Met01a.inp(0 = NO, 1 = YES)Use O'Brien procedure for adjustmentof 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 observationsto upper layers ? (IEXTRP) Default: -4 ! IEXTRP = -4 !(1 = no extrapolation is done,2 = power law extrapolation used,3 = user input multiplicative factorsfor layers 2 - NZ used (see FEXTRP array)4 = similarity theory used-1, -2, -3, -4 = same as above except layer 1 dataat upper air stations are ignoredExtrapolate surface winds evenif calm? (ICALM) Default: 0 ! ICALM = 0 !(0 = NO, 1 = YES)Layer-dependent biases modifying the weights ofsurface and upper air stations (BIAS(NZ))-1<=BIAS<=1Negative BIAS reduces the weight of upper air stations(e.g. BIAS=-0.1 reduces the weight of upper air stationsby 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 stationsby 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 , 0 , 0 !Minimum distance from nearest upper air stationto surface station for which extrapolationof surface winds at surface station will be allowed(RMIN2: Set to -1 for IEXTRP = 4 or other situationswhere all surface stations should be extrapolated)Default: 4. ! RMIN2 = -1.0 !Use gridded prognostic wind field modeloutput fields as input to the diagnosticwind 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]Page 1101Met01a.inp2 = 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 prognosticmodel input data (ISTEPPG) Default: 1 ! ISTEPPG = 1 !RADIUS OF INFLUENCE PARAMETERSUse 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 landin the surface layer (RMAX1) No default ! RMAX1 = 20. !Units: kmMaximum radius of influence over landaloft (RMAX2) No default ! RMAX2 = 50. !Units: kmMaximum radius of influence over water(RMAX3) No default ! RMAX3 = 500. !Units: kmOTHER WIND FIELD INPUT PARAMETERSMinimum radius of influence used inthe wind field interpolation (RMIN) Default: 0.1 ! RMIN = 0.1 !Units: kmRadius of influence of terrainfeatures (TERRAD) No default ! TERRAD = 10. !Units: kmRelative weighting of the firstguess field and observations in theSURFACE layer (R1) No default ! R1 = 10. !(R1 is the distance from an Units: kmobservational station at which theobservation and first guess field areequally weighted)Relative weighting of the firstguess field and observations in thelayers ALOFT (R2) No default ! R2 = 25. !Page 1201Met01a.inp(R2 is applied in the upper layers Units: kmin the same manner as R1 is used inthe surface layer).Relative weighting parameter of theprognostic wind field data (RPROG) No default ! RPROG = 54. !(Used only if IPROG = 1) Units: km------------------------Maximum acceptable divergence in thedivergence minimization procedure(DIVLIM) Default: 5.E-6 ! DIVLIM= 5.0E-06 !Maximum number of iterations in thedivergence min. procedure (NITER) Default: 50 ! NITER = 50 !Number of passes in the smoothingprocedure (NSMTH(NZ))NOTE: NZ values must be enteredDefault: 2,(mxnz-1)*4 ! NSMTH =2 , 4 , 4 , 4 , 4 , 4 , 4 , 4 , 4 , 4 , 4 , 4 !Maximum number of stations used ineach layer for the interpolation ofdata 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 theinfluence of kinematic effects(ALPHA) Default: 0.1 ! ALPHA = 0.1 !Multiplicative scaling factor forextrapolation of surface observationsto 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 INFORMATIONNumber of barriers to interpolationof the wind fields (NBAR) Default: 0 ! NBAR = 0 !THE FOLLOWING 4 VARIABLES ARE INCLUDEDONLY IF NBAR > 0Page 1301Met01a.inpNOTE: NBAR values must be entered No defaultsfor each variable Units: kmX coordinate of BEGINNINGof each barrier (XBBAR(NBAR)) ! XBBAR = 0. !Y coordinate of BEGINNINGof each barrier (YBBAR(NBAR)) ! YBBAR = 0. !X coordinate of ENDINGof each barrier (XEBAR(NBAR)) ! XEBAR = 0. !Y coordinate of ENDINGof each barrier (YEBAR(NBAR)) ! YEBAR = 0. !DIAGNOSTIC MODULE DATA INPUT OPTIONSSurface temperature (IDIOPT1) Default: 0 ! IDIOPT1 = 0 !0 = Compute internally fromhourly surface observations1 = Read preprocessed values froma data file (DIAG.DAT)Surface met. station to use forthe surface temperature (ISURFT) No default ! ISURFT = 64 !(Must be a value from 1 to NSSTA)(Used only if IDIOPT1 = 0)--------------------------Domain-averaged temperature lapserate (IDIOPT2) Default: 0 ! IDIOPT2 = 0 !0 = Compute internally fromtwice-daily upper air observations1 = Read hourly preprocessed valuesfrom a data file (DIAG.DAT)Upper air station to use forthe 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-scalelapse rate is computed (ZUPT) Default: 200. ! ZUPT = 200. !(Used only if IDIOPT2 = 0) Units: meters--------------------------Domain-averaged wind components(IDIOPT3) Default: 0 ! IDIOPT3 = 0 !Page 1401Met01a.inp0 = Compute internally fromtwice-daily upper air observations1 = Read hourly preprocessed valuesa data file (DIAG.DAT)Upper air station to use forthe 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 throughwhich the domain-scale windsare computed(ZUPWND(1), ZUPWND(2)) Defaults: 1., 1000. ! ZUPWND= 1., 2000. !(Used only if IDIOPT3 = 0) Units: meters--------------------------Observed surface wind componentsfor wind field module (IDIOPT4) Default: 0 ! IDIOPT4 = 0 !0 = Read WS, WD from a surfacedata file (SURF.DAT)1 = Read hourly preprocessed U, V froma data file (DIAG.DAT)Observed upper air wind componentsfor wind field module (IDIOPT5) Default: 0 ! IDIOPT5 = 0 !0 = Read WS, WD from an upperair data file (UP1.DAT, UP2.DAT, etc.)1 = Read hourly preprocessed U, V froma data file (DIAG.DAT)LAKE BREEZE INFORMATIONUse 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. !Page 1501Met01a.inpX 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 CONSTANTSNeutral, 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 Coriolisparameter (FCORIOL) Default: 1.E-4 ! FCORIOL = 1.0E-04!Units: (1/s)SPATIAL AVERAGING OF MIXING HEIGHTSConduct spatial averaging(IAVEZI) (0=no, 1=yes) Default: 1 ! IAVEZI = 1 !Max. search radius in averagingPage 1601Met01a.inpprocess (MNMDAV) Default: 1 ! MNMDAV = 1 !Units: GridcellsHalf-angle of upwind looking conefor averaging (HAFANG) Default: 30. ! HAFANG = 30. !Units: deg.Layer of winds used in upwindaveraging (ILEVZI) Default: 1 ! ILEVZI = 1 !(must be between 1 and NZ)OTHER MIXING HEIGHT VARIABLESMinimum potential temperature lapserate in the stable layer above thecurrent convective mixing ht. Default: 0.001 ! DPTMIN = 0.001 !(DPTMIN) Units: deg. K/mDepth of layer above current conv.mixing height through which lapse Default: 200. ! DZZI = 200. !rate is computed (DZZI) Units: metersMinimum overland mixing height Default: 50. ! ZIMIN = 20. !(ZIMIN) Units: metersMaximum overland mixing height Default: 3000. ! ZIMAX = 3500. !(ZIMAX) Units: metersMinimum overwater mixing height Default: 50. ! ZIMINW = 20. !(ZIMINW) -- (Not used if observed Units: metersoverwater mixing hts. are used)Maximum overwater mixing height Default: 3000. ! ZIMAXW = 3500. !(ZIMAXW) -- (Not used if observed Units: metersoverwater mixing hts. are used)TEMPERATURE PARAMETERS3D temperature from observations orfrom 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 observationsUse 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 !Page 1701Met01a.inpRadius of influence for temperatureinterpolation (TRADKM) Default: 500. ! TRADKM = 500. !Units: kmMaximum Number of stations to includein 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,HAFANGso make sure they are correct)Default temperature gradient Default: -.0098 ! TGDEFB = -0.0098 !below the mixing height overwater (K/m) (TGDEFB)Default temperature gradient Default: -.0045 ! TGDEFA = -0.0045 !above the mixing height overwater (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 disablePRECIP INTERPOLATION PARAMETERSMethod 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. btwnnearest stns w & w/outprecip 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)Page 1801Met01a.inp1 2Name 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 !Page 1901Met01a.inp! 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 !Page 2001Met01a.inp! 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 !Page 2101Met01a.inp! 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 !-------------------1Four character string for station name(MUST START IN COLUMN 9)2Five 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 2Name ID X coord. Y coord. Time zone(km) (km)-----------------------------------------------Page 2201Met01a.inp! 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 !-------------------1Four character string for station name(MUST START IN COLUMN 9)2Five 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 2Name 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 !Page 2301Met01a.inp! 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 !Page 2401Met01a.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 !Page 2501Met01a.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 2601Met01a.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 2701Met01a.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 !Page 2801Met01a.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 !Page 2901Met01a.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 !-------------------1Four character string for station name(MUST START IN COLUMN 9)2Six digit station code composed of statecode (first 2 digits) and station ID (last4 digits)!END!Page 30

### American Electric Power C-1 Trinity Consultants Northeastern Power Station 083701.0024 

## A PPENDIX 

## C

– S AMPLE 

## CALPUFF C ONTROL 

## F ILE2001_NE_NOx.inpAEP 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 12001_NE_NOx.inpCOASTLN.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 CASET = 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 22001_NE_NOx.inpnone 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 foundin the met. file (METRUN) Default: 0 ! METRUN = 0 !METRUN = 0 - Run period explicitly defined belowMETRUN = 1 - Run all periods in met. fileStarting 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.Page 32001_NE_NOx.inpCST = 6., EST = 5.Length of run (hours) (IRLG) -- No default ! IRLG = 8760 !Number of chemical species (NSPEC)Default: 5 ! NSPEC = 10 !Number of chemical speciesto be emitted (NSE) Default: 3 ! NSE = 7 !Flag to stop run afterSETUP phase (ITEST) Default: 2 ! ITEST = 2 !(Used to allow checkingof the model inputs, files, etc.)ITEST = 1 - STOPS program after SETUP phaseITEST = 2 - Continues with execution of programafter SETUPRestart Configuration:Control flag (MRESTART) Default: 0 ! MRESTART = 0 !0 = Do not read or write a restart file1 = Read a restart file at the beginning ofthe run2 = Write a restart file during run3 = Read a restart file at beginning of runand write a restart file during runNumber of periods in Restartoutput cycle (NRESPD) Default: 0 ! NRESPD = 0 !0 = File written only at last period>0 = File updated every NRESPD periodsMeteorological 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) andsurface parameters file (SURFACE.DAT)PG sigma-y is adjusted by the factor (AVET/PGTIME)**0.2Averaging Time (minutes) (AVET)Default: 60.0 ! AVET = 60. !PG Averaging Time (minutes) (PGTIME)Page 42001_NE_NOx.inpDefault: 60.0 ! PGTIME = 60. !!END!-------------------------------------------------------------------------------INPUT GROUP: 2 -- Technical options--------------Vertical distribution used in thenear field (MGAUSS) Default: 1 ! MGAUSS = 1 !0 = uniform1 = GaussianTerrain adjustment method(MCTADJ) Default: 3 ! MCTADJ = 3 !0 = no adjustment1 = ISC-type of terrain adjustment2 = simple, CALPUFF-type of terrainadjustment3 = partial plume path adjustmentSubgrid-scale complex terrainflag (MCTSG) Default: 0 ! MCTSG = 0 !0 = not modeled1 = modeledNear-field puffs modeled aselongated 0 (MSLUG) Default: 0 ! MSLUG = 0 !0 = no1 = 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 buildingdownwash? (MBDW) Default: 1 ! MBDW = 1 !1 = ISC method2 = PRIME methodPage 52001_NE_NOx.inpVertical wind shear modeled abovestack 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 notmodeled1 = transformation rates computedinternally (MESOPUFF II scheme)2 = user-specified transformationrates used3 = transformation rates computedinternally (RIVAD/ARM3 scheme)4 = secondary organic aerosol formationcomputed (MESOPUFF II scheme for OH)Aqueous phase transformation flag (MAQCHEM)(Used only if MCHEM = 1, or 3) Default: 0 ! MAQCHEM = 0 !0 = aqueous phase transformationnot modeled1 = transformation rates adjustedfor aqueous phase reactionsWet removal modeled ? (MWET) Default: 1 ! MWET = 1 !0 = no1 = yesDry deposition modeled ? (MDRY) Default: 1 ! MDRY = 1 !0 = no1 = yes(dry deposition method specifiedfor each species in Input Group 3)Method used to compute dispersioncoefficients (MDISP) Default: 3 ! MDISP = 3 !1 = dispersion coefficients computed from measured valuesof turbulence, sigma v, sigma w2 = dispersion coefficients from internally calculatedsigma v, sigma w using micrometeorological variables(u*, w*, L, etc.)3 = PG dispersion coefficients for RURAL areas (computed usingPage 62001_NE_NOx.inpthe ISCST multi-segment approximation) and MP coefficients inurban areas4 = same as 3 except PG coefficients computed usingthe MESOPUFF II eqns.5 = CTDM sigmas used for stable and neutral conditions.For unstable conditions, sigmas are computed as inMDISP = 3, described above. MDISP = 5 assumes thatmeasured values are readSigma-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 measurementsfrom PROFILE.DAT to compute sigma-y(valid for METFM = 1, 2, 3, 4)2 = use sigma-w measurementsfrom PROFILE.DAT to compute sigma-z(valid for METFM = 1, 2, 3, 4)3 = use both sigma-(v/theta) and sigma-wfrom PROFILE.DAT to compute sigma-y and sigma-z(valid for METFM = 1, 2, 3, 4)4 = use sigma-theta measurementsfrom PLMMET.DAT to compute sigma-y(valid only if METFM = 3)Back-up method used to compute dispersionwhen measured turbulence data aremissing (MDISP2) Default: 3 ! MDISP2 = 3 !(used only if MDISP = 1 or 5)2 = dispersion coefficients from internally calculatedsigma v, sigma w using micrometeorological variables(u*, w*, L, etc.)3 = PG dispersion coefficients for RURAL areas (computed usingthe ISCST multi-segment approximation) and MP coefficients inurban areas4 = same as 3 except PG coefficients computed usingthe MESOPUFF II eqns.PG sigma-y,z adj. for roughness? Default: 0 ! MROUGH = 0 !(MROUGH)0 = no1 = yesPartial plume penetration of Default: 1 ! MPARTL = 1 !elevated inversion?(MPARTL)0 = no1 = yesPage 72001_NE_NOx.inpStrength of temperature inversion Default: 0 ! MTINV = 0 !provided in PROFILE.DAT extended records?(MTINV)0 = no (computed from measured/default gradients)1 = yesPDF used for dispersion under convective conditions?Default: 0 ! MPDF = 0 !(MPDF)0 = no1 = yesSub-Grid TIBL module used for shore line?Default: 0 ! MSGTIBL = 0 !(MSGTIBL)0 = no1 = yesBoundary conditions (concentration) modeled?Default: 0 ! MBCON = 0 !(MBCON)0 = no1 = yes, using formatted BCON.DAT file2 = yes, using unformatted CONC.DAT fileAnalyses of fogging and icing impacts due to emissions fromarrays of mechanically-forced cooling towers can be performedusing CALPUFF in conjunction with a cooling tower emissionsprocessor (CTEMISS) and its associated postprocessors. Hourlyemissions of water vapor and temperature from each cooling towercell are computed for the current cell configuration and ambientconditions by CTEMISS. CALPUFF models the dispersion of theseemissions and provides cloud information in a specialized formatfor 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 = no1 = yes - report results in PLUME Mode format2 = yes - report results in RECEPTOR Mode formatTest options specified to see ifthey conform to regulatoryvalues? (MREG) Default: 1 ! MREG = 0 !Page 82001_NE_NOx.inp0 = NO checks are made1 = Technical options must conform to USEPALong Range Transport (LRT) guidanceMETFM 1 or 2AVET 60. (min)PGTIME 60. (min)MGAUSS 1MCTADJ 3MTRANS 1MTIP 1MCHEM 1 or 3 (if modeling SOx, NOx)MWET 1MDRY 1MDISP 2 or 3MPDF 0 if MDISP=31 if MDISP=2MROUGH 0MPARTL 1SYTDEP 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!Page 92001_NE_NOx.inpDry OUTPUT GROUPSPECIES MODELED EMITTED DEPOSITED NUMBERNAME (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 resultsfor certain species are combined (added) prior to output. TheCGRUP name will be used as the species name in output files.Use this feature to model specific particle-size distributionsby 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 MercatorTTM : Tangential Transverse MercatorLCC : Lambert Conformal ConicPS : Polar StereographicPage 102001_NE_NOx.inpEM : Equatorial MercatorLAZA : Lambert Azimuthal Equal AreaFalse 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 projectionS : Southern hemisphere projectionLatitude 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 projectionRLAT0 selected for convenienceLCC : RLON0 identifies central (true N/S) meridian of projectionRLAT0 selected for conveniencePS : RLON0 identifies central (grid N/S) meridian of projectionRLAT0 selected for convenienceEM : RLON0 identifies central meridian of projectionRLAT0 is REPLACED by 0.0N (Equator)LAZA: RLON0 identifies longitude of tangent-point of mapping planeRLAT0 identifies latitude of tangent-point of mapping planeMatching 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 XLAT2PS : Projection plane slices through Earth at XLAT1(XLAT2 is not used)----------Note: Latitudes and longitudes should be positive, and include aletter N,S,E, or W indicating north or south latitude, andeast or west longitude. For example,35.9 N Latitude = 35.9NPage 112001_NE_NOx.inp118.7 E Longitude = 118.7EDatum-region------------The Datum-Region for the coordinates is identified by a characterstring. Many mapping products currently available use the model of theEarth known as the World Geodetic System 1984 (WGS-G ). Other localmodels may be in use, and their selection in CALMET will make its outputconsistent with local mapping products. The list of Datum-Regions withofficial transformation parameters is provided by the National Imagery andMapping 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, SphereNWS-84 NWS 6370KM Radius, SphereESR-S ESRI REFERENCE 6371KM Radius, SphereDatum-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 coordinateNo. 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: kmCell face heights(ZFACE(nz+1)) No defaultsUnits: m! ZFACE = 0.,20.,40.,60.,80.,100.,150.,200.,250.,500.,1000.,2000.,3500. !Reference Coordinatesof SOUTHWEST corner ofgrid cell(1, 1):Page 122001_NE_NOx.inpX 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 thecomputational 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 thesampling grid is at grid point (IESAMP, JESAMP) of the MET. grid.The sampling grid must be identical to or a subset of the computationalgrid. It may be a nested grid inside the computational grid.The grid spacing of the sampling grid is DGRIDKM/MESHDN.Logical flag indicating if griddedreceptors 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)Page 132001_NE_NOx.inpX 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 samplinggrid (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 isrequired for visibilityanalysis)Use data compression option in output file?(LCOMPRS) Default: T ! LCOMPRS = T !*0 = Do not create file, 1 = create fileDIAGNOSTIC MASS FLUX OUTPUT OPTIONS:Mass flux across specified boundariesfor selected species reported hourly?(IMFLX) Default: 0 ! IMFLX = 0 !0 = no1 = yes (FLUXBDY.DAT and MASSFLX.DAT filenamesare specified in Input Group 0)Mass balance for each speciesPage 142001_NE_NOx.inpreported hourly?(IMBAL) Default: 0 ! IMBAL = 0 !0 = no1 = yes (MASSBAL.DAT filename isspecified 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 forConcentration Deposition1 = g/m**3 g/m**2/s2 = mg/m**3 mg/m**2/s3 = ug/m**3 ug/m**2/s4 = ng/m**3 ng/m**2/s5 = Odour UnitsMessages tracking progress of runwritten to the screen ?(IMESG) Default: 2 ! IMESG = 2 !0 = no1 = 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 ------ -- MASSFLUX --SPECIES/GROUP PRINTED? SAVED ON DISK? PRINTED? SAVED ON DISK? PRINTED? SAVED ON DISK? SAVED ONDISK?------- ------------------------ ------------------------ ---------------------------------------Page 152001_NE_NOx.inp! SO2 = 0, 1, 0, 1, 0, 1, 1 !! SO4 = 0, 1, 0, 1, 0, 1, 1 !! NOX = 0, 1, 0, 1, 0, 1, 1 !! HNO3 = 0, 1, 0, 1, 0, 1, 1 !! NO3 = 0, 1, 0, 1, 0, 1, 1 !! PMC = 0, 1, 0, 1, 0, 1, 1 !! PMF = 0, 1, 0, 1, 0, 1, 1 !! EC = 0, 1, 0, 1, 0, 1, 1 !! SOA = 0, 1, 0, 1, 0, 1, 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 terrainreceptors (NCTREC) Default: 0 ! NCTREC = 0 !Terrain and CTSG Receptor data forCTSG hills input in CTDM format ?(MHILL) No Default ! MHILL = 2 !1 = Hill and Receptor data createdPage 162001_NE_NOx.inpby CTDM processors & read fromHILL.DAT and HILLRCT.DAT files2 = 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 SCALE 2 AMAX1AMAX2NO. (km) (km) (deg.) (m) (m) (m) (m) (m) (m) (m)(m)---- ---- ---- ------ ----- ------ ------ ------ ------- ------- -------------------------Subgroup (6c)---------------COMPLEX TERRAIN RECEPTOR INFORMATIONXRCT YRCT ZRCT XHH(km) (km) (m)------ ----- ------ -----------------------1Page 172001_NE_NOx.inpDescription of Complex Terrain Variables:XC, YC = Coordinates of center of hillTHETAH = Orientation of major axis of hill (clockwise fromNorth)ZGRID = Height of the 0 of the grid above mean sealevelRELIEF = Height of the crest of the hill above the grid elevationEXPO 1 = Hill-shape exponent for the major axisEXPO 2 = Hill-shape exponent for the major axisSCALE 1 = Horizontal length scale along the major axisSCALE 2 = Horizontal length scale along the minor axisAMAX = Maximum allowed axis length for the major axisBMAX = Maximum allowed axis length for the major axisXRCT, YRCT = Coordinates of the complex terrain receptorsZRCT = Height of the ground (MSL) at the complex terrainReceptorXHH = 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 separateinput 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 HENRY'S LAWCOEFFICIENTNAME (cm**2/s) (s/cm)(dimensionless)------- ----------- ---------- ---------- -------------------------------------------! SO2 = 0.1509, 1000., 8., 0., 0.04 !! NOX = 0.1656, 1., 8., 5., 3.5 !! HNO3 = 0.1628, 1., 18., 0., 0.00000008 !!END!-------------------------------------------------------------------------------INPUT GROUP: 8 -- Size parameters for dry deposition of particlesPage 182001_NE_NOx.inp--------------For SINGLE SPECIES, the mean and standard deviation are used tocompute 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 explicitlyspecified (by the 'species' in the group), and the standard deviationfor each should be entered as 0. The model will then use thedeposition velocity for the stated mean diameter.SPECIES GEOMETRIC MASS MEAN GEOMETRIC STANDARDNAME 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 toevaluate 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 vegetationIVEG=2 for active and stressed vegetationIVEG=3 for inactive vegetationPage 192001_NE_NOx.inp!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 value1 = read hourly ozone concentrations fromthe OZONE.DAT data fileMonthly ozone concentrations(Used only if MCHEM = 1, 3, or 4 andMOZ = 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, 40.00 !Monthly ammonia concentrations(Used only if MCHEM = 1, or 3)(BCKNH3) in ppb Default: 12*10.Page 202001_NE_NOx.inp! 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 value1 = read hourly H2O2 concentrations fromthe H2O2.DAT data fileMonthly H2O2 concentrations(Used only if MQACHEM = 1 andMH2O2 = 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 computingthe 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 12Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov DecClean ContinentalBCKPMF 1. 1. 1. 1. 1. 1. 1. 1. 1. 1. 1. 1.OFRAC .15 .15 .20 .20 .20 .20 .20 .20 .20 .20 .20 .15VCNX 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 .5OFRAC .25 .25 .30 .30 .30 .30 .30 .30 .30 .30 .30 .25VCNX 50. 50. 50. 50. 50. 50. 50. 50. 50. 50. 50. 50.Page 212001_NE_NOx.inpUrban - 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 .20VCNX 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 .25VCNX 15. 15. 15. 15. 15. 15. 15. 15. 15. 15. 15. 15.Regional PlumeBCKPMF 20. 20. 20. 20. 20. 20. 20. 20. 20. 20. 20. 20.OFRAC .20 .20 .25 .35 .25 .40 .40 .40 .30 .30 .30 .20VCNX 15. 15. 15. 15. 15. 15. 15. 15. 15. 15. 15. 15.Urban - no controls presentBCKPMF 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100.OFRAC .30 .30 .35 .35 .35 .55 .55 .55 .35 .35 .35 .30VCNX 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, 50.00, 50.00 !!END!-------------------------------------------------------------------------------INPUT GROUP: 12 -- Misc. Dispersion and Computational Parameters---------------Horizontal size of puff (m) beyond whichtime-dependent dispersion equations (Heffter)are used to determine sigma-y andsigma-z (SYTDEP) Default: 550. ! SYTDEP = 5.5E02 !Switch for using Heffter equation for sigma zas above (0 = Not use Heffter; 1 = use Heffter(MHFTSZ) Default: 0 ! MHFTSZ = 0 !Stability class used to determine plumegrowth rates for puffs above the boundarylayer (JSUP) Default: 5 ! JSUP = 5 !Page 222001_NE_NOx.inpVertical dispersion constant for stableconditions (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 fromSchulman-Scire to Huber-Snyder Building Downwashscheme (SS used for Hs < Hb + TBD * HL)(TBD) Default: 0.5 ! TBD = .5 !TBD < 0 ==> always use Huber-SnyderTBD = 1.5 ==> always use Schulman-ScireTBD = 0.5 ==> ISC Transition-pointRange of land use categories for whichurban 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)Page 232001_NE_NOx.inp(ISIGMAV) Default: 1 ! ISIGMAV = 1 !0 = read sigma-theta1 = read sigma-vChoice of mixing heights (Used only if METFM = 4)(IMIXCTDM) Default: 0 ! IMIXCTDM = 0 !0 = read PREDICTED mixing heights1 = read OBSERVED mixing heightsMaximum length of a slug (met. grid units)(XMXLEN) Default: 1.0 ! XMXLEN = 1.0 !Maximum travel distance of a puff/slug (ingrid units) during one sampling step(XSAMLEN) Default: 1.0 ! XSAMLEN = 10 !Maximum Number of slugs/puffs release fromone source during one time step(MXNEW) Default: 99 ! MXNEW = 60 !Maximum Number of sampling steps forone puff/slug during one time step(MXSAM) Default: 99 ! MXSAM = 60 !Number of iterations used when computingthe transport wind for a sampling stepthat includes gradual rise (for CALMETand 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 velocitiessigma-v and sigma-w for eachstability class (m/s)(SVMIN(6) and SWMIN(6)) Default SVMIN : .50, .50, .50, .50, .50, .50Default SWMIN : .20, .12, .08, .06, .03, .016Stability 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 puffPage 242001_NE_NOx.inpused to initiate adjustment for horizontalconvergence (1/s)Partial adjustment starts at CDIV(1), andfull adjustment is reached at CDIV(2)(CDIV(2)) Default: 0.0,0.0 ! CDIV = 0.01, 0.01 !Minimum wind speed (m/s) allowed fornon-calm conditions. Also used as minimumspeed returned when using power-lawextrapolation 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-lawexponents for stabilities 1-6(PLX0(6)) Default : ISC RURAL valuesISC RURAL : .07, .07, .10, .15, .35, .55ISC URBAN : .15, .15, .20, .25, .30, .30Stability Class : A B C D E F--- --- --- --- --- ---! PLX0 = 0.07, 0.07, 0.10, 0.15, 0.35, 0.55 !Default potential temperature gradientfor stable classes E, F (degK/m)(PTG0(2)) Default: 0.020, 0.035! PTG0 = 0.020, 0.035 !Default plume path coefficients foreach stability class (used when optionfor partial plume height terrain adjustmentis selected -- MCTADJ=3)(PPC(6)) Stability Class : A B C D E FPage 252001_NE_NOx.inpDefault 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 factorequal 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 puffis split - nsplit=2 means that 1 puff splitsinto 2(NSPLIT) Default: 3 ! NSPLIT = 3 !Time(s) of a day when split puffs are eligible tobe split once again; this is typically set onceper 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 mixingheight (m) exceeds a minimum value(ZISPLIT) Default: 100. ! ZISPLIT = 100.0 !Split is allowed only if ratio of last hour'smixing ht to the maximum mixing ht experiencedby the puff is less than a maximum value (thispostpones a split until a nocturnal layer develops)(ROLDMAX) Default: 0.25 ! ROLDMAX = 0.25 !HORIZONTAL SPLIT----------------Number of puffs that result every time a puffis split - nsplith=5 means that 1 puff splitsinto 5(NSPLITH) Default: 5 ! NSPLITH = 5 !Minimum sigma-y (Grid Cells Units) of puffbefore it may be split(SYSPLITH) Default: 1.0 ! SYSPLITH = 1.0 !Page 262001_NE_NOx.inpMinimum puff elongation rate (SYSPLITH/hr) due towind shear, before it may be split(SHSPLITH) Default: 2. ! SHSPLITH = 2.0 !Minimum concentration (g/m^3) of eachspecies in puff before it may be splitEnter array of NSPEC values; if a single value isentered, it will be used for ALL species(CNSPLITH) Default: 1.0E-07 ! CNSPLITH = 1.0E-07 !Integration control variables ------------------------Fractional convergence criterion for numerical SLUGsampling integration(EPSSLUG) Default: 1.0e-04 ! EPSSLUG = 1.0E-04 !Fractional convergence criterion for numerical AREAsource integration(EPSAREA) Default: 1.0e-06 ! EPSAREA = 1.0E-06 !Trajectory step-length (m) used for numerical riseintegration(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 heightat the release point if greater than this minimum.(HTMINBC) Default: 500. ! HTMINBC = 500.0 !Search radius (in BC segment lengths) about a receptor for samplingnearest BC puff. BC puffs are emitted with a spacing of one segmentlength, so the search radius should be greater than 1.(RSAMPBC) Default: 4. ! RSAMPBC = 10.0 !Near-Surface depletion adjustment to concentration profile used whensampling BC puffs?(MDEPBC) Default: 1 ! MDEPBC = 1 !0 = Concentration is NOT adjusted for depletion1 = Adjust Concentration for depletion!END!-------------------------------------------------------------------------------Page 272001_NE_NOx.inpINPUT GROUPS: 13a, 13b, 13c, 13d -- Point source parameters-----------------------------------------------Subgroup (13a)---------------Number of point sources withparameters provided below (NPT1) No default ! NPT1 = 2 !Units used for point sourceemissions below (IPTU) Default: 1 ! IPTU = 3 !1 = g/s2 = kg/hr3 = lb/hr4 = tons/yr5 = Odour Unit * m**3/s (vol. flux of odour compound)6 = Odour Unit * m**3/min7 = metric tons/yrNumber of source-speciescombinations with variableemissions scaling factorsprovided below in (13d) (NSPT1) Default: 0 ! NSPT1 = 0 !Number of point sources withvariable emission parametersprovided in external file (NPT2) No default ! NPT2 = 0 !(If NPT2 > 0, these pointsource emissions are read fromthe file: PTEMARB.DAT)!END!---------------Subgroup (13b)---------------aPOINT SOURCE: CONSTANT DATA-----------------------------b cSource X Y Stack Base Stack Exit Exit Bldg. EmissionNo. Coordinate Coordinate Height Elevation Diameter Vel. Temp. Dwash Rates(km) (km) (m) (m) (m) (m/s) (deg. K)------ ---------- ---------- ------ ------ -------- ----- -------- ----- --------1 ! SRCNAM = NE3 ! Northeastern Unit 3Page 282001_NE_NOx.inp1 ! 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 42 ! 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 !--------aData for each source are treated as a separate input subgroupand 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 representthe effect of rain-caps or other physical configurations thatreduce momentum rise associated with the actual exit velocity.(Default: 1.0 -- full momentum used)b0. = No building downwash modeled, 1. = downwash modeledNOTE: must be entered as a REAL number (i.e., with decimal point)cAn emission rate must be entered for every pollutant modeled.Enter emission rate of zero for secondary pollutants that aremodeled, 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 aNo. Effective building height, width, length and X/Y offset (in meters)every 10 degrees. LENGTH, XBADJ, and YBADJ are only needed forMBDW=2 (PRIME downwash option)------ --------------------------------------------------------------------Page 292001_NE_NOx.inp--------aBuilding height, width, length, and X/Y offset from the source are treatedas a separate input subgroup for each source and therefore must end withan input group terminator. The X/Y offset is the position, relative to thestack, of the center of the upwind face of the projected building, with thex-axis pointing along the flow direction.---------------Subgroup (13d)---------------aPOINT SOURCE: VARIABLE EMISSIONS DATA---------------------------------------Use this subgroup to describe temporal variations in the emissionrates given in 13b. Factors entered multiply the rates in 13b.Skip sources here that have constant emissions. For more elaboratevariation in source parameters, use PTEMARB.DAT and NPT2 > 0.IVARY determines the type of variation, and is source-specific:(IVARY) Default: 00 = Constant1 = 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, wherefirst group is Stability Class A,and the speed classes have upperbounds (m/s) defined in Group 125 = Temperature (12 scaling factors, where temperatureclasses have upper bounds (C) of:0, 5, 10, 15, 20, 25, 30, 35, 40,45, 50, 50+)--------aData for each species are treated as a separate input subgroupand therefore must end with an input group terminator.-------------------------------------------------------------------------------Page 302001_NE_NOx.inpINPUT GROUPS: 14a, 14b, 14c, 14d -- Area source parameters-----------------------------------------------Subgroup (14a)---------------Number of polygon area sources withparameters specified below (NAR1) No default ! NAR1 = 0 !Units used for area sourceemissions below (IARU) Default: 1 ! IARU = 1 !1 = g/m**2/s2 = kg/m**2/hr3 = lb/m**2/hr4 = tons/m**2/yr5 = Odour Unit * m/s (vol. flux/m**2 of odour compound)6 = Odour Unit * m/min7 = metric tons/m**2/yrNumber of source-speciescombinations with variableemissions scaling factorsprovided below in (14d) (NSAR1) Default: 0 ! NSAR1 = 0 !Number of buoyant polygon area sourceswith variable location and emissionparameters (NAR2) No default ! NAR2 = 0 !(If NAR2 > 0, ALL parameter data forthese sources are read from the file: BAEMARB.DAT)!END!---------------Subgroup (14b)---------------aAREA SOURCE: CONSTANT DATA----------------------------bSource Effect. Base Initial EmissionNo. Height Elevation Sigma z Rates(m) (m) (m)------- ------ ------ -------- -----------------Page 312001_NE_NOx.inpaData for each source are treated as a separate input subgroupand therefore must end with an input group terminator.bAn emission rate must be entered for every pollutant modeled.Enter emission rate of zero for secondary pollutants that aremodeled, 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 aNo. Ordered list of X followed by list of Y, grouped by source------ --------------------------------------------------------------------aData for each source are treated as a separate input subgroupand therefore must end with an input group terminator.---------------Subgroup (14d)---------------aAREA SOURCE: VARIABLE EMISSIONS DATA--------------------------------------Use this subgroup to describe temporal variations in the emissionrates given in 14b. Factors entered multiply the rates in 14b.Skip sources here that have constant emissions. For more elaboratevariation in source parameters, use BAEMARB.DAT and NAR2 > 0.IVARY determines the type of variation, and is source-specific:(IVARY) Default: 00 = Constant1 = 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, wherefirst group is Stability Class A,and the speed classes have upperPage 322001_NE_NOx.inpbounds (m/s) defined in Group 125 = Temperature (12 scaling factors, where temperatureclasses have upper bounds (C) of:0, 5, 10, 15, 20, 25, 30, 35, 40,45, 50, 50+)--------aData for each species are treated as a separate input subgroupand therefore must end with an input group terminator.-------------------------------------------------------------------------------INPUT GROUPS: 15a, 15b, 15c -- Line source parameters------------------------------------------Subgroup (15a)---------------Number of buoyant line sourceswith variable location and emissionparameters (NLN2) No default ! NLN2 = 0 !(If NLN2 > 0, ALL parameter data forthese sources are read from the file: LNEMARB.DAT)Number of buoyant line sources (NLINES) No default ! NLINES = 0 !Units used for line sourceemissions below (ILNU) Default: 1 ! ILNU = 3 !1 = g/s2 = kg/hr3 = lb/hr4 = tons/yr5 = Odour Unit * m**3/s (vol. flux of odour compound)6 = Odour Unit * m**3/min7 = metric tons/yrNumber of source-speciescombinations with variableemissions scaling factorsprovided below in (15c) (NSLN1) Default: 0 ! NSLN1 = 0 !Maximum number of segments used to modelPage 332001_NE_NOx.inpeach line (MXNSEG) Default: 7 ! MXNSEG = 7 !The following variables are required only if NLINES > 0. They areused in the buoyant line source plume rise calculations.Number of distances at which Default: 6 ! NLRISE = 6 !transitional rise is computedAverage 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 EmissionNo. Coordinate Coordinate Coordinate Coordinate Height Elevation Rates(km) (km) (km) (km) (m) (m)------ ---------- ---------- --------- ---------- ------- --------- -----------------aData for each source are treated as a separate input subgroupand therefore must end with an input group terminator.bAn emission rate must be entered for every pollutant modeled.Page 342001_NE_NOx.inpEnter emission rate of zero for secondary pollutants that aremodeled, but not emitted. Units are specified by ILNTU(e.g. 1 for g/s).---------------Subgroup (15c)---------------aBUOYANT LINE SOURCE: VARIABLE EMISSIONS DATA----------------------------------------------Use this subgroup to describe temporal variations in the emissionrates 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: 00 = Constant1 = 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, wherefirst group is Stability Class A,and the speed classes have upperbounds (m/s) defined in Group 125 = Temperature (12 scaling factors, where temperatureclasses have upper bounds (C) of:0, 5, 10, 15, 20, 25, 30, 35, 40,45, 50, 50+)--------aData for each species are treated as a separate input subgroupand therefore must end with an input group terminator.-------------------------------------------------------------------------------INPUT GROUPS: 16a, 16b, 16c -- Volume source parameters------------------------------------------Subgroup (16a)---------------Page 352001_NE_NOx.inpNumber of volume sources withparameters provided in 16b,c (NVL1) No default ! NVL1 = 0 !Units used for volume sourceemissions below in 16b (IVLU) Default: 1 ! IVLU = 3 !1 = g/s2 = kg/hr3 = lb/hr4 = tons/yr5 = Odour Unit * m**3/s (vol. flux of odour compound)6 = Odour Unit * m**3/min7 = metric tons/yrNumber of source-speciescombinations with variableemissions scaling factorsprovided below in (16c) (NSVL1) Default: 0 ! NSVL1 = 0 !Number of volume sources withvariable location and emissionparameters (NVL2) No default ! NVL2 = 0 !(If NVL2 > 0, ALL parameter data forthese sources are read from the VOLEMARB.DAT file(s) )!END!---------------Subgroup (16b)---------------aVOLUME SOURCE: CONSTANT DATA------------------------------bX Y Effect. Base Initial Initial EmissionCoordinate Coordinate Height Elevation Sigma y Sigma z Rates(km) (km) (m) (m) (m) (m)---------- ---------- ------ ------ -------- -------- ----------------aData for each source are treated as a separate input subgroupand therefore must end with an input group terminator.bAn emission rate must be entered for every pollutant modeled.Page 362001_NE_NOx.inpEnter emission rate of zero for secondary pollutants that aremodeled, but not emitted. Units are specified by IVLU(e.g. 1 for g/s).---------------Subgroup (16c)---------------aVOLUME SOURCE: VARIABLE EMISSIONS DATA----------------------------------------Use this subgroup to describe temporal variations in the emissionrates given in 16b. Factors entered multiply the rates in 16b.Skip sources here that have constant emissions. For more elaboratevariation in source parameters, use VOLEMARB.DAT and NVL2 > 0.IVARY determines the type of variation, and is source-specific:(IVARY) Default: 00 = Constant1 = 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, wherefirst group is Stability Class A,and the speed classes have upperbounds (m/s) defined in Group 125 = Temperature (12 scaling factors, where temperatureclasses have upper bounds (C) of:0, 5, 10, 15, 20, 25, 30, 35, 40,45, 50, 50+)--------aData for each species are treated as a separate input subgroupand therefore must end with an input group terminator.-------------------------------------------------------------------------------INPUT GROUPS: 17a & 17b -- Non-gridded (discrete) receptor information--------------------------------------Subgroup (17a)---------------Page 372001_NE_NOx.inpNumber of non-gridded receptors (NREC) No default ! NREC = 291 !!END!---------------Subgroup (17b)---------------aNON-GRIDDED (DISCRETE) RECEPTOR DATA------------------------------------X Y Ground Height bReceptor Coordinate Coordinate Elevation Above GroundNo. (km) (km) (m) (m)-------- ---------- ---------- --------- ------------1 ! X = 359.836, -362.005, 274, 0 ! !END! HG12 ! X = 360.575, -361.972, 299, 0 ! !END! HG23 ! X = 361.314, -361.939, 328, 0 ! !END! HG34 ! X = 362.053, -361.906, 365, 0 ! !END! HG45 ! X = 358.316, -361.150, 250, 0 ! !END! HG56 ! X = 359.055, -361.117, 278, 0 ! !END! HG67 ! X = 359.794, -361.084, 335, 0 ! !END! HG78 ! X = 360.533, -361.051, 307, 0 ! !END! HG89 ! X = 361.272, -361.018, 345, 0 ! !END! HG910 ! X = 357.537, -360.261, 261, 0 ! !END! HG1011 ! X = 358.275, -360.228, 271, 0 ! !END! HG1112 ! X = 359.014, -360.195, 274, 0 ! !END! HG1213 ! X = 359.753, -360.162, 331, 0 ! !END! HG1314 ! X = 360.492, -360.129, 327, 0 ! !END! HG1415 ! X = 361.231, -360.096, 304, 0 ! !END! HG1516 ! X = 361.970, -360.063, 335, 0 ! !END! HG1617 ! X = 362.709, -360.030, 312, 0 ! !END! HG1718 ! X = 363.448, -359.997, 340, 0 ! !END! HG1819 ! X = 364.187, -359.963, 361, 0 ! !END! HG1920 ! X = 364.926, -359.930, 382, 0 ! !END! HG2021 ! X = 357.496, -359.340, 274, 0 ! !END! HG2122 ! X = 358.235, -359.307, 274, 0 ! !END! HG2223 ! X = 358.973, -359.274, 335, 0 ! !END! HG2324 ! X = 359.712, -359.241, 294, 0 ! !END! HG2425 ! X = 360.451, -359.208, 304, 0 ! !END! HG2526 ! X = 361.190, -359.175, 279, 0 ! !END! HG2627 ! X = 361.929, -359.142, 304, 0 ! !END! HG2728 ! X = 362.668, -359.109, 318, 0 ! !END! HG2829 ! X = 363.406, -359.075, 335, 0 ! !END! HG2930 ! X = 364.145, -359.042, 347, 0 ! !END! HG3031 ! X = 364.884, -359.008, 340, 0 ! !END! HG3132 ! X = 358.932, -358.353, 247, 0 ! !END! HG32Page 382001_NE_NOx.inp33 ! X = 359.671, -358.320, 271, 0 ! !END! HG3334 ! X = 360.410, -358.287, 275, 0 ! !END! HG3435 ! X = 361.149, -358.254, 274, 0 ! !END! HG3536 ! X = 361.887, -358.220, 277, 0 ! !END! HG3637 ! X = 362.626, -358.187, 304, 0 ! !END! HG3738 ! X = 363.365, -358.154, 330, 0 ! !END! HG3839 ! X = 364.104, -358.121, 357, 0 ! !END! HG3940 ! X = 364.842, -358.087, 384, 0 ! !END! HG4041 ! X = 365.581, -358.054, 372, 0 ! !END! HG4142 ! X = 356.675, -357.530, 274, 0 ! !END! HG4243 ! X = 357.414, -357.497, 293, 0 ! !END! HG4344 ! X = 358.153, -357.464, 272, 0 ! !END! HG4445 ! X = 358.891, -357.431, 271, 0 ! !END! HG4546 ! X = 359.630, -357.398, 274, 0 ! !END! HG4647 ! X = 360.369, -357.365, 327, 0 ! !END! HG4748 ! X = 361.107, -357.332, 316, 0 ! !END! HG4849 ! X = 361.846, -357.299, 304, 0 ! !END! HG4950 ! X = 362.585, -357.266, 354, 0 ! !END! HG5051 ! X = 363.323, -357.233, 346, 0 ! !END! HG5152 ! X = 364.062, -357.199, 335, 0 ! !END! HG5253 ! X = 364.801, -357.166, 344, 0 ! !END! HG5354 ! X = 365.539, -357.132, 364, 0 ! !END! HG5455 ! X = 357.373, -356.576, 243, 0 ! !END! HG5556 ! X = 358.112, -356.543, 335, 0 ! !END! HG5657 ! X = 358.850, -356.510, 324, 0 ! !END! HG5758 ! X = 359.589, -356.477, 335, 0 ! !END! HG5859 ! X = 360.327, -356.444, 341, 0 ! !END! HG5960 ! X = 361.066, -356.411, 333, 0 ! !END! HG6061 ! X = 361.805, -356.378, 306, 0 ! !END! HG6162 ! X = 362.543, -356.345, 304, 0 ! !END! HG6263 ! X = 363.282, -356.311, 365, 0 ! !END! HG6364 ! X = 364.020, -356.278, 304, 0 ! !END! HG6465 ! X = 364.759, -356.245, 309, 0 ! !END! HG6566 ! X = 365.497, -356.211, 307, 0 ! !END! HG6667 ! X = 357.332, -355.654, 270, 0 ! !END! HG6768 ! X = 358.071, -355.622, 274, 0 ! !END! HG6869 ! X = 358.809, -355.589, 301, 0 ! !END! HG6970 ! X = 359.548, -355.556, 274, 0 ! !END! HG7071 ! X = 360.286, -355.523, 274, 0 ! !END! HG7172 ! X = 361.025, -355.490, 312, 0 ! !END! HG7273 ! X = 361.763, -355.457, 274, 0 ! !END! HG7374 ! X = 362.502, -355.423, 322, 0 ! !END! HG7475 ! X = 363.240, -355.390, 304, 0 ! !END! HG7576 ! X = 363.979, -355.357, 275, 0 ! !END! HG7677 ! X = 364.717, -355.323, 304, 0 ! !END! HG7778 ! X = 365.456, -355.290, 290, 0 ! !END! HG7879 ! X = 362.460, -354.502, 249, 0 ! !END! HG7980 ! X = 363.199, -354.469, 274, 0 ! !END! HG80Page 392001_NE_NOx.inp81 ! X = -159.867, -584.484, 454, 0 ! !END! WM182 ! X = -159.108, -584.499, 486, 0 ! !END! WM283 ! X = -158.348, -584.513, 487, 0 ! !END! WM384 ! X = -157.589, -584.528, 478, 0 ! !END! WM485 ! X = -156.829, -584.542, 518, 0 ! !END! WM586 ! X = -156.070, -584.557, 518, 0 ! !END! WM687 ! X = -161.368, -583.531, 510, 0 ! !END! WM788 ! X = -160.609, -583.546, 493, 0 ! !END! WM889 ! X = -159.849, -583.560, 488, 0 ! !END! WM990 ! X = -159.090, -583.575, 615, 0 ! !END! WM1091 ! X = -158.331, -583.589, 522, 0 ! !END! WM1192 ! X = -157.571, -583.604, 494, 0 ! !END! WM1293 ! X = -156.812, -583.618, 609, 0 ! !END! WM1394 ! X = -156.052, -583.633, 518, 0 ! !END! WM1495 ! X = -162.110, -582.592, 487, 0 ! !END! WM1596 ! X = -161.350, -582.607, 518, 0 ! !END! WM1697 ! X = -160.591, -582.622, 609, 0 ! !END! WM1798 ! X = -159.832, -582.636, 554, 0 ! !END! WM1899 ! X = -159.072, -582.651, 578, 0 ! !END! WM19100 ! X = -158.313, -582.666, 557, 0 ! !END! WM20101 ! X = -157.554, -582.680, 571, 0 ! !END! WM21102 ! X = -156.794, -582.694, 670, 0 ! !END! WM22103 ! X = -156.035, -582.709, 518, 0 ! !END! WM23104 ! X = -160.573, -581.698, 518, 0 ! !END! WM24105 ! X = -159.814, -581.712, 548, 0 ! !END! WM25106 ! X = -159.054, -581.727, 548, 0 ! !END! WM26107 ! X = -158.295, -581.742, 518, 0 ! !END! WM27108 ! X = -160.555, -580.774, 517, 0 ! !END! WM28109 ! X = -159.796, -580.789, 579, 0 ! !END! WM29110 ! X = -159.037, -580.803, 613, 0 ! !END! WM30111 ! X = -158.278, -580.818, 548, 0 ! !END! WM31112 ! X = -157.518, -580.832, 523, 0 ! !END! WM32113 ! X = -161.296, -579.835, 542, 0 ! !END! WM33114 ! X = -160.537, -579.850, 545, 0 ! !END! WM34115 ! X = -159.778, -579.865, 552, 0 ! !END! WM35116 ! X = -152.895, -577.222, 579, 0 ! !END! WM36117 ! X = -155.913, -576.242, 609, 0 ! !END! WM37118 ! X = -155.154, -576.256, 654, 0 ! !END! WM38119 ! X = -154.396, -576.270, 621, 0 ! !END! WM39120 ! X = -153.637, -576.284, 629, 0 ! !END! WM40121 ! X = -152.878, -576.298, 579, 0 ! !END! WM41122 ! X = -152.119, -576.312, 560, 0 ! !END! WM42123 ! X = -156.654, -575.304, 615, 0 ! !END! WM43124 ! X = -155.896, -575.318, 641, 0 ! !END! WM44125 ! X = -155.137, -575.332, 640, 0 ! !END! WM45126 ! X = -154.378, -575.346, 662, 0 ! !END! WM46127 ! X = -153.620, -575.361, 618, 0 ! !END! WM47128 ! X = -152.861, -575.375, 630, 0 ! !END! WM48Page 402001_NE_NOx.inp129 ! X = -152.102, -575.389, 534, 0 ! !END! WM49130 ! X = -156.637, -574.380, 606, 0 ! !END! WM50131 ! X = -155.878, -574.394, 566, 0 ! !END! WM51132 ! X = -155.120, -574.408, 633, 0 ! !END! WM52133 ! X = -154.361, -574.423, 670, 0 ! !END! WM53134 ! X = -153.603, -574.437, 609, 0 ! !END! WM54135 ! X = -152.844, -574.451, 579, 0 ! !END! WM55136 ! X = -152.085, -574.465, 535, 0 ! !END! WM56137 ! X = -155.102, -573.485, 548, 0 ! !END! WM57138 ! X = -154.344, -573.499, 518, 0 ! !END! WM58139 ! X = -153.585, -573.513, 506, 0 ! !END! WM59140 ! X = 318.344, -456.077, 555, 0 ! !END! UB1141 ! X = 319.091, -456.047, 589, 0 ! !END! UB2142 ! X = 321.334, -455.959, 563, 0 ! !END! UB3143 ! X = 318.308, -455.154, 549, 0 ! !END! UB4144 ! X = 319.055, -455.125, 487, 0 ! !END! UB5145 ! X = 319.803, -455.096, 487, 0 ! !END! UB6146 ! X = 320.551, -455.067, 490, 0 ! !END! UB7147 ! X = 318.272, -454.232, 650, 0 ! !END! UB8148 ! X = 319.019, -454.203, 563, 0 ! !END! UB9149 ! X = 319.767, -454.174, 540, 0 ! !END! UB10150 ! X = 320.514, -454.144, 502, 0 ! !END! UB11151 ! X = 321.262, -454.115, 526, 0 ! !END! UB12152 ! X = 322.757, -454.056, 534, 0 ! !END! UB13153 ! X = 323.504, -454.026, 563, 0 ! !END! UB14154 ! X = 318.236, -453.310, 548, 0 ! !END! UB15155 ! X = 318.983, -453.281, 628, 0 ! !END! UB16156 ! X = 319.731, -453.252, 623, 0 ! !END! UB17157 ! X = 320.478, -453.222, 579, 0 ! !END! UB18158 ! X = 321.225, -453.193, 469, 0 ! !END! UB19159 ! X = 321.973, -453.163, 457, 0 ! !END! UB20160 ! X = 322.720, -453.134, 573, 0 ! !END! UB21161 ! X = 323.468, -453.104, 605, 0 ! !END! UB22162 ! X = 324.215, -453.074, 588, 0 ! !END! UB23163 ! X = 318.200, -452.388, 608, 0 ! !END! UB24164 ! X = 318.947, -452.359, 660, 0 ! !END! UB25165 ! X = 319.694, -452.329, 598, 0 ! !END! UB26166 ! X = 320.442, -452.300, 599, 0 ! !END! UB27167 ! X = 321.189, -452.271, 639, 0 ! !END! UB28168 ! X = 321.937, -452.241, 457, 0 ! !END! UB29169 ! X = 322.684, -452.212, 568, 0 ! !END! UB30170 ! X = 318.164, -451.466, 730, 0 ! !END! UB31171 ! X = 318.911, -451.437, 681, 0 ! !END! UB32172 ! X = 319.658, -451.407, 640, 0 ! !END! UB33173 ! X = 320.406, -451.378, 625, 0 ! !END! UB34174 ! X = 321.153, -451.348, 426, 0 ! !END! UB35175 ! X = 321.900, -451.319, 555, 0 ! !END! UB36176 ! X = 322.647, -451.289, 612, 0 ! !END! UB37Page 412001_NE_NOx.inp177 ! X = 317.380, -450.573, 667, 0 ! !END! UB38178 ! X = 318.128, -450.544, 580, 0 ! !END! UB39179 ! X = 318.875, -450.514, 656, 0 ! !END! UB40180 ! X = 319.622, -450.485, 640, 0 ! !END! UB41181 ! X = 320.369, -450.456, 487, 0 ! !END! UB42182 ! X = 321.116, -450.426, 457, 0 ! !END! UB43183 ! X = 321.864, -450.397, 654, 0 ! !END! UB44184 ! X = 322.611, -450.367, 548, 0 ! !END! UB45185 ! X = 323.358, -450.338, 622, 0 ! !END! UB46186 ! X = 324.105, -450.308, 683, 0 ! !END! UB47187 ! X = 317.345, -449.651, 579, 0 ! !END! UB48188 ! X = 318.092, -449.621, 554, 0 ! !END! UB49189 ! X = 318.839, -449.592, 609, 0 ! !END! UB50190 ! X = 319.586, -449.563, 622, 0 ! !END! UB51191 ! X = 320.333, -449.534, 427, 0 ! !END! UB52192 ! X = 321.080, -449.504, 555, 0 ! !END! UB53193 ! X = 321.827, -449.475, 502, 0 ! !END! UB54194 ! X = 322.574, -449.445, 639, 0 ! !END! UB55195 ! X = 323.322, -449.416, 580, 0 ! !END! UB56196 ! X = 324.069, -449.386, 639, 0 ! !END! UB57197 ! X = 318.803, -448.670, 548, 0 ! !END! UB58198 ! X = 319.550, -448.641, 548, 0 ! !END! UB59199 ! X = 320.297, -448.612, 438, 0 ! !END! UB60200 ! X = 321.044, -448.582, 579, 0 ! !END! UB61201 ! X = 322.538, -448.523, 620, 0 ! !END! UB62202 ! X = 320.261, -447.689, 579, 0 ! !END! UB63203 ! X = 321.007, -447.660, 426, 0 ! !END! UB64204 ! X = 321.754, -447.631, 611, 0 ! !END! UB65205 ! X = 318.731, -446.826, 604, 0 ! !END! UB66206 ! X = 319.477, -446.797, 548, 0 ! !END! UB67207 ! X = 320.224, -446.767, 488, 0 ! !END! UB68208 ! X = 320.971, -446.738, 402, 0 ! !END! UB69209 ! X = 321.718, -446.708, 579, 0 ! !END! UB70210 ! X = 322.465, -446.679, 573, 0 ! !END! UB71211 ! X = 323.212, -446.649, 609, 0 ! !END! UB72212 ! X = 269.710, -618.629, 365, 0 ! !END! CC1213 ! X = 270.473, -618.605, 365, 0 ! !END! CC2214 ! X = 271.235, -618.580, 368, 0 ! !END! CC3215 ! X = 268.155, -617.755, 411, 0 ! !END! CC4216 ! X = 268.917, -617.730, 462, 0 ! !END! CC5217 ! X = 269.680, -617.705, 431, 0 ! !END! CC6218 ! X = 270.443, -617.681, 518, 0 ! !END! CC7219 ! X = 271.205, -617.656, 487, 0 ! !END! CC8220 ! X = 271.968, -617.631, 396, 0 ! !END! CC9221 ! X = 265.075, -616.929, 518, 0 ! !END! CC10222 ! X = 265.838, -616.904, 523, 0 ! !END! CC11223 ! X = 266.600, -616.880, 548, 0 ! !END! CC12224 ! X = 267.363, -616.855, 579, 0 ! !END! CC13Page 422001_NE_NOx.inp225 ! X = 268.125, -616.831, 547, 0 ! !END! CC14226 ! X = 268.888, -616.806, 538, 0 ! !END! CC15227 ! X = 269.650, -616.781, 640, 0 ! !END! CC16228 ! X = 270.412, -616.757, 608, 0 ! !END! CC17229 ! X = 259.709, -616.173, 335, 0 ! !END! CC18230 ! X = 260.472, -616.149, 431, 0 ! !END! CC19231 ! X = 261.234, -616.125, 457, 0 ! !END! CC20232 ! X = 261.996, -616.101, 414, 0 ! !END! CC21233 ! X = 262.759, -616.077, 426, 0 ! !END! CC22234 ! X = 263.521, -616.053, 426, 0 ! !END! CC23235 ! X = 264.283, -616.029, 388, 0 ! !END! CC24236 ! X = 265.046, -616.005, 388, 0 ! !END! CC25237 ! X = 265.808, -615.980, 365, 0 ! !END! CC26238 ! X = 266.571, -615.956, 386, 0 ! !END! CC27239 ! X = 267.333, -615.931, 396, 0 ! !END! CC28240 ! X = 268.095, -615.907, 426, 0 ! !END! CC29241 ! X = 268.858, -615.882, 446, 0 ! !END! CC30242 ! X = 269.620, -615.857, 441, 0 ! !END! CC31243 ! X = 270.382, -615.833, 457, 0 ! !END! CC32244 ! X = 271.145, -615.808, 465, 0 ! !END! CC33245 ! X = 271.907, -615.783, 442, 0 ! !END! CC34246 ! X = 272.670, -615.758, 426, 0 ! !END! CC35247 ! X = 259.680, -615.249, 304, 0 ! !END! CC36248 ! X = 260.443, -615.225, 304, 0 ! !END! CC37249 ! X = 261.205, -615.201, 319, 0 ! !END! CC38250 ! X = 261.967, -615.177, 334, 0 ! !END! CC39251 ! X = 262.730, -615.153, 370, 0 ! !END! CC40252 ! X = 263.492, -615.129, 405, 0 ! !END! CC41253 ! X = 264.254, -615.105, 409, 0 ! !END! CC42254 ! X = 265.016, -615.081, 450, 0 ! !END! CC43255 ! X = 265.779, -615.056, 518, 0 ! !END! CC44256 ! X = 266.541, -615.032, 609, 0 ! !END! CC45257 ! X = 267.303, -615.007, 534, 0 ! !END! CC46258 ! X = 268.066, -614.983, 517, 0 ! !END! CC47259 ! X = 268.828, -614.958, 575, 0 ! !END! CC48260 ! X = 269.590, -614.933, 600, 0 ! !END! CC49261 ! X = 270.352, -614.909, 609, 0 ! !END! CC50262 ! X = 271.115, -614.884, 609, 0 ! !END! CC51263 ! X = 271.877, -614.859, 561, 0 ! !END! CC52264 ! X = 260.414, -614.301, 335, 0 ! !END! CC53265 ! X = 261.176, -614.277, 432, 0 ! !END! CC54266 ! X = 261.938, -614.253, 487, 0 ! !END! CC55267 ! X = 262.700, -614.229, 499, 0 ! !END! CC56268 ! X = 263.463, -614.205, 514, 0 ! !END! CC57269 ! X = 264.225, -614.181, 442, 0 ! !END! CC58270 ! X = 264.987, -614.157, 439, 0 ! !END! CC59271 ! X = 265.749, -614.132, 395, 0 ! !END! CC60272 ! X = 266.511, -614.108, 400, 0 ! !END! CC61Page 432001_NE_NOx.inp273 ! X = 267.274, -614.083, 426, 0 ! !END! CC62274 ! X = 268.036, -614.059, 487, 0 ! !END! CC63275 ! X = 268.798, -614.034, 548, 0 ! !END! CC64276 ! X = 269.560, -614.010, 548, 0 ! !END! CC65277 ! X = 270.322, -613.985, 548, 0 ! !END! CC66278 ! X = 271.085, -613.960, 535, 0 ! !END! CC67279 ! X = 261.147, -613.353, 304, 0 ! !END! CC68280 ! X = 261.909, -613.329, 334, 0 ! !END! CC69281 ! X = 262.671, -613.305, 396, 0 ! !END! CC70282 ! X = 263.433, -613.281, 457, 0 ! !END! CC71283 ! X = 264.195, -613.257, 457, 0 ! !END! CC72284 ! X = 264.958, -613.233, 426, 0 ! !END! CC73285 ! X = 265.720, -613.208, 411, 0 ! !END! CC74286 ! X = 266.482, -613.184, 406, 0 ! !END! CC75287 ! X = 267.244, -613.159, 396, 0 ! !END! CC76288 ! X = 268.006, -613.135, 401, 0 ! !END! CC77289 ! X = 268.768, -613.110, 397, 0 ! !END! CC78290 ! X = 261.118, -612.429, 322, 0 ! !END! CC79291 ! X = 261.880, -612.405, 334, 0 ! !END! CC80-------------aData for each receptor are treated as a separate input subgroupand therefore must end with an input group terminator.bReceptor height above ground is optional. If no value is entered,the receptor is placed on the ground.Page 44

### American Electric Power D-1 Trinity Consultants Northeastern Power Station 083701.0024 

## A PPENDIX 

## D

– S AMPLE 

## CALPOST C ONTROL 

## F ILE01_CC_vis.INPAEP 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 ifproviding NON-BLANK character string)User Character String (U) to augment default filenames(activate with exclamation points only ifproviding NON-BLANK character string)Timeseries TSttUUUU.DAT * TSUNAM = *Top Nth Rank Plot RttUUUUU.DATor RttiiUUU.GRD * TUNAM = *Page 101_CC_vis.INPExceedance Plot XttUUUUU.DATor 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 CASET = 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 constructedusing a template that includes a pathname, user-suppliedcharacter(s), and fixed strings (tt,ii,jjj, and hh), wherett = Averaging Period (e.g. 03)ii = Rank (e.g. 02)jjj= Julian Dayhh = Hour(ending)are determined internally based on selections made below.If a path or user-supplied character(s) are supplied, eachmust contain at least 1 non-blank character.!END!--------------------------------------------------------------------------------INPUT GROUP: 1 -- General run control parameters--------------Option to run all periods foundin the met. file(s) (METRUN) Default: 0 ! METRUN = 0 !METRUN = 0 - Run period explicitly defined belowMETRUN = 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,Page 201_CC_vis.INP5 = 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 = 0.0Add 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;ORSelect SPECIFIC DISCRETE receptors by entering a flag (0,1) for each0 = discrete receptor not processed1 = discrete receptor processedusing repeated value notation to select blocks of receptors:416*0, 1048*1, 1482*0Flag 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):Page 301_CC_vis.INPX 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 CALPOSTprocessing by filling a processing grid array with 0s and 1s. If theprocessing flag for receptor index (i,j) is 1 (ON), that receptorwill 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 beprocessed in the run. By default, all array values are set to 1 (ON).Number of gridded receptor rows provided in Subgroup (1a) toidentify 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 processingby filling a processing grid array with 0s and 1s. A total ofNGONOFF lines are read here. Each line corresponds to one 'row'in the sampling grid, starting with the NORTHERNMOST row thatcontains receptors that you wish to exclude, and finishing withrow 1 to the SOUTH (no intervening rows may be skipped). Withina row, each receptor position is assigned either a 0 or 1,starting with the westernmost receptor.0 = gridded receptor not processed1 = gridded receptor processedRepeated value notation may be used to select blocks of receptors:23*1, 15*0, 12*1Because all values are initially set to 1, any receptors north ofPage 401_CC_vis.INPthe 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 extinctionInclude 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 fileCOARSE (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 !Page 501_CC_vis.INP1 = Supply single light extinction and hygroscopic fraction- IWAQM (1993) RH adjustment applied to hygroscopic backgroundand modeled sulfate and nitrate2 = Compute extinction from speciated PM measurements (A)- Hourly RH adjustment applied to observed and modeled sulfateand nitrate- RH factor is capped at RHMAX3 = Compute extinction from speciated PM measurements (B)- Hourly RH adjustment applied to observed and modeled sulfateand nitrate- Receptor-hour excluded if RH>RHMAX- Receptor-day excluded if fewer than 6 valid receptor-hours4 = 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-hours5 = 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-hours6 = Compute extinction from speciated PM measurements- FLAG RH adjustment factor applied to observed andmodeled sulfate and nitrateAdditional 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 andbackground) are computed using a monthly RH adjustment factorin 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:----------------------------------------Page 601_CC_vis.INPBackground extinction coefficients are computed from monthlyCONCENTRATIONS of ammonium sulfate (BKSO4), ammonium nitrate (BKNO3),coarse particulates (BKPMC), organic carbon (BKOC), soil (BKSOIL), andelemental 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 theCALPUFF 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 forPage 701_CC_vis.INPConcentration Deposition1 = g/m**3 g/m**2/s2 = mg/m**3 mg/m**2/s3 = ug/m**3 ug/m**2/s4 = ng/m**3 ng/m**2/s5 = Odour UnitsVisibility: 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 foran averaging time of NAVG hours are reported forNAVG greater than 0:(NAVG) -- Default: 0 ! NAVG = 0 !Types of tabulations reported------------------------------1) Visibility: daily visibility tabulations are always reportedfor the selected receptors when ASPEC = VISIB.In addition, any of the other tabulations listedbelow may be chosen to characterize the lightextinction 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 receptorselected (NTOP must be <= 4)Page 801_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 !1,2,3,44) Threshold exceedance counts for each receptor and each averagingtime selected[List file or Plot file](LEXCD) -- Default: F ! LEXCD = F !-- Identify the threshold for each averaging time by assigning anon-negative value (output units).-- Default: -1.0Threshold 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 betallied daily, and receptors that experience more than NCOUNTcounts over any NDAY period will be reported. This type ofexceedance 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 periodselected and output is grouped by day[List file or Plot file](LECHO) -- Default: F ! LECHO = F !Timeseries Option -- Averages at all selected receptors foreach selected averaging period are written to timeseries files.Each file contains one averaging period, and all receptors arewritten to a single record each averaging time.[TSttUUUU.DAT files](LTIME) -- Default: F ! LTIME = F !Page 901_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 Echotables selected above. Two formats for these files are available,DATA and GRID. In the DATA format, results at all receptors arelisted 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 inrows (x varies), starting with the most southern row of the grid.The GRID format is given the .GRD extension, and includes headerscompatible with the SURFER(R) plotting software.A plotting and analysis file can also be created for the dailypeak visibility summary output, in DATA format only.Generate Plot file output in addition to writing tablesto 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 filefor debugging?(LDEBUG) -- Default: F ! LDEBUG = F !!END!Page 10

### American Electric Power E-1 Trinity Consultants Northeastern Power Station 083701.0024 

## A PPENDIX 

## E

– C ONTROL 

## S CENARIO 

## E MISSION 

## E STIMATESPrinted: 5/27/2008Northeastern Power PlantBART Modeling Source ParametersStack ParametersStack parameters (English)Unit 3 Unit 4 Unit 3 Unit 4 Unit 3 Unit 4 Unit 3 Unit 4 Unit 3 Unit 4 Unit 3 Unit 4Heat Input (MMBtu/hr)15,812 5,594 5,812 5,594 5,812 5,594 5,812 5,594 5,812 5,594 5,812 5,594Exit Velocity (ft/sec) 62 57 62 57 62 57 62 57 51 48 49 46Stack Diameter (feet) 27 27 27 27 27 27 27 27 27 27 27 27Stack 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 1,652,486 1,674,247 1,573,545Stack Temp. (°F)2304 288 304 288 304 288 304 288 168 168 138 138Stack Temp. (°R) 764 748 764 748 764 748 764 748 628 628 598 598Stack Height (feet) 600 600 600 600 600 600 600 600 600 600 600 600Base Elevation (feet)3640 640 640 640 640 640 640 640 640 640 640 640Stack parameters (Metric)Heat Input (MMBtu/hr)15,812 5,594 5,812 5,594 5,812 5,594 5,812 5,594 5,812 5,594 5,812 5,594Exit Velocity (m/sec) 18.97 17.46 18.97 17.46 18.97 17.46 18.97 17.46 15.60 14.67 14.86 13.96Stack Diameter (meters) 8.23 8.23 8.23 8.23 8.23 8.23 8.23 8.23 8.23 8.23 8.23 8.23Stack Temp. (K) 424 415 424 415 424 415 424 415 349 349 332 332Stack Height (meters) 183 183 183 183 183 183 183 183 183 183 183 183Base Elevation (meters)3195 195 195 195 195 195 195 195 195 195 195 1951Maximum 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/WFGDBaseline Case LNB & OFA SNCR SCR DFGDAmerican Electric PowerNortheastern Power StationSource ParametersTrinity Consultants083701.0024Printed: 5/27/2008Northeastern Power PlantBART Emissions Modeling InputsNortheastern Unit 3PM102SO4(from PM)3PM (coarse)3PM (fine)3EC3SOA3lb/mmBtu lb/hr lb/mmBtu lb/hr ppm lb/mmBtu lb/hr lb/mmBtu lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hrCase 1 Baseline Case -- 0.536 3,115.5 0.900 5,231.2 3.0 0.011 66.3 0.038 220.3 147.6 127.2 34.1 26.2 1.0 31.8Case 2 SNCR 25% 0.402 2,336.6 0.900 5,231.2 3.0 0.011 66.3 0.038 220.3 147.6 127.2 34.1 26.2 1.0 31.8Case 3 LNB & OFA 72% 0.150 871.9 0.900 5,231.2 3.0 0.011 66.3 0.038 220.3 147.6 127.2 34.1 26.2 1.0 31.8Case 4 SCR 90% 0.054 311.5 0.900 5,231.2 3.0 0.011 66.3 0.038 220.3 147.6 127.2 34.1 26.2 1.0 31.8Case 5 DFGD 83% 0.536 3,115.5 0.150 871.9 3.0 0.002 11.0 0.038 220.3 147.6 127.2 34.1 26.2 1.0 31.8Case 6 WFGD 93% 0.536 3,115.5 0.063 366.2 3.0 0.001 4.6 0.038 220.3 147.6 127.2 34.1 26.2 1.0 31.8Case 7 ESP & FF 78% 0.536 3,115.5 0.900 5,231.2 3.0 0.011 66.3 0.009 49.4 33.1 28.5 7.6 5.9 0.2 7.1Northeastern Unit 4PM102SO4(from PM)3PM (coarse)3PM (fine)3EC3SOA3lb/mmBtu lb/hr lb/mmBtu lb/hr ppm lb/mmBtu lb/hr lb/mmBtu lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hrCase 1 Baseline Case -- 0.491 2,746.6 0.900 5,034.5 3.0 0.011 62.3 0.059 330.6 221.5 190.9 51.1 39.4 1.5 47.7Case 2 SNCR 25% 0.368 2,060.0 0.900 5,034.5 3.0 0.011 62.3 0.059 330.6 221.5 190.9 51.1 39.4 1.5 47.7Case 3 LNB & OFA 69% 0.150 839.1 0.900 5,034.5 3.0 0.011 62.3 0.059 330.6 221.5 190.9 51.1 39.4 1.5 47.7Case 4 SCR 90% 0.049 274.7 0.900 5,034.5 3.0 0.011 62.3 0.059 330.6 221.5 190.9 51.1 39.4 1.5 47.7Case 5 DFGD 83% 0.491 2,746.6 0.150 839.1 3.0 0.002 10.4 0.059 330.6 221.5 190.9 51.1 39.4 1.5 47.7Case 6 WFGD 93% 0.491 2,746.6 0.063 352.4 3.0 0.001 4.4 0.059 330.6 221.5 190.9 51.1 39.4 1.5 47.7Case 7 ESP & FF 87% 0.491 2,746.6 0.900 5,034.5 3.0 0.011 62.3 0.008 44.2 29.6 25.5 6.8 5.3 0.2 6.41 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 SO496 lb SO466.3 lbmin 764 Rankine hour 379.7 SCF lbmol S lbmol SO4hour2Represents 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.cfmCoarse 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 guidanceCPM OR 14.43% Organic condensible PM considered secondary organic aerosols per NPSPM10SpeciationPM10Speciation3 parts S1,000,000 parts coal=H2SO4(as SO4 from SO2)1H2SO4(as SO4 from SO2)1PercentReductionPercentReductionPMNOx SO2PMNOx SO2American Electric PowerNortheastern Power StationModel InputsTrinity Consultants083701.0024

### American Electric Power F-1 Trinity Consultants Northeastern Power Station 083701.0024 

## A PPENDIX 

## F

– C ONTROL 

## C OST 

## C ALCULATIONSPrinted: 5/27/2008



### BART Economic Analysis for SNCR (NO X 

### )

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
083701.0024Printed: 5/27/2008



### BART Economic Analysis for LNB & OFA (NO X 

### )

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
083701.0024Printed: 5/27/2008



### BART Economic Analysis for SCR (NO X 

### )

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
083701.0024Printed: 5/27/2008

BART Economic Analysis for DFGD (SO 2 )

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

SO 2 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 SO 2 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
083701.0024Printed: 5/27/2008

BART Economic Analysis for WFGD (SO 2 )

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

SO 2 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 SO 2 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 

## A PPENDIX 

## G

– CALPUFF S YSTEM 

## M ODEL 

## F ILES



## Control Scenario Description Model Run Number

NOx SO 2



### 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