Control Strategy Tool (CoST)
Cost Equations Documentation

Office of Air Quality Planning and Standards
U.S. Environmental Protection Agency
Research Triangle Park, NC 27711

Contacts: David Misenheimer, Larry Sorrels, Darryl Weatherhead

Last Updated
November 25, 2014


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Control Strategy Tool (CoST) Cost Equations

Contents

Tables	iii

Figures	iv

Document Revision History	1

1	Introduction	2

2	NOx Control Cost Equations	5

2.1	IPM Sector (ptipm) NOx Control Cost Equations	5

2.1.1	Equation Type 1 for N0X	5

2.1.2	Equation Type 1 Example for N0X	8

2.2	Non-IPM Sector (ptnonipm) NOx Control Cost Equations	10

2.2.1	Equation Type 2	10

2.2.2	Equation Type 2 Example	14

2.2.3	Non-IPM Sector (ptnonipm) NOx Control Cost per Ton Calculations	18

2.2.4	Non-IPM Sector (ptnonipm) N0X Control Cost per Ton Example	19

2.2.5	Equation Type 12 for N0X	21

2.2.6	Equation Type 12 Example for N0X	23

3	SO2 Control Cost Equations	26

3.1	IPM Sector (ptipm) S02 Control Cost Equations	26

3.1.1	Equation Type 1 for SO2	26

3.1.2	Equation Type 1 Example for SO2	29

3.2	Non-IPM Sector (ptnonipm) S02 Control Cost Equations	31

3.2.1	Equation Type 3	32

3.2.2	Equation Type 3 Example	36

3.2.3	Equation Type 4	38

3.2.4	Equation Type 4 Example	40

3.2.5	Equation Type 5	41

3.2.6	Equation Type 5 Example	42

3.2.7	Equation Type 6	44

3.2.8	Equation Type 6 Example	45

3.2.9	Equation Type 11	47

3.2.10	Equation Type 11 Example	48

3.2.11	ICI Boiler Control Equations Type 16 for SO2	50

3.2.12	ICI Boiler Control Equations Type 16 Example for SO2	54

3.2.13	ICI Boiler Control Equations Type 18 for SO2	55

3.2.14	ICI Boiler Control Equations Type 18 Example for SO2	56

3.2.15	ICI Boiler Control Equations Type 19 for SO2	57

3.2.16	ICI Boiler Control Equations Type 19 Example for SO2	58

4	PM Control Cost Equations	61

4.1 IPM Sector (ptipm) PM Control Cost Equations	61

4.1.1	Equation Type 8	61

4.1.2	Equation Type 8 Example for IPM Sector Sources	63

4.1.3	Equation Type 9	65

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Control Strategy Tool (CoST) Cost Equations

4.1.4	Equation Type 9 Example	67

4.1.5	Equation Type 10	69

4.1.6	Equation Type 10 Example	72

4.2 Non-IPM Sector (ptnonipm) PM Control Cost Equations	75

4.2.1	Equation Type 8 for PM	75

4.2.2	Equation Type 8 Example with Inventory Stackflow	77

4.2.3	Equation Type 8 Example without Inventory Stackflow	79

4.2.4	ICI Boiler Control Equations Type 14 for PM	80

4.2.5	ICI Boiler Control Equations Type 14 Example for PM	80

4.2.6	ICI Boiler Control Equations Type 15 for PM	82

4.2.7	ICI Boiler Control Equations Type 15 Example for PM	84

4.2.8	ICI Boiler Control Equations Type 17 for PM	86

4.2.9	ICI Boiler Control Equations Type 17 Example for PM	87

Appendix A. CoST Source Code	A-l

A.1 Equation Type 1 CoST Code for NOx	A-l

A.2 Equation Type 2 CoST Code	A-4

A.3 Equation Type 3 CoST Code	A-8

A.4 Equation Type 4 CoST Code	A-10

A.5 Equation Type 5 CoST Code	A-ll

A.6 Equation Type 6 CoST Code	A-13

A.7 Equation Type 7 CoST Code	A-14

A.8 Equation Type 8 CoST Code	A-15

A.9 Equation Type 9 CoST Code	A-17

A.10 Equation Type 10 CoST Code	A-19

A.11 Equation Type 11 CoST Code	A-21

A.12 Equation Type 12 CoST Code	A-23

A.13 Equation Type 13 CoST Code	A-25

A.14 Equation Type 14 CoST Code	A-25

A.15 Equation Type 15 CoST Code	A-27

A.16 Equation Type 16 CoST Code	A-30

A.17 Equation Type 17 CoST Code	A-32

A.18 Equation Type 18 CoST Code	A-33

A.19 Equation Type 19 CoST Code	A-34

A.20 NOx Ptnonipm CoST Code - Default Cost per Ton Equations	A-36

Appendix B. CoST Equation Control Parameters	B-l

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Control Strategy Tool (CoST) Cost Equations

Tables

Table 1-1. Equipment types and primary pollutants for each equation type	3

Table 1-2. Control Equipment Abbreviations in CoST	3

Table 2-1. N0X Source Categories Associated with Equation Type 1	5

Table 2-2. N0X Source Categories Associated with Equation Type 2	11

Table 2-3. N0X Source Categories Associated with Equation Type 12	21

Table 3-1. SO2 Source Categories Associated with EquationType 1	27

Table 3-2. SO2 Source Categories Associated with EquationType 3	32

Table 3-3. SO2 Source Categories Associated with EquationType 4	38

Table 3-4. SO2 Source Categories Associated with Equation Type 5	41

Table 3-5. SO2 Source Categories Associated with Equation Type 6	44

Table 3-6. SO2 Source Categories Associated with EquationType 11	47

Table 3-7. SO2 Source Categories Associated with EquationType 16	50

Table 4-1. PM Electric Generation Categories Associated with EquationType 8	62

Table 4-2. Electric Generation Categories Associated with EquationType 9	65

Table 4-3. Electric Generation Categories Associated with EquationType 10	69

Table 4-4. PM ptnonipm Categories Associated with Equation Type 8	75

Table B-l. ptipm Sector N0X Control Technology Parameters (Equation Type 1)	B-l

Table B-2. ptipm Sector NOx Control Cost Equation Parameters (Equation Type 1)	B-2

Table B-3. ptipm Sector SO2 Control Technology Parameters (Equation Type 1)	B-3

Table B-4. ptipm Sector SO2 Control Cost Equation Parameters (Equation Type 1)	B-3

Table B-5. ptipm Sector SO2 Control Cost Parameter for Low Sulfur Coal Fuel Switching Options.. B-4

Table B-6. ptnonipm Sector NOx Control Technology Parameters (EquationType 2)	B-4

Table B-7. ptnonipm Sector NOx Control Cost Equation Parameters (EquationType 2)	B-5

Table B-8. ptnonipm Sector SO2 Control Measure Cost Assignments (Equation Types 3-6)	B-6

Table B-9. ptipm Sector PM Control Cost Equation Parameters (Equation Type 8)	B-7

Table B-10. ptnonipm Sector PM Control CostEquation Parameters (EquationType 8)	B-7

Table B-ll. ptnonipm Sector PM Controls Default Cost per Ton Factors (Equation Type 8 or

Controls Applied to Nonpoint Sources)	B-14

Table B-12. ptipm Sector PM Control Cost Equation Parameters (Equation Type 9)	B-20

Table B-13. ptipm Sector PM Control CostEquation Factors (EquationType 10)	B-20

Table B-14. ptnonipm Sector SO2 Controls Default Cost per Ton Values (Equation Type 11)	B-21

Table B-15. ptnonipm Sector NOx Control Cost Parameters (EquationType 12)	B-23

Table B-16. Assumptions used in constructing Equation Types 14-19	B-23

Table B-17. Assumptions used in construction Equations Type 16	B-24

Table B-18. Assumptions used in constructing Equations Type 17	B-24

Table B-19. Assumptions used in constructing Equations Type 18	B-24

Table B-20. NOx ptnonipm Default Control Technologies (EquationType 2)	B-25

Table B-21. NOx ptnonipm Default Cost per Ton Values (EquationType 2)	B-31

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Control Strategy Tool (CoST) Cost Equations

Figures

Figure 2-1. Equation Type 1 example screenshot for N0X	9

Figure 2-2: Equation Type 2 CoST Screenshot	16

Figure 2-3: Non-IPM Sector N0X Control Measure Cost per Ton Screenshot	19

Figure 2-4: Equation Type 12 Example Screenshot for N0X	24

Figure 3-1: Equation Type 1 Example Screenshot for SO2	30

Figure 3-2: Equation Type 3 Example Screenshot	37

Figure 3-3: Equation Type 4 Example Screenshot	40

Figure 3-4: Equation Type 5 Example Screenshot	43

Figure 3-5. Equation Type 6 Example Screenshot	46

Figure 3-6: Equation Type 11 Example Screenshot	49

Figure 3-7: Equation Type 16 Example Screenshot	54

Figure 3-8: Equation Type 18 Example Screenshot	57

Figure 3-9: Equation Type 19 Example Screenshot	59

Figure 4-1: Equation Type 8 Example Screenshot for ptipm Source	64

Figure 4-2: Equation Type 9 Example Screenshot	68

Figure 4-3: Equation Type 10 Example Screenshot	73

Figure 4-4: Equation Type 8 Example Screenshot	78

Figure 4-5: Equation Type 14 Example Screenshot	81

Figure 4-6: Equation Type 15 Example Screenshot	84

Figure 4-7: Equation Type 17 Example Screenshot	88

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Control Strategy Tool (CoST) Cost Equations

vi


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Control Strategy Tool (CoST) Cost Equations

Acknowledgements

EPA would like to acknowledge the work of the University of North Carolina (UNC) Institute
for the Environment in updating and re-organizing this document. This work was accomplished
under EPA contract EP-D-12-044.

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Control Strategy Tool (CoST) Cost Equations

Document Revision History

Version

Description

June 9, 2010

First release version

August 31, 2011

Major update to include new CoST equations

October 25, 2011

Edits to reflect the current state of the software and control measures
database

July 3, 2014

Integration of edits and comments from previous version; addition of
Industrial/Commercial/Institutional (ICI) boiler equations

August 29, 2014

Reorganization of document; addition of Appendix A for listing the
SQL queries used by the CoST equations; addition of Appendix B for
tables of parameter values used by the CoST equations

September 4, 2014

Fixed page/chapter numbering and integration of edits and comments
from previous version; add document control code

1


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Control Strategy Tool (CoST) Cost Equations

1 Introduction

The purpose of EPA's Control Strategy Tool (CoST) is to model the emission reductions and
costs associated with control strategies applied to sources of air pollution. It was developed as a
replacement to EPA's AirControlNET (ACN) software. CoST overlays a detailed database of
control measure information on EPA emissions inventories to compute source- and pollutant-
specific emission reductions and associated costs at various geographic levels (national, regional,
local). The Control Measures Database (CMDB) contained in CoST is composed of control
measure and cost information for reducing the emissions of criteria pollutants (e.g., NOx, SO2,
VOC, PM10, PM2.5, and NH3) as well as CO and Hg from:

•	Point sources in the U.S. electric power sector, as reflected in EPA's application of the
Integrated Planning Model or "IPM" (ptipm emissions inventory sector)

•	Point sources other than those contained in IPM (ptnonipm)

•	Nonpoint sources (nonpt)

•	Mobile sources (onroad and nonroad)1.

CoST estimates the costs of emission control technologies in 2 ways:

1)	Cost equations are used to determine engineering costs that take into account several
variables for the source when data are available for those variables.

2)	A simple cost factor in terms of dollars per ton of pollutant reduced is used to calculate
the annual cost of the control measure.

Cost equations are used for some point sources (ptipm and ptnonipm sources); they are not used
for nonpoint (nonpt) sources. This document describes the cost equations used in CoST.

This document provides a list of equations and associated variables assigned to specific control
measures in CoST. The application of these equations is based on the individual emissions
inventory records to which they are applied and the specific characteristics of those records. For
example, Equation Type 1 calculates capital cost largely on a unit's generating capacity in
megawatts (MW) and is scaled based on the original control cost calculations. It is applicable to
NOx and SO2 emissions at ptipm electric generating unit (EGU) sources. For this equation type,
variable and fixed operating and maintenance (O&M) costs are estimated.

Typically, each equation type is applied either to a pollutant-source combination or to a more
general grouping of pollutants and sources. The scaling factors, additional variables, and cross-
references by control measure and equation type are detailed in this document.

The remainder of this document is divided into chapters by the primary pollutant to be
controlled. Chapters 2, 3, and 4 focus on NOx, SO2, and PM, respectively. Each chapter is further
divided into two major sections; the first focuses on IPM equation types and the second focuses
on the non-IPM types. Table 1-1 presents the equipment types and pollutants for each equation

1 Emissions inventory definitions obtained from "Technical Support Document: Preparation of Emissions
Inventories for the Version 4, 2005-based Platform". Available at:
ftp://ftp.epa.gov/EmisInventorv/2005v4/2005 emissions tsd draft llmav2010.pdf

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Control Strategy Tool (CoST) Cost Equations

type. The description of each type of control equipment is listed in Table 1-2. The source code in
CoST and the control parameters are provided in the appendices.

Table 1-1. Equipment types and primary pollutants for each equation type.

Equation
Type

Equipment Type

Primary
Pollutants

Section

1

NOx: LNB, LNBO, LNC1, LNC2, LNC3, NGR, SCR, SNCR

NOx,

2.1.1,

SCh: FGD

SO2

3.1.1

2

LNB, SCR, SCR+LNB, SCR+steam injection, SCR+water injection, SNCR,
SNCR-Urea, SNCR-Ammonia, Steam Injection, Water Injection

NOx

2.2.1

3

FGD, sulfuric acid plant

SO2

3.2.1

4

increase conversion rate, dual absorption

SO2

3.2.3

5

amine scrubbing

SO2

3.2.5

6

coke oven gas desulfurization

SO2

3.2.7

7

[not currently supported by CoST]







fabric filters, ESP, watering, catalytic oxidizers, venture scrubbers, substitute

PM

4.1.1,



land-filling or chipping for burning

4.2.1

9

fabric filter - mechanical shaker

PM

4.1.3

10

ESP upgrade

PM

4.1.5

11

IDIS, SDA, wet FGD, low sulfur fuel, wet gas scrubber, sulfur recovery, tail gas

SO2

3.2.9

treatment, catalyst additives, chemical additions to waste

12

SCR, SCR-95%, ULNB, Excess 02 Control

NOx

2.2.5

13

[not currently supported by [CoST]





14

fabric filters

PM

4.2.4

15

ESP

PM

4.2.6

16

wet scrubber

SO2

3.2.11

17

DIFF system

PM

4.2.8

18

increased caustic injection rate for existing dry injection control

SO2

3.2.13

19

spray dryer absorber

SO2

3.2.15

cost per ton

episodic ban, seasonal ban, LNB, AF Ratio, AF + IR, Mid-Kiln Firing, SCR,
SNCR, ULNB, LEA, low emission combustion, and many others

NOx

2.2.3

Table 1-2. Control Equipment Abbreviations in CoST

Equipment Abbreviation

Equipment Description

AF Ratio

Air/Fuel ratio controls

DIFF System

dry injection & fabric filter system

ESP

electrostatic precipitator

Excess O2 Control

excess oxygen control to combustor

FGD

flue gas desulfurization

FGDW

FGU wet scrubber

IDIS

IR

Ignition timing retard (for internal combustion engines)

LEA

low excess air

LNB

low NOx burner

LNBO

low NOx burner technology with overfire air

LNC1

low NOx burner technology w/ closed-coupled OFA

LNC2

low NOx burner technology w/ separated OFA

LNC3

low NOx burner technology w/ close coupled/separated OFA

LSD

lime spray dryer

LSFO

limestone forced oxidation

NGR

natural gas reburning

OFA

overfire air

SCR

selective catalytic reduction

SCR-95%

selective catalytic reduction with over 95% NOx efficiency

SCR+LNB

both selective catalytic reduction and low NOx burner technology

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Control Strategy Tool (CoST) Cost Equations

Equipment Abbreviation

Equipment Description

SCR+steam injection

selective catalytic reduction with steam injection

SCR+water injection

selective catalytic reduction with water injection

SDA

spray dryer absorber

SNCR

selective noncatalytic reduction

SNCR-Urea

selective noncatalytic reduction - urea

SNCR-Ammonia

selective noncatalytic reduction - ammonia

ULNB

ultra-low NOx burner

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Control Strategy Tool (CoST) Cost Equations

2 NOx Control Cost Equations

This chapter is divided into two main sections - IPM and non-IPM sources. The types of cost
equations for point source NOx controls are described in their appropriate sections.

•	Equation type 1 for IPM sector external combustion boilers

•	Equation type 2 for non-IPM boiler and gas turbine point sources

•	Equation type 12 for gas-fired process heaters at petroleum refineries

•	Default cost per ton equations for non-IPM point sources

Each equation type is discussed, the relevant parameters are presented, and example calculations
are provided. Appendix A includes the SQL queries that implement each CoST equation type.
Appendix B provides tables of parameters and values used with each equation type.

2.1 IPM Sector (ptipm) NOx Control Cost Equations

Equation Type 1 is the only cost equation belonging to this category of IPM sector (ptipm) point
sources requiring NOx emission reductions. These sources are electric generating units. All of the
cost data for ptipm sources are originally from the Integrated Planning Model (IPM) v3.0, which
is a model used by EPA's Clean Air Markets Division to estimate the costs of control strategies
applied to electric utilities.

2.1.1 Equation Type 1 for NOx

The data for this equation type were developed based on a series of model plants. The capacities
of these model plants are used along with scaling factors and the emission inventory's unit-
specific boiler characteristics (e.g., boiler capacity, stack parameters) to generate a control cost
for an applied technology. Default cost per ton-reduced is not considered in the application of
NOx control measures to ptipm point sources. Table 2-1 lists all of the Source Classification
Codes (SCCs) for the sources associated with Equation Type 1 in the CoST CMDB.

Table 2-1. NOx Source Categories Associated with Equation Type 1

SCC	Description

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Wet Bottom
(Bituminous Coal)	

10100201

1 m nn?n? External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

(Bituminous Coal)	

10100203 External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Cyclone Furnace (Bituminous
	Coal)	

10100212

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

	(Tangential) (Bituminous Coal)	

1 m nn? 17 External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed

	Combustion: Bubbling Bed (Bituminous Coal)	

i m nrm? External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom
	(Subbituminous Coal)	

10100226

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom
Tangential (Subbituminous Coal)	

10100301	External Combustion Boilers; Electric Generation; Lignite; Pulverized Coal: Dry Bottom, Wall Fired	

10100302	External Combustion Boilers; Electric Generation; Lignite; Pulverized Coal: Dry Bottom, Tangential Fired	

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Control Strategy Tool (CoST) Cost Equations

SCC	Description

10100317 External Combustion Boilers; Electric Generation; Lignite; Atmospheric Fluidized Bed Combustion - Bubbling Bed
10100601 External Combustion Boilers; Electric Generation; Natural Gas; Boilers >100 Million Btu/hr except Tangential
10100604 External Combustion Boilers; Electric Generation; Natural Gas; Tangentially Fired Units	

2.1.1.1 Capital Cost Equations

The purpose of a capital cost analysis is to put potential uses of capital (e.g., money, equipment)
on the same economic basis. This allows a direct comparison to be made between these potential
uses. The capital cost equations in CoST provide an estimate of the annualized capital cost of
multiple technologies for their direct economic comparison.

When developing Equation Type 1 multiple model plants were designed and the economic
calculations were then simplified. CoST calculates the capital cost associated with a control
measure by applying a scaling factor to the calculations for an appropriate model plant; the
scaling factor is calculated based on the ratio of the model plant's capacity to the capacity of a
boiler measured in megawatts (MW). Tables B-l and B-2 document the scaling factor
associated with a model plant size and a scaling factor exponent.

/.

Scaling Factor = I-

Scaling Factor Model Size\Scalin3 Factor Exponent
Capacity	J

Where:

Scaling Factor Model Size = the boiler capacity of the model plant (MW)

Scaling Factor Exponent = an empirical value based on the specific control measure
Capacity = capacity of the boiler (MW) from the inventory being processed.

The capital cost associated with these NOx control measures is a straightforward calculation of
the capital cost multiplier, the unit's boiler capacity (MW), and the scaling factor that was
calculated in the prior equation.

Capital Cost = Capital Cost Multiplier x Capacity x Scaling Factor x 1,000
Where:

Capital Cost Multiplier = an empirical value based on the specific control measure
Capacity = capacity of the boiler (MW) from the inventory being processed

The following equation provides the Capital Recovery Factor for the case of discrete interest
compounding (i.e., not continuous compounding).

Interest Rate x (1 + Interest Rate^EciulPment Llfe
Capital Recovery Factor =	(1 + ,nterest Ratey,ulpment ufe . t	

Where:

Interest Rate = annual interest rate

Equipment Life = expected economic life of the control equipment

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Control Strategy Tool (CoST) Cost Equations

Finally, the following equation calculates the annualized capital cost. This is the cost of capital
only; it does not include costs due to operations and maintenance. Those are discussed next.

Annualized Capital Cost = Capital Cost x Capital Recovery Factor

Where the Capital Cost and the Capital Recovery Factor have been calculated previously.

2.1.1.2	Operation and Maintenance Cost Equations

Operation and maintenance (O&M) costs, which are also calculated on an annual basis, are in
addition to the capital cost of equipment. These O&M costs are divided into fixed costs and
variable costs. Fixed costs are incurred because the equipment exists whether or not it is in
operation. Examples of fixed costs are property taxes, insurance, and administrative charges. The
fixed Operation and Maintenance (O&M) component is also based on the unit's capacity.

Fixed O&M = Fixed O&M Cost Multiplier x Capacity x 1,000

Where:

Fixed O&M Cost Multiplier = an empirical value based on the control measure
Capacity = capacity of the boiler (MW) from the inventory being processed
1,000 = unit conversion factor

The variable portion of the O&M costs includes an additional estimate for the unit's capacity
factor. This factor is the unit's efficiency rating based on existing utilization and operation. A
value of 1.00 would represent a completely efficient operation with no losses of production due
to heat loss or other factors. A precalculated capacity utilization factor of 85% is used for the
following utility boiler control measures; LNB, LNBO, LNC1, LNC2, and LNC3. A
precalculated capacity utilization factor of 85% is used for the following utility boiler control
measures; SCR, SNCR, and NGR.

Variable O&M = Variable O&M Cost Multiplier x Capacity x Capacity Factor x 8,760
Where:

Variable O&M Cost Multiplier = an empirical value based on the specific control measure
Capacity Factor = an empirical value based on the specific control measure
8,760 = assumed number of hours of operation per year

The total annual operations and maintenance cost is then the sum of the annual fixed and variable
O&M costs.

O&M Cost = Fixed O&M + Variable O&M

2.1.1.3	Total Annualized Cost Equation

The annualized cost is then estimated using the unit's capital cost times the CRF (derived with
the equipment specific interest rate and lifetime expectancy) and the sum of the fixed and
variable O&M costs.

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Control Strategy Tool (CoST) Cost Equations

Total Annualized Cost = Annualized Capital Cost + O&M Cost
2.1.2 Equation Type 1 Example for N0X

This section provides example calculations for an application of Equation Type 1. The example
scenario is a utility boiler - coal/tangential that requires NOx control. Using Table B-l the CoST
code is NSCR UBCT, the control measure is SCR and the control efficiency is 90%. The
remaining parameters required by Equation Type 1 are read from Table B-2.

2.1.2.1 Variables for Example Equations Type 1

The following values are read from Table B-2 and are shown in Error! Reference source not
found..

Interest Rate = 7%

Equipment Life = 20 years
Capacity (MW) = 182.298
Capital Cost Multiplier ($/kW) = 100
Fixed O&M Cost Multiplier = 0.66
Variable O&M Cost Multiplier = 0.6
Scaling Factor Model Size (MW) = 243
Scaling Factor Exponent = 0.27
Capacity Factor = 0.65
Year for Cost Basis = 1999

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Control Strategy Tool (CoST) Cost Equations



Figure 2-1. Equation Type 1 example screenshot for NOx

View Control Measure: SCR; Utility Boiler-CoalTangential

Ef E

Summary Efficiencies

SCCs

Equations

Equation

Equation Type

Variable Name

Value

Type 1

Pollutant

NOX

Type 1

Cost Year

1999

Type 1

Capital Cost Multiplier

100.0

Type 1

Fixed O&M Cost Multiplier

0.66

Type 1

Variable O&M Cost Multiplier

0.6

Type 1

Scaling Factor-Model Size (MW)

243.0

Type 1

Scaling Factor - Exponent

0.27

Type 1

Capacity Factor

0.65



Close

2.1.2.2 Annualized Capital Cost

(Scaling Factor Model Size\Scalins Factor Exponent

Capacity

0.27

Scaling Factor = I-

/ Z43.0 \

Scalinq Factor = 	

3	V182.298/

Scaling Factor = 1.081

Capital Cost = Capital Cost Multiplier x Capacity x Scaling Factor x 1,000

$	kW

Capital Cost = 100 —— x 182.298 MW x 1.081 x 1,000--—
K	kW	MW

Capital Cost = $19,700,828 (1999$)

Interest Rate x (1 + Interest Rate^EciulPment Llfe
Capital	Recovery Factor =	(1 + )ntere5t t	

0.07 X (1 + 0.07)20
Capital Recovery Factor = ^ + Q q7)2o _ x

Capital Recovery Factor = 0.094393

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Control Strategy Tool (CoST) Cost Equations

Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Annualized Capital Cost = $19,700,828 x 0.094393
Annualized Capital Cost = $1,859,620 (1999$)

2.1.2.3 Operation and Maintenance Cost

Fixed O&M = Fixed O&M Cost Multiplier x Capacity x 1,000

$	kW

Fixed O&M = 0.66-— x 182.298 MW x 1,000	

kW	MW

Fixed O&M = $120,317
Variable O&M

x 8,760 (Hours Per Year)

S

Variable O&M = 0.6—— x 182.298 MW x 0.65 x 8,760 Hours

MWh

Variable O&M = $622,803

O&M Cost = Fixed O&M + Variable O&M
O&M Cost = $120,317 + $622,803
O&M Cost = $743,130 (1999$)

2.1.2.4 Total Annualized Cost

Total Annualized Cost = Annualized Capital Cost + O&M Cost
Total Annualized Cost = $1,859,620 + $743,130 (1999$)

Total Annualized Cost = $2,602,750 (1999$)

2.2 Non-IPM Sector (ptnonipm) NOx Control Cost Equations

Control costs for some non-EGU point sources where NOx is the primary pollutant to be
controlled are discussed in this section. Emission control measures are estimated for some
Industrial/Commercial/Institutional (ICI) Boilers and Gas Turbines using Equation Type 2.
Equation Type 12 estimates emission control measures for gas-fired process heaters at petroleum
refineries. Finally, a default cost per ton is used for some additional source types.

2.2.1 Equation Type 2

Costs for some point source NOx emission control measures are estimated using Equation Type
2, as described in this section. Equation Type 2 uses a boiler capacity variable from the input
emissions inventory, as well as a scaling component that is based on the original Alternative
Control Technology or Control Technology Guidelines (ACT/CTG) analyses used to derive
these estimates. Table 2-2 lists all of the SCCs for the sources associated with Equation Type 2

in the CoST CMDB.

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Control Strategy Tool (CoST) Cost Equations

Table 2-2. NOx Source Categories Associated with Equation Type 2

see





Description

10200101

External Combustion Boilers

Industrial

Anthracite Coal; Pulverized Coal

10200104

External Combustion Boilers

Industrial

Anthracite Coal; Traveling Grate (Overfeed) Stoker

10200201

External Combustion Boilers

Industrial

Bituminous/Subbituminous Coal; Pulverized Coal: Wet Bottom

10200202

External Combustion Boilers

Industrial

Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

10200204

External Combustion Boilers

Industrial

Bituminous/Subbituminous Coal; Spreader Stoker

10200205

External Combustion Boilers

Industrial

Bituminous/Subbituminous Coal; Overfeed Stoker

10200206

External Combustion Boilers

Industrial

Bituminous/Subbituminous Coal; Underfeed Stoker

10200210

External Combustion Boilers

Industrial

Bituminous/Subbituminous Coal; Overfeed Stoker **

10200212

External Combustion Boilers
(Tangential)

Industrial

Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

10200213

External Combustion Boilers

Industrial

Bituminous/Subbituminous Coal; Wet Slurry

10200217

External Combustion Boilers

Industrial

Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed Combustion:

Bubbling Bed (Bituminous C

sal)



10200219

External Combustion Boilers

Industrial

Bituminous/Subbituminous Coal; Cogeneration (Bituminous Coal)

10200222

External Combustion Boilers

Industrial

Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

(Subbituminous Coal





10200224

External Combustion Boilers

Industrial

Bituminous/Subbituminous Coal; Spreader Stoker (Subbituminous Coal)

10200225

External Combustion Boilers

Industrial

Bituminous/Subbituminous Coal; Traveling Grate (Overfeed) Stoker

(Subbituminous Coal)





10200229

External Combustion Boilers

Industrial

Bituminous/Subbituminous Coal; Cogeneration (Subbituminous Coal)

10200301

External Combustion Boilers

Industrial

Lignite; Pulverized Coal: Dry Bottom, Wall Fired

10200306

External Combustion Boilers

Industrial

Lignite; Spreader Stoker

10200401

External Combustion Boilers

Industrial

Residual Oil; Grade 6 Oil

10200402

External Combustion Boilers

Industrial

Residual Oil; 10-100 Million Btu/hr

10200403

External Combustion Boilers

Industrial

Residual Oil; <10 Million Btu/hr

10200404

External Combustion Boilers

Industrial

Residual Oil; Grade 5 Oil

10200405

External Combustion Boilers

Industrial

Residual Oil; Cogeneration

10200501

External Combustion Boilers

Industrial

Distillate Oil; Grades 1 and 2 Oil

10200502

External Combustion Boilers

Industrial

Distillate Oil; 10-100 Million Btu/hr

10200503

External Combustion Boilers

Industrial

Distillate Oil; <10 Million Btu/hr

10200504

External Combustion Boilers

Industrial

Distillate Oil; Grade 4 Oil

10200505

External Combustion Boilers

Industrial

Distillate Oil; Cogeneration

10200601

External Combustion Boilers

Industrial

Natural Gas; >100 Million Btu/hr

10200602

External Combustion Boilers

Industrial

Natural Gas; 10-100 Million Btu/hr

10200603

External Combustion Boilers

Industrial

Natural Gas; <10 Million Btu/hr

10200604

External Combustion Boilers

Industrial

Natural Gas; Cogeneration

10200901

External Combustion Boilers

Industrial

Wood/Bark Waste; Bark-fired Boiler

10200902

External Combustion Boilers

Industrial

Wood/Bark Waste; Wood/Bark-fired Boiler

10200903

External Combustion Boilers

Industrial

Wood/Bark Waste; Wood-fired Boiler - Wet Wood (>=20% moisture)

10200904

External Combustion Boilers

Industrial

Wood/Bark Waste; Bark-fired Boiler (< 50,000 Lb Steam)

10200905

External Combustion Boilers

Industrial

Wood/Bark Waste; Wood/Bark-fired Boiler (< 50,000 Lb Steam)

10200906

External Combustion Boilers

Industrial

Wood/Bark Waste; Wood-fired Boiler (< 50,000 Lb Steam)

10200907

External Combustion Boilers

Industrial

Wood/Bark Waste; Wood Cogeneration

10200912

External Combustion Boilers

Industrial

Wood/Bark Waste; Fluidized bed combustion boiler

10201401

External Combustion Boilers

Industrial

CO Boiler; Natural Gas

10201403

External Combustion Boilers

Industrial

CO Boiler; Distillate Oil

10201404

External Combustion Boilers

Industrial

CO Boiler; Residual Oil

10300101

External Combustion Boilers

Commercial/Institutional; Anthracite Coal; Pulverized Coal

10300102

External Combustion Boilers

Commercial/Institutional; Anthracite Coal; Traveling Grate (Overfeed) Stoker

10300103

External Combustion Boilers

Commercial/Institutional; Anthracite Coal; Hand-fired

10300205

External Combustion Boilers

Commercial/Institutional; Bituminous/Subbituminous Coal; Pulverized Coal: Wet

Bottom (Bituminous Coal)





10300206

External Combustion Boilers

Commercial/Institutional; Bituminous/Subbituminous Coal; Pulverized Coal: Dry

Bottom (Bituminous Coal)





10300207

External Combustion Boilers
(Bituminous Coal)

Commercial/Institutional; Bituminous/Subbituminous Coal; Overfeed Stoker

11


-------
Control Strategy Tool (CoST) Cost Equations

see

Description

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Underfeed Stoker
(Bituminous Coal)

10300208

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Spreader Stoker
(Bituminous Coal)	

10300209

10300211 External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Overfeed Stoker

10300216

10300217

10300221

10300222

10300224

10300225

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Pulverized Coal: Dry

Bottom (Tangential) (Bituminous Coal)	

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Atmospheric Fluidized

Bed Combustion: Bubbling Bed (Bituminous Coal)	

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Pulverized Coal: Wet

Bottom (Subbituminous Coal)	

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Pulverized Coal: Dry

Bottom (Subbituminous Coal)	

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Spreader Stoker

(Subbituminous Coal)	

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Traveling Grate
(Overfeed) Stoker (Subbituminous Coal)

10300309	External Combustion Boilers; Commercial/Institutional; Lignite; Spreader Stoker	

10300401	External Combustion Boilers; Commercial/Institutional; Residual Oil; Grade 6 Oil	

10300402	External Combustion Boilers; Commercial/Institutional; Residual Oil; 10-100 Million Btu/hr	

10300404	External Combustion Boilers; Commercial/Institutional; Residual Oil; Grade 5 Oil	

10300501	External Combustion Boilers; Commercial/Institutional; Distillate Oil; Grades 1 and 2 Oil	

10300502	External Combustion Boilers; Commercial/Institutional; Distillate Oil; 10-100 Million Btu/hr	

10300503	External Combustion Boilers; Commercial/Institutional; Distillate Oil; < 10 Million Btu/hr	

10300504	External Combustion Boilers; Commercial/Institutional; Distillate Oil; Grade 4 Oil	

10300601	External Combustion Boilers; Commercial/Institutional; Natural Gas; >100 Million Btu/hr	

10300602	External Combustion Boilers; Commercial/Institutional; Natural Gas; 10-100 Million Btu/hr	

10300603	External Combustion Boilers; Commercial/Institutional; Natural Gas; <10 Million Btu/hr	

10300901	External Combustion Boilers; Commercial/Institutional; Wood/Bark Waste; Bark-fired Boiler	

10300902	External Combustion Boilers; Commercial/Institutional; Wood/Bark Waste; Wood/Bark-fired Boiler

10300903

External Combustion Boilers;
(>=20% moisture)	

Commercial/Institutional; Wood/Bark Waste; Wood-fired Boiler - Wet Wood

10300912 External Combustion Boilers; Commercial/Institutional; Wood/Bark Waste; Fluidized bed combustion boilers	

20100101 Internal Combustion Engines; Electric Generation; Distillate Oil (Diesel);Turbine	

20100105 Internal Combustion Engines; Electric Generation; Distillate Oil (Diesel); Reciprocating: Crankcase Blowby	

7m nm Internal Combustion Engines; Electric Generation; Distillate Oil (Diesel); Reciprocating: Evaporative Losses (Fuel

	Storage and Delivery System)	

20100107 Internal Combustion Engines; Electric Generation; Distillate Oil (Diesel); Reciprocating: Exhaust	

20100108

Internal Combustion Engines; Electric Generation; Distillate Oil (Diesel); Turbine: Evaporative Losses (Fuel

Storage and Delivery System)	

20100109 Internal Combustion Engines; Electric Generation; Distillate Oil (Diesel); Turbine: Exhaust	

20100201 Internal Combustion Engines; Electric Generation; Natural Gas; Turbine	

20100205	Internal Combustion Engines; Electric Generation; Natural Gas; Reciprocating: Crankcase Blowby	

20100206	Intemal Combustion Engines;

	System)	

Electric Generation; Natural Gas; Reciprocating: Evaporative Losses (Fuel Delivery

20100207 Internal Combustion Engines; Electric Generation; Natural Gas; Reciprocating: Exhaust

20100208

Internal Combustion Engines;
System)

Electric Generation; Natural Gas; Turbine: Evaporative Losses (Fuel Delivery

20100209 Internal Combustion Engines; Electric Generation; Natural Gas; Turbine: Exhaust

20200101 Internal Combustion Engines; Industrial; Distillate Oil (Diesel); Turbine

20200103 Internal Combustion Engines; Industrial; Distillate Oil (Diesel); Turbine: Cogeneration

20200105 Internal Combustion Engines; Industrial; Distillate Oil (Diesel); Reciprocating: Crankcase Blowby

20200106

Internal Combustion Engines;
and Delivery System)	

Industrial; Distillate Oil (Diesel); Reciprocating: Evaporative Losses (Fuel Storage

20200107 Internal Combustion Engines; Industrial; Distillate Oil (Diesel); Reciprocating: Exhaust

20200108

Internal Combustion Engines;
Delivery System)

Industrial; Distillate Oil (Diesel); Turbine: Evaporative Losses (Fuel Storage and

20200109 Internal Combustion Engines; Industrial; Distillate Oil (Diesel); Turbine: Exhaust

12


-------
Control Strategy Tool (CoST) Cost Equations

SCC	Description	

20200201	Internal Combustion Engines; Industrial; Natural Gas; Turbine	

20200203	Internal Combustion Engines; Industrial; Natural Gas; Turbine: Cogeneration	

20200205	Internal Combustion Engines; Industrial; Natural Gas; Reciprocating: Crankcase Blowby	

20200206	Internal Combustion Engines; Industrial; Natural Gas; Reciprocating: Evaporative Losses (Fuel Delivery System)

20200207	Internal Combustion Engines; Industrial; Natural Gas; Reciprocating: Exhaust	

20200208	Internal Combustion Engines; Industrial; Natural Gas; Turbine: Evaporative Losses (Fuel Delivery System)	

20200209	Internal Combustion Engines; Industrial; Natural Gas; Turbine: Exhaust	

20200252	Internal Combustion Engines; Industrial; Natural Gas; 2-cycle Lean Burn	

20200253	Internal Combustion Engines; Industrial; Natural Gas; 4-cycle Rich Burn	

20200254	Internal Combustion Engines; Industrial; Natural Gas; 4-cycle Lean Burn	

20200255	Internal Combustion Engines; Industrial; Natural Gas; 2-cycle Clean Burn	

20200256	Internal Combustion Engines; Industrial; Natural Gas; 4-cycle Clean Burn	

20300102	Internal Combustion Engines; Commercial/Institutional; Distillate Oil (Diesel); Turbine	

20300105	Internal Combustion Engines; Commercial/Institutional; Distillate Oil (Diesel); Reciprocating: Crankcase Blowby

_n,nm _,	Internal Combustion Engines; Commercial/Institutional; Distillate Oil (Diesel); Reciprocating: Evaporative Losses

	(Fuel Storage and Delivery System)	

20300107	Internal Combustion Engines; Commercial/Institutional; Distillate Oil (Diesel); Reciprocating: Exhaust	

?mnni ns	Internal Combustion Engines; Commercial/Institutional; Distillate Oil (Diesel); Turbine: Evaporative Losses (Fuel

	Storage and Delivery System)	

20300109	Internal Combustion Engines; Commercial/Institutional; Distillate Oil (Diesel); Turbine: Exhaust	

20300202	Internal Combustion Engines; Commercial/Institutional; Natural Gas; Turbine	

20300203	Internal Combustion Engines; Commercial/Institutional; Natural Gas; Turbine: Cogeneration	

20300205	Internal Combustion Engines; Commercial/Institutional; Natural Gas; Reciprocating: Crankcase Blowby	

_n,nn-n,	Internal Combustion Engines; Commercial/Institutional; Natural Gas; Reciprocating: Evaporative Losses (Fuel

-1—V	1 '	f-1	.	X

	Delivery System)	

20300207 Internal Combustion Engines; Commercial/Institutional; Natural Gas; Reciprocating: Exhaust	

imnmno Internal Combustion Engines; Commercial/Institutional; Natural Gas; Turbine: Evaporative Losses (Fuel Delivery
2U3UUzUo ^ . ,

	System)	

20300209 Internal Combustion Engines; Commercial/Institutional; Natural Gas; Turbine: Exhaust	

Table B-6 lists the point source categories and control measures covered by Cost Equation Type
2. These are Industrial/Commercial/Institutional (ICI) Boilers and Gas Turbines and do not
include the large utility or industrial external combustion boilers that are part of the IPM sector.

Equation Type 2-based costs are estimated for units that have a boiler capacity value not
exceeding 2,000 million Btu per hour (mmBtu/hr). For those sources not meeting the boiler
capacity threshold, default costs per ton are used (see Section 2.2.3). Furthermore, a size
classification is applied for other ptnonipm sources based on the ozone season daily emissions
value. Following the definition included in the NOx SIP call program, a daily emissions value of
less than one ton NOx per day designates the source as small and applies control cost parameters
consistent with this classification. Sources that emit one or more tons per day are considered
large, and the appropriate parameters for large sources are applied.

For Equation Type 2 controls, if a NOx control is already in place from the input inventory,
another control can be applied incrementally only. The control costs associated with incremental
controls are based on alternate default cost per ton or alternate control cost variables. These
alternate values take into account the incremental ineffectiveness of applying controls to units
which already have a level of control assigned.

13


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Control Strategy Tool (CoST) Cost Equations

2.2.1.1	Capital Cost Equation

Tables B-6 and B-7 provide a list of the control cost parameters and variables as assigned during
the application of Cost Equation Type 2 to NOx controls. The O&M costs are calculated by
subtracting the product of capital costs x capital recovery factor (CRF) from the annualized
costs. The CRF is included in the current Control Measures Database (CMDB). This value is
recalculated in CoST using the equipment life and interest rate of the specific measure, when
available. If equipment life is unavailable for the measure then the CRF provided in the CMDB
is used.

Capital Cost = Capital Cost Multiplier x DESIGN JCAPAC1TY Cavital cost Exponent
Where:

Capital Cost Multiplier = an empirical value based on the specific control measure
Capital Cost Exponent = an empirical value based on the specific control measure
DESIGN CAPACITY = the capacity in mmBTU/hr obtained from the emissions inventory

Interest Rate x (1 + Interest Rate^Ectulpment Life

Capital Recovery Factor =			——:	777	

f	y	(I + Interest Rate)EciulvmentLlfe - I

Where:

Interest Rate = annual interest rate

Equipment Life = expected economic life of the control equipment

Annualized Capital Cost = Capital Cost x Capital Recovery Factor

Where the Capital Cost and the Capital Recovery Factor have been calculated previously.

2.2.1.2	Total Annualized Cost Equation

Total Annualized Cost = Annual Cost Multiplier x DESIGN_CAPAClTYAnnual Cost ExP°nent
Where:

Annual Cost Multiplier = an empirical value based on the specific control measure
Annual Cost Exponent = an empirical value based on the specific control measure
DESIGN CAPACITY = the capacity in mmBTU/hr obtained from the emissions inventory

2.2.1.3	Operation and Maintenance Equation

0&.M Cost = Total Annualized Cost — Annualized Capital Cost

Where the Total Annualized Cost and the Annualized Capital Cost were calculated previously.
2.2.2 Equation Type 2 Example

This section provides example calculations for an application of Equation Type 2. The example
scenario is an ICI boiler - coal/wall that requires NOx control. Using Table B-6 the CoST code is

14


-------
Control Strategy Tool (CoST) Cost Equations

NSCRIBCW, the control measure is SCR and the control efficiency is 90%. The remaining
parameters required by Equation Type 1 are read from Table B-7.

2.2.2.1 Example Equation Variables

The following values are read from Table B-7 and are shown in Figure 2-2. Also, this example
uses the values for the Default Application, not the Incremental Application (i.e., no NOx control
is already being used).

Interest Rate = 7%

Equipment Life = 20 years

DESIGN CAPACITY = 301.0 mmBTU/hr (from emissions inventory)

Capital Cost Multiplier = 82400.9

Capital Cost Exponent = 0.65

Annual Cost Multiplier = 5555.6

Annual Cost Exponent = 0.79

Year for Cost Basis = 1990

The following values are for the Incremental Application shown in Section 2.2.2.3.

Interest Rate = 7%

Equipment Life = 20 years

DESIGN CAPACITY = 301.0 mmBTU/hr (from emissions inventory)

Capital Cost Multiplier = 79002.2

Capital Cost Exponent = 0.65

Annual Cost Multiplier = 8701.5

Annual Cost Exponent = 0.65

Year for Cost Basis = 1990

15


-------
Control Strategy Tool (CoST) Cost Equations

Figure 2-2: Equation Type 2 CoST Screenshot

View Control Measure: SCR: ICI Boilers - Coal.Wali













( Summary Efficiencies | SCCs

Equations ( Properties

References



Equation Type:

Name:	Type 2

Description: NonEGU NOx

Inventory Fields: deslgn_capacity, rtesign_capacity_utirt_nuroefStor, design .capacity_nnii.denominator

Equation:

Annual Cost = Annual Cost Multiplier* (Boiler Capacity) * Exponent
Capital Coal = Capital Cost Multiplier x (Boiler Capacity) * Exponent

Equation Type

Variable Name

Value

Type 2

Pollutant

NOX

Type 2

Cost Year

1990

Type 2

Capital Cost Multiplier

62400.9

Type 2

Capital Cost Exponent

0.65

Type 2

Annual Cost Multiplier

55556

Type 2

Annual Cost Exponent

0 79

Type 2

Incremental Capital Cost Multiplier

79002.2

Type 2

Incremental Capital Cost Exponent

0.65

Type 2

Incremental Annual Cost Multiplier

8701.5

Type 2

Incremental Annual Cost Exponent

0.65

2.2.2.2 When No Control is Currently in Place for the Source

All costs are in 1990 U.S. Dollars because that is the base year for the references for these
equations and for the capital-to-annual ratios.

2.2.2.2.1 Capital Cost Equations

Capital Cost = Capital Cost Multiplier x DESIGN_CAPACITY CaPltal cost Exponent
Capital Cost = $82,400 x 301.0065
Capital Cost = $3,365/117 (1990$)

Interest Rate x (1 + Interest Rate^E(iulpment Life

Capital Recovery Factor = 		;	——	7-773	

(1 + Interest Rate)EquivmentL^e - 1

0.07 x (1 + 0.07)20
Capital Recovery Factor = • — -		—«

Capital Recovery Factor = 0.094393

16


-------
Control Strategy Tool (CoST) Cost Equations

Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Annualized Capital Cost = $3,365,117 x 0.0944
Annualized Capital Cost = $317,643 (1990$)

2.2.2.2.2	Total Annualized Cost Equation

Total Annualized Cost = Annual Cost Multiplier x DESIGN_CAPAClTYAnnual Cost ExP°nent
Total Annualized Cost = $5,555.60 x 301.0 0,79
Total Annualized Cost = $504,427 (1990$)

2.2.2.2.3	Operation and Maintenance Equation

0&.M Cost = Total Annualized Cost — Annualized Capital Cost
0&.M Cost = $504,427 - $317,643
0&.M Cost = $186,784 (1990$)

2.2.2.3 When Control is Applied Incrementally to the Source

2.2.2.3.1	Capital Cost Equations
Capital Cost

= Incremental Capital Cost Multiplier x DESIGN_CAPACITYIncremental capital cost Exponent
Capital Cost = $79,002.20 x 301.00,65
Capital Cost = $3,226,319 (1990$)

Interest Rate x (1 + Interest Rate~)Equipment Llfe
Capital Recovery Factor =	a + interest Rate?"*™"	!	

0.07 X (1 + 0.07)20
Capital Recovery Factor = ^ + Q q7)2o _ x

Capital Recovery Factor = 0.094393

Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Annualized Capital Cost = $3,226,319 x 0.0944
Annualized Capital Cost = $304,564 (1990$)

2.2.2.3.2	Total Annualized Cost Equation

Total Annualized Cost
= Incremental Annual Cost Multiplier

X DESIGN £J[pj[£ITY^ncremen^a^ Annual Cost Exponent

Total Annualized Cost = $8,701.50 x 301.00 65
Total Annualized Cost = $355,354 (1990$)

2.2.2.3.3	Operation and Maintenance Equation

O&M Cost = Total Annualized Cost — Annualized Capital Cost
0&.M Cost = $355,354- $304,564

17


-------
Control Strategy Tool (CoST) Cost Equations

O&M Cost = $50,791 (1990$)

2.2.3 Nott-IPM Sector (ptnonipm) NOx Control Cost per Ton Calculations

When a source qualifies for Equation Type 2 except for the boiler capacity, default cost per ton
values are assigned and applied to the annual emissions reduction achieved by the applied
control measure. In these applications, a capital-to-annual cost ratio is applied to estimate the
capital cost associated with the control. The O&M costs are calculated by subtracting the product
of capital cost x CRF from the annualized costs. The variables used in the default cost per ton
equations are provided in Tables B-20 and B-21.

Note that the calculations for this cost per ton method are performed in a different order than for
the Equation Type 2 calculations.

2.2.3.1	Total Annualized Cost

When no control is currently in place for the source:

Total Annualized Cost = Emission Reduction x Default Cost Per Ton

Where:

Emission Reduction = calculated by CoST

Default Cost per Ton = an empirical value based on the specific control measure

When a control is applied incrementally to the source:

Total Annualized Cost = Emission Reduction x Incremental Cost Per Ton

Where:

Emission Reduction = calculated by CoST

Incremental Cost per Ton = an empirical value based on the specific control measure

2.2.3.2	Capital Cost

Capital Cost = Total Annualized Cost x Capital to Annual Ratio

Interest Rate x (1 + Interest Rate^EciulPment Llfe
Capital Recovery Factor =	[C1 + lnterest Ratey^m ^	

Where:

Interest Rate = annual interest rate

Equipment Life = expected economic life of the control equipment

Annualized Capital Cost = Capital Cost x Capital Recovery Factor

Where the Capital Cost and the Capital Recovery Factor were calculated previously.

18


-------
Control Strategy Tool (CoST) Cost Equations

2.2.3.3 Operation and Maintenance Cost

Total 0&.M = Total Annualized Cost — Annualized Capital Cost

Where the Total Annualized Cost and the Annualized Capital Cost were calculated previously.
2.2.4 Non-IPM Sector (ptnonipm) NOx Control Cost per Ton Example

This section provides example calculations for an application of this cost per ton method for NOx
control on a source in the non-IPM sector. Use Tables B-20 and B-21 with the CoST CM
Abbreviation NLNBFCSRS to obtain the values in this example.

2.2.4.1 Example Equation Variables

Interest Rate = 7%

NOx Emission Redaction =125 tons/yr
Equipment Life = 10 years (from Summary Tab)
Capital to Annual Ratio = 7.0 (from Efficiencies Tab)
Default Cost per Ton Reduced = 750 (1990$)
Incremental Cost per Ton Reduced = 250 (1990$)
Year for Cost Basis = 1990

Figure 2-3: Non-IPM Sector NOx Control Measure Cost per Ton Screenshot

View Control Measure: LNB + FGR; Iron & Steel Mills - Annealing

~ Ef

Summary [f Efficiencies f SCCs Equations Properties References

Row Limit 100

Row Filter

J

Apply

T



$000

M

~

TT

Pollutant

Locale

Effective Date

Cost Year

CPT

Incremental CPT

Control Efficiency

Ref YrCPT

Mi

NOX

1990

750.00

250.00

60.00

1191.00

NOX

1990

750.00

250.00

60.00

1191.00

2 rows : 22 columns: 0 Selected [Filter: None, Sort: None]

View

Report

Close

19


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Control Strategy Tool (CoST) Cost Equations

2.2.4.2	When no Control Measure is currently in Place for the Source

2.2.4.2.1	Total Annualized Cost

Total Annualized Cost = Emission Reduction x Default Cost Per Ton
Total Annualized Cost = 125 x $750
Total Annualized Cost = $93,750 (1990$)

2.2.4.2.2	Capital Cost

When no control measure is currently in place for the source:

Capital Cost = Total Annualized Cost x Capital to Annual Ratio
Capital Cost = $93,750 x 7.0
Capital Cost = $656,250 (1990$)

Interest Rate x (1 + Interest Rate^EciulPment Llfe
Capital Recovery Factor =	[(1 + Interest Rate)Equipment Life _ x]	

0.07 X (1 + 0.07)10
Capital Recovery Factor = + Q Qr^10 _

Capital Recovery Factor = 0.1424

Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Annualized Capital Cost = $656,250 x 0.1424
Annualized Capital Cost = $93,435 (1990$)

2.2.4.2.3	Operation and Maintenance Cost

Total 0&.M Cost = Total Annualized Cost — Annualized Capital Cost
Total 0&.M Cost = $93,750 — $93,435
Total 0&.M Cost = $315 (1990$)

2.2.4.3	When Control Measure is Applied Incrementally to the Source

2.2.4.3.1	Total Annualized Cost

Total Annualized Cost = Emission Reduction x Incremental Cost Per Ton
Total Annualized Cost = 125 x $250
Total Annualized Cost = $31,250 (1990$)

2.2.4.3.2	Capital Cost

When the control measure is added to one that is already in place at the source:
Capital Cost = Total Annualized Cost x Capital to Annual Ratio
Capital Cost = $31,250 x 7.0
Capital Cost = $218,750 (1990$)

Interest Rate x (1 + Interest Rate^EciulPment Llfe
Capital Recovery Factor =	[C1 + lnterest Ratey^m ^	

20


-------
Control Strategy Tool (CoST) Cost Equations

0.07 X (1 + 0.07)10
Capital Recovery Factor = + Q Qr^10 _

Capital Recovery Factor = 0.14

Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Annualized Capital Cost = $218,750 x 0.14
Annualized Capital Cost = $30,625 (1990$)

2.2.4.3.3 Operation and Maintenance Cost

Total 0&.M Cost = Total Annualized Cost — Annualized Capital Cost
Total 0&.M Cost = $31,250 — $30,625
Total O&lM Cost = $625 (1990$)

2.2.5 Equation Type 12 for NOx

For a select set of gas-fired process heaters at petroleum refineries, control costs are estimated
using stack flowrate and temperature represented by Equation Type 12. Costs are estimated for
units that have a positive stack flowrate and temperature value. For those sources with missing
stack flowrate or temperature, no costs are calculated. No default cost estimates are currently
available for these sources. Table 2-3 lists all of the SCCs for the sources associated with
Equation Type 12 in the CoST CMDB.

Table 2-3. NOx Source Categories Associated with Equation Type 12

see

Description

30600102

Industrial Processes; Petroleum Industry; Process Heaters; Gas-fired

30600104

Industrial Processes; Petroleum Industry; Process Heaters; Gas-fired

30600105

Industrial Processes; Petroleum Industry; Process Heaters; Natural Gas-fired

30600106

Industrial Processes; Petroleum Industry; Process Heaters; Process Gas-fired

30600107

Industrial Processes; Petroleum Industry; Process Heaters; LPG-fired

30600108

Industrial Processes; Petroleum Industry; Process Heaters; Landfill Gas-fired

Table B-15 provides a list of the control cost parameters and variables as assigned during the
application of Cost Equation Type 12 to NOx controls applied to ptnonipm sources.

2.2.5.1 Capital Cost Equations

The conditions in the stack are determined from the inventory being processed. Calculate the
standard flowrate in standard cubic feet per minute (scfm):

7r.i	. s r	IJ-.I	. ^	/ Standard Temperature (Rankine) \

Stack Flowrate (scfm) = Stack Flowrate (acfm) x 	-r-	-

v	v ' J \ Stack Temperature (F)+ 460 /

(	520	\

Stack Flowrate (scfm) = Stack Flowrate (acfm) x 			——	

y	J \Stack Temperature (F) + 460 /

Where:

21


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Control Strategy Tool (CoST) Cost Equations

Stack Flow rate (acfm) = flow rate of gas in the stack in actual cubic feet per minute (i.e., at the
actual conditions of the stack, acfm)

Stack Flow rate (scfm) = flow rate of gas in the stack in standard cubic feet per minute (i.e., at

60°F and ambient pressure, scfm)

Stack Temperature (F) = actual temperature in the stack

Capital Cost

= (Fixed Capital Cost Multiplier + Variable Capital Cost Multiplier)

/Stack Flowrate (scfm)\°6
X V	150,000	)

Where:

Fixed Capital Cost Multiplier = an empirical value based on the specific control measure
Variable Capital Cost Multiplier = an empirical value based on the specific control measure2

Interest Rate x (1 + Interest Rate^EciulPment Llfe
Capital Recovery Factor =	(1 + ,nterest Ratey,ulpment ufe . t	

Where:

Interest Rate = annual interest rate

Equipment Life = expected economic life of the control equipment

Annualized Capital Cost = Capital Cost x Capital Recovery Factor

Where the Capital Cost and the Capital Recovery Factor have been calculated previously.

2.2.5.2 Operation and Maintenance Cost Equations

/Stack Flow Rate (scfm)\

Fixed O&M = Fixed O&M Cost Multiplier x (			1

H V	150,000	/

Where:

Fixed O&M Cost Multiplier = an empirical value based on the specific control measure
Stack Flow Rate = expected flow rate out of the stack in standard cubic feet per minute (scfm)

(Stack Flow Rate (scfm)\

Variable O&M = Variable O&M Cost Multiplier x 			

H V	150,000	/

Where:

Variable O&M Cost Multiplier = an empirical value based on the specific control measure
Stack Flow Rate = expected flow rate out of the stack in standard cubic feet per minute (scfm)

Annualized O&M Cost = Fixed O&M + Variable O&M

2 Fixed and variable cost multipliers for Equation Type 12 are from the reference "MACTEC Engineering and
Consulting, Inc., 2005, "Petroleum Refinery Best Available Retrofit Technology (BART) Engineering Analysis".

22


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Control Strategy Tool (CoST) Cost Equations

Where the Fixed O&M and the Variable O&M have been calculated previously.

2.2.5.3 Total Annualized Cost Equation

Total Annualized Cost = Annualized O&M Cost + Annualized Capital Cost

Where the Annualized O&M Cost and the Annualized Capital Cost were calculated previously.

2.2.6 Equation Type 12 Example for NOx

This section provides example calculations for an application of Equation Type 12. The example
scenario is a gas-fired process heater at a petroleum refinery. The NOx control mechanism is
excess oxygen control (PRGFPRE02C). The remaining parameters required by Equation Type
12 are read from Table B-15 and are shown in Figure 2-4.

2.2.6.1 Example Equation Variables

Interest Rate = 7%

Equipment Life = 20 years (from summary tab of control measure data)

Stack Flow rate (acfm) = 43,055 ftVmin

Stack Temperature (F) = 650 °F

Fixed Capital Cost Multiplier = $20,000

Variable Capital Cost Multiplier = $0

Fixed O&M Cost Multiplier = $4,000

Variable O&M Cost Multiplier = $0

Capital Recovery Factor = 0.243890694

Year for Cost Basis = 2006

23


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Control Strategy Tool (CoST) Cost Equations

Figure 2-4: Equation Type 12 Example Screenshot for NCK

. View Control Measure: Petroleum Refinery Gas-Fired Process Heaters; Excess 02 Control Gf 0





( Summary Efficiencies SCCs Equations f Properties | References

Equation Type:

Name: Type 12

Description: NOx Controls for Gas-Fired Process Heaters at Petroleum Refineries Equations
Inventory Fields: stack_flow_rate,stack_temperature



Equation:

stack_flow_rate (scfm) = stack_flow_rate (acfm) x 460 / (stack_temperature + 460)

Total Capital Investment (TCI) = (Fixed TCI + Variable TCI) x (stack_flow_rate (scfm)/150,000)* 6
Annual Operating Cost (AOC) = (AOC fixed + AOC variable) x (stack_f!ow_rate (scfm)/150,000)
Total Annual Cost (TAC) = AOC + Capital Recovery Factor (CRF)xTCI









Equation Type

Variable Name

Value

Type 12

Pollutant

NOX

Type 12

Cost Year

2006

Type 12

Total Capital Investment (TCI) Fixed Factor

20000.0

Type 12

Total Capital Investment (TCI) Variable Factor



Type 12

Annual Operating Cost (AOC) Fixed Factor

4000.0

Type 12

Annual Operating Cost (AOC) Variable Factor





Report Close

2.2.6.2 Annualized Capital Cost

/Standard Temperature (Rankine) \

Stack Flow Rate (scfm) = Stack Flow Rate (acfm) x j					1 I

K ' J	\ stack Temperature (/• ) + 460 J

( 520

Stack Flow Rate (scfm) = 43,055 x

650 + 460
Stack Flow Rate (scfm) = 20,170
Capital Cost

= (Fixed Capital Cost Multiplier + Variable Capital Cost Multiplier)
(Stack Flow Rate (scfm)\°'6

x

V	150,000	)

( 20,170 \0'5
Capital Cost = (20,000 + 0.0) x , ——— J

\ _1- J\J p U U U /

Capital Cost = $6,001 (2006$)

24


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Control Strategy Tool (CoST) Cost Equations

Note that for Equation Type 12 the Capital Recovery Factor is read from the table instead of
being calculated from the discount rate and equipment life.

Annualized Capital Cost = Capital Cost x Capital Recovery Factor

Annualized Capital Cost = $6,001 x 0.243890694

Annualized Capital Cost = $1,464 (2006$)

2.2.6.3 Operation and Maintenance Cost

Variable O&M = Variable O&M Cost Multiplier x fstack Flow Rate (scfmA

r	V	150,000	)

Variable O&M = $0

Annualized O&M Cost = Fixed O&M + Variable O&M
O&M Cost = $538 + $0
O&M Cost = $538 (2006$)

2.2.6.4 Total Annualized Cost

Total Annualized Cost = Annualized O&M Cost + Annualized Capital Cost
Total Annualized Cost = $538 + $1464 (2006$)

Total Annualized Cost = $2,002 (2006$)

Fixed O&M = Fixed O&M Cost Multiplier x

Fixed O&M = 4,000 x

Fixed O&M = $538

Variable O&M = Ox

25


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Control Strategy Tool (CoST) Cost Equations

3 SO2 Control Cost Equations

This section is divided into two main sections - IPM and non-IPM sources. The types of cost
equations for point source SO2 controls are described in their appropriate sections.

•	Equation type 1 for IPM sector external combustion boilers

•	Equation type 3 for non-IPM sector external combustion boilers, process heaters,
primary metals, glassmaking furnace

•	Equation type 4 for non-IPM sulfuric acid plants

•	Equation type 5 for non-IPM elemental sulfur production

•	Equation type 6 for non-IPM primary metal production related to by-product coke
manufacturing

•	Equation type 11 for non-IPM industrial external combustion boilers.

•	Equation type 16 for non-IPM external combustion boilers and select industrial
processes

•	Equation type 18 for the same non-IPM sources as equation type 16

•	Equation type 19 for the same non-IPM sources as equation type 16

Each equation type is discussed, the relevant parameters are presented, and example calculations
are provided. Appendix A includes the SQL queries that implement each CoST equation type.
Appendix B provides tables of parameters and values used with each equation type.

3.1 IPM Sector (ptipm) SO2 Control Cost Equations

IPM sector (ptipm) point sources utilizing control cost equations for SO2 emission reductions are
limited to Equation Type 1 and to two low sulfur coal switching default cost per ton equation
calculations. In Equation Type 1, model plant capacities are used along with scaling factors and
the emission inventory's unit-specific boiler characteristics to generate a control cost for an
applied technology.

Default cost per ton reduced values are not considered in the application of SO2 control measures
to ptipm point sources with the exception of two low sulfur coal switching options as presented
in Table B-5.

These two low sulfur coal options are applied based on the sulfur content of the coal burned as
provided in the emissions inventory. Three classifications of coal are assigned: (1) medium
sulfur (<= 2% S by weight), (2) high sulfur (2-3% S by weight), and (3) very high sulfur (>3% S
by weight).

3.1.1 Equation Type 1 for SO2

Equation Type 1 involves the application of a scaling factor to adjust the capital cost associated
with a control measure to the boiler size (MW) based on the original control technology's
documentation. The applicable SCCs are listed in Table 3-1. As noted in Tables B-3 and B-4, a
scaling factor model plant size and exponent are provided for this estimate.

26


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Control Strategy Tool (CoST) Cost Equations

For SO2 controls applied to ptipm sources, a scaling factor is applied when the emission
inventory source size is less than the scaling factor model size. If the unit's capacity is greater
than or equal to the scaling factor model size, the scaling factor is set to unity (1.0).

Additional restrictions on source size are shown for other controls that use equation type 1. In
Table B-4, when the Application Restriction lists a minimum and maximum capacity, the control
is not applied unless the capacity of the source in the inventory falls within that range.

	Table 3-1. SO2 Source Categories Associated with Equation Type 1	

SCC	Description

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Wet Bottom

(Bituminous Coal)	

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

(Bituminous Coal)	

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Cyclone Furnace (Bituminous

Coal)	

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Spreader Stoker (Bituminous

Coal)	

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Traveling Grate (Overfeed)

Stoker (Bituminous Coal)	

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Wet Bottom (Tangential)

(Bituminous Coal)	

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

	(Tangential) (Bituminous Coal)	

10100215 External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Cell Burner (Bituminous Coal)
1 m nn? 17 External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed
	Combustion: Bubbling Bed (Bituminous Coal)	

10100201

10100202

10100203

10100204

10100205

10100211

10100212

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed

Combustion: Circulating Bed (Bitum. Coal)	

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Wet Bottom

(Subbituminous Coal)	

1 m nn??? External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom
	(Subbituminous Coal)	

10100218

10100221

10100223

10100224

10100225

10100226

10100235

10100237

10100238

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Cyclone Furnace

(Subbituminous Coal)	

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Spreader Stoker

(Subbituminous Coal)	

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Traveling Grate (Overfeed)

Stoker (Subbituminous Coal)	

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

Tangential (Subbituminous Coal)	

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Cell Burner (Subbituminous

Coal)	

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed

Combustion: Bubbling Bed (Subbitum Coal)	

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed
Combustion - Circulating Bed (Subbitum Coal)	

3.1.1.1 Capital Cost Equations

The capital cost associated with these ptipm SO2 control measures is a straightforward
calculation of the capital cost multiplier, the unit's boiler capacity (in MW), and the scaling
factor exponent.

27


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Control Strategy Tool (CoST) Cost Equations

Scaling Factor =

¦Scaling Factor Model Size\Scaling Factor Exponent

)

Capacity

Where:

Scaling Factor Model Size = the boiler capacity (MW) of the model plant
Scaling Factor Exponent = an empirical value based on the specific control measure
Capacity = the boiler capacity (MW) obtained from the emissions inventory

Capital Cost = Capital Cost Multiplier x Capacity x Scaling Factor x 1,000

Where:

Capital Cost Multiplier ($/kW) = an empirical value based on the specific control measure
Capacity QAW) = obtained from the emissions inventory

1000= conversion factor to convert the Capital Cost Multiplier from $/kW to $/MW.

Where:

Interest Rate = annual interest rate

Equipment Life = expected economic life of the control equipment

Annualized Capital Cost = Capital Cost x Capital Recovery Factor

Where the Capital Cost and the Capital Recovery Factor have been calculated previously.

3.1.1.2 Operation and Maintenance Cost Equations

The fixed O&M component is based on the unit's capacity. The variable O&M includes an
estimate for the unit's capacity factor. This factor is the unit's efficiency rating based on existing
utilization and operation. A value of 1.00 would represent a completely efficient operation with
no losses of production due to heat loss or other factors. Where appropriate, CoST provides a
list of precalculated capacity factor calculations ranging from 65% to 85% (0.65 to 0.85).

The annualized cost is then estimated using the unit's capital cost times the CRF (derived with
the equipment specific interest rate and lifetime expectancy) and the sum of the fixed and
variable O&M costs.

Fixed 0&.M = Fixed 0&.M Cost Multiplier x Capacity x 1,000
Where:

Fixed O&M Cost Multiplier = an empirical value based on the specific control measure
Capacity = obtained from the emissions inventory

1000 = a conversion factor to convert the Fixed O&M Cost Multiplier from $/kW to $/MW
Variable O&M = Variable O&M Cost Multiplier x Capacity x Capacity Factor x 8,760

Capital Recovery Factor =

Interest Rate x (1 + Interest Rate^EctulPment Llfe

(1 + Interest Rate)EiuivmentLife - 1

28


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Control Strategy Tool (CoST) Cost Equations

Where:

Variable O&M Cost Multiplier ($/MW-h) = an empirical value based on the specific control
measure

Capacity Factor = an empirical value based on the specific control measure

Capacity (MW) = obtained from the emissions inventory

8760 = the number of hours the equipment is assumed to operate a year

O&M Cost = Fixed O&M + Variable O&M
3.1.1.3 Total Annualized Cost Equation

Total Annualized Cost = Annualized Capital Cost + O&M Cost

Where the Annualized Capital Cost and the O&M Cost were calculated previously.

3.1.2 Equation Type 1 Example for SO2

This section provides example calculations for an application of Equation Type 1 where SChis
the primary pollutant for this control technology. The example is for a utility boiler with medium
sulfur content in its feedstock (i.e., %S<=2%), and a flue gas desulfurization wet scrubber for its
control equipment.

3.1.2.1 Example Equation Variables

The following values are read from Tables B-3 and B-4 and are shown in Figure 3-1.

Interest Rate = 7%

Equipment Life = 15 years (from summary tab of control measure data)

Capacity = 160.6 MW

Scaling Factor Model Size = 500

Scaling Factor Exponent = 0.6

Capital Cost Multiplier =149 $/kW

Fixed O&M Cost Multiplier = 5.40 $/kW

Variable O&M Cost Multiplier = 0.83 $/MWh

Capacity Factor = 0.65

Year for Cost Basis = 1990

29


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Control Strategy Tool (CoST) Cost Equations

£

Figure 3-1: Equation Type 1 Example Screenshot for SO2

Hi

View Control Measure: FGD Wet Scrubber; Utility Boilers - Medium Sulfur Content

~ Ef

Summary Efficiencies SCCs Equations_ Properties References

Equation Type:

Name:	Type 1

Description: EGU

Inventory Fields: design_capacity, design_capacity_unit_numerator, design_capacity_unit_denominator

Equation:

Scaling Factor (SF) = (Model Plant boiler capacity/ MW)A (Scaling Factor Exponential)
Capital Cost= TCC x NETDC x SF x 1000 Fixed O&M Cost = OMF x NETDC x 1000
Variable O&M Cost= OMVx NETDC x 1 000 x CAPFAC x 8760 /1 000
CRF = I x (1 + I)A Eg. Life / [(1 + I) "¦ Eg. Life -1]	

Equation Type

Variable Name

Value

Type 1

Pollutant

S02

Type 1

Cost Year

1990

Type 1

Capital Cost Multiplier

149.0

Type 1

Fixed O&M Cost Multiplier

5.4

Type 1

Variable O&M Cost Multiplier

0.83

Type 1

Scaling Factor- Model Size (MW)

500.0

Type 1

Scaling Factor- Exponent

0.6

Type 1

Capacity Factor

0.65

Report

Close

3.1.2.2 Annualized Capital Cost

(Scaling Factor Model Size\Scalins Factor Exponent

Scaling Factor = -

\	Capacity

/500.0\°6

Scaling Factor = 	

V160.6/

Scaling Factor = 1.977

Capital Cost = Capital Cost Multiplier x Capacity x Scaling Factor x 1,000

$	kW

Capital Cost = 149 —— x 160.6 MW x 1.977 x 1,000——
K	kW	MW

Capital Cost = $47,300,582 (1990$)

Interest Rate x (1 + Interest Rate^EiulPment Llfe
Capital Recovery Factor =	(1 + ,nterest Ratey,uiPn,ent ufe . t	

0.07 X (1 + 0.07)15
Capital Recovery Factor = (-1 + QQ7ji5_1

30


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Control Strategy Tool (CoST) Cost Equations

Capital Recovery Factor = 0.109795

Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Annualized Capital Cost = $47,300,582 x 0.109795
Annualized Capital Cost = $5,193,367(1990$)

3.1.2.3 Operation and Maintenance Cost

$

Fixed O&M = Fixed O&M Cost Multiplier \ ~j^J x Capacity (^MW) x 1,000

$	kW

Fixed O&M = 5.40 -— x 160.6 MW x 1,000	

kW	MW

Fixed O&M = $867,240

Variable 0&.M = Variable 0&.M Cost Multiplier	x Capacity (MW) x Capacity Factor x

8,760 (Hours Per Year)

S

Variable O&M = 0.83 , x 160.6 MW x 0.65 x 8,760 Hours

MWh

Variable O&M = $758,998

O&M Cost = Fixed O&M + Variable O&M
O&M Cost = $867,240 + $758,998
O&M Cost = $1,626,238(1990$)

3.1.2.4 Total Annualized Cost

Total Annualized Cost = Annualized Capital Cost + O&M Cost
Total Annualized Cost = $5,193,367 + $1,626,238
Total Annualized Cost = $6,819,605 (1990$)

3.2 Non-IPM Sector (ptnonipm) SO2 Control Cost Equations

Ptnonipm point sources utilizing control cost equations for SO2 emission reductions are
represented by Equation Types 3 through 6, 11, 16, and 18 through 19. The equation types vary
by control measure. Each equation uses the source's stack flowrate (in ft3/min) as the primary
variable to estimate cost. For a select set of SO2 controls, boiler capacity (in mmBTU/hr) is used
to assign a default cost per ton reduced which is used to derive the unit's control cost. Cost
equations and default cost per ton reduced are taken from the original Alternative Control
Technology, Control Technology Guidelines (ACT/CTG), or other EPA analyses used to derive
these estimates. Table B-8 provides a list of the control cost equations assigned to various
ptnonipm control measures.

If the unit already has some SO2 control measure applied in the input inventory, incremental
controls are applied only if their control efficiency value exceeds that of the input control.

31


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Control Strategy Tool (CoST) Cost Equations

Control costs do not differ in these cases and the costs associated with incremental controls are
the same as those applied on uncontrolled sources.

An additional list of control measures are assigned to SO2 reductions but involve the application
of default cost per ton measures to estimate the costs assigned with each control measure. These
measures and their cost per ton reduced values (some based on boiler capacity size bins) are
presented in Table B-8. The controls that have cost per ton reduced values based on boiler
capacity size bins use Equation Type 11 to estimate costs (see Table B-14). A ratio of capital to
annual costs is applied to estimate the capital cost associated with the control. The O&M costs
are calculated by subtracting the capital cost x CRF from the total annualized cost.

Equations 16 and 18 were developed for the industrial, commercial, and institutional boilers and
processes heater NESHAP for major sources (Boiler MACT). Equation 19 was developed for the
commercial and industrial solid waste incinerator NESHAP (CISWI). The equations to calculate
flowrates for Equation Types 14 through 18 are provided in section 3.2.11. Error! Reference
source not found.Table B-15 lists the assumptions that are included in multiple Equation Types;
assumptions that are for one specific control are listed in its respective section.

3.2.1 Equation Type 3

Table 3-2 lists all of the Source Classification Codes (SCCs) for the sources associated with
Equation Type 3 and SO2 in the CoST CMDB.

	Table 3-2. SO2 Source Categories Associated with Equation Type 3	

SCC	Description	

10200101 External Combustion Boilers; Industrial; Anthracite Coal; Pulverized Coal	

10200104 External Combustion Boilers; Industrial; Anthracite Coal; Traveling Grate (Overfeed) Stoker	

10200107 External Combustion Boilers; Industrial; Anthracite Coal; Hand-fired	

10200201	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Pulverized Coal: Wet Bottom	

10200202	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom	

10200203	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Cyclone Furnace	

10200204	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Spreader Stoker	

10200205	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Overfeed Stoker	

10200206	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Underfeed Stoker	

10200210 External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Overfeed Stoker	

10200212	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom
	(Tangential)	

10200213	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Wet Slurry	

10200219 External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Cogeneration (Bituminous Coal)	

1 n?nn?91 External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Pulverized Coal: Wet Bottom

	(Subbituminous Coal)	

1 ronrm? External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom
	(Subbituminous Coal)	

10200223	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Cyclone Furnace (Subbituminous Coal)

10200224	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Spreader Stoker (Subbituminous Coal)
1 ronrms External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Traveling Grate (Overfeed) Stoker

	(Subbituminous Coal)	

1 ronrmfi External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom Tangential

	(Subbituminous Coal)	

10200229 External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Cogeneration (Subbituminous Coal)

10200300	External Combustion Boilers; Industrial; Lignite; Pulverized Coal: Wet Bottom	

10200301	External Combustion Boilers; Industrial; Lignite; Pulverized Coal: Dry Bottom, Wall Fired	

10200302	External Combustion Boilers; Industrial; Lignite; Pulverized Coal: Dry Bottom, Tangential Fired	

32


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Control Strategy Tool (CoST) Cost Equations

see

Description

10200303

External Combustion Boilers; Industrial; Lignite; Cyclone Furnace

10200304

External Combustion Boilers; Industrial; Lignite; Traveling Grate (Overfeed) Stoker

10200306

External Combustion Boilers; Industrial; Lignite; Spreader Stoker

10200307

External Combustion Boilers; Industrial; Lignite; Cogeneration

10200400

External Combustion Boilers; Industrial; Residual Oil; undefined

10200401

External Combustion Boilers; Industrial; Residual Oil; Grade 6 Oil

10200402

External Combustion Boilers; Industrial; Residual Oil; 10-100 Million Btu/hr

10200403

External Combustion Boilers; Industrial; Residual Oil; <10 Million Btu/hr

10200404

External Combustion Boilers; Industrial; Residual Oil; Grade 5 Oil

10200405

External Combustion Boilers; Industrial; Residual Oil; Cogeneration

10201403

External Combustion Boilers; Industrial; CO Boiler; Distillate Oil

10201404

External Combustion Boilers; Industrial; CO Boiler; Residual Oil

10300101

External Combustion Boilers; Commercial/Institutional; Anthracite Coal; Pulverized Coal

10300102

External Combustion Boilers; Commercial/Institutional; Anthracite Coal; Traveling Grate (Overfeed) Stoker

10300103

External Combustion Boilers; Commercial/Institutional; Anthracite Coal; Hand-fired

10300205

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Pulverized Coal: Wet

Bottom (Bituminous Coal)

10300206

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Pulverized Coal: Dry

Bottom (Bituminous Coal)

10300207

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Overfeed Stoker
(Bituminous Coal)

10300208

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Underfeed Stoker

(Bituminous Coal)

10300209

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Spreader Stoker
(Bituminous Coal)

10300211

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Overfeed Stoker

10300214

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Hand-fired (Bituminous

Coal)

10300216

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Pulverized Coal: Dry

Bottom (Tangential) (Bituminous Coal)

10300221

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Pulverized Coal: Wet

Bottom (Subbituminous Coal)

10300222

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Pulverized Coal: Dry

Bottom (Subbituminous Coal)

10300223

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Cyclone Furnace

(Subbituminous Coal)

10300224

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Spreader Stoker

(Subbituminous Coal)

10300225

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Traveling Grate

(Overfeed) Stoker (Subbituminous Coal)

10300226

External Combustion Boilers; Commercial/Institutional;Bituminous/Subbituminous Coal;Pulverized Coal: Dry

Bottom Tangential (Subbituminous Coal)

10300305

External Combustion Boilers; Commercial/Institutional; Lignite; Pulverized Coal: Dry Bottom, Wall Fired

10300306

External Combustion Boilers; Commercial/Institutional; Lignite; Pulverized Coal: Dry Bottom, Tangential Fired

10300307

External Combustion Boilers; Commercial/Institutional; Lignite; Traveling Grate (Overfeed) Stoker

10300309

External Combustion Boilers; Commercial/Institutional; Lignite; Spreader Stoker

10300400

External Combustion Boilers; Commercial/Institutional; Residual Oil; undefined

10300401

External Combustion Boilers; Commercial/Institutional; Residual Oil; Grade 6 Oil

10300402

External Combustion Boilers; Commercial/Institutional; Residual Oil; 10-100 Million Btu/hr

10300404

External Combustion Boilers; Commercial/Institutional; Residual Oil; Grade 5 Oil

30300101

Industrial Processes; Primary Metal Production; Aluminum Ore (Electro-reduction); Prebaked Reduction Cell

30300102

Industrial Processes; Primary Metal Production; Aluminum Ore (Electro-reduction); Horizontal Stud Soderberg Cell

30300103

Industrial Processes; Primary Metal Production; Aluminum Ore (Electro-reduction); Vertical Stud Soderberg Cell

30300105

Industrial Processes; Primary Metal Production; Aluminum Ore (Electro-reduction); Anode Baking Furnace

30300199

Industrial Processes; Primary Metal Production; Aluminum Ore (Electro-reduction); Not Classified

30300201

Industrial Processes; Primary Metal Production; Aluminum Hydroxide Calcining; Overall Process

30300306

Industrial Processes; Primary Metal Production; By-product Coke Manufacturing; Oven Underfiring

33


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Control Strategy Tool (CoST) Cost Equations

see

Description

Industrial Processes; Primary Metal Production; Iron Production (See 3-03-015 for Integrated Iron & Steel MACT);
Windbox

30300813

Industrial Processes; Primary Metal Production; Iron Production (See 3-03-015 for Integrated Iron & Steel MACT);
Cooler

30300817

Industrial Processes; Primary Metal Production; Iron Production (See 3-03-015 for Integrated Iron & Steel MACT);
Blast Heating Stoves	

30300824

Industrial Processes; Primary Metal Production; Iron Production (See 3-03-015 for Integrated Iron & Steel MACT);
Cast House

30300825

Industrial Processes; Primary Metal Production; Steel Manufacturing (See 3-03-015 for Integrated Iron & Steel
MACT); Open Hearth Furnace: Stack	

30300901

Industrial Processes; Primary Metal Production; Steel Manufacturing (See 3-03-015 for Integrated Iron & Steel
MACT); Electric Arc Furnace: Carbon Steel (Stack)	

30300908

Industrial Processes; Primary Metal Production; Steel Manufacturing (See 3-03-015 for Integrated Iron & Steel
MACT); Soaking Pits	

30300911

Industrial Processes; Primary Metal Production; Steel Manufacturing (See 3-03-015 for Integrated Iron & Steel
MACT); Hot Rolling	

30300931

Industrial Processes; Primary Metal Production; Steel Manufacturing (See 3-03-015 for Integrated Iron & Steel
MACT); Reheat Furnaces	

30300933

Industrial Processes; Primary Metal Production; Steel Manufacturing (See 3-03-015 for Integrated Iron & Steel
MACT); Other Not Classified

30300999

30301001

Industrial Processes; Primary Metal Production; Lead Production; Sintering: Single Stream

30301002

Industrial Processes; Primary Metal Production; Lead Production; Blast Furnace Operation

30301101

Industrial Processes; Primary Metal Production; Molybdenum; Mining: General

30301199

Industrial Processes; Primary Metal Production; Molybdenum; Other Not Classified

30301201

Industrial Processes; Primary Metal Production; Titanium; Chlorination

30303003

Industrial Processes; Primary Metal Production; Zinc Production; Sinter Strand

30399999

Industrial Processes; Primary Metal Production; Other Not Classified; Other Not Classified

30500606	Industrial Processes; Mineral Products; Cement Manufacturing (Dry Process); Kilns	

30500622	Industrial Processes; Mineral Products; Cement Manufacturing (Dry Process); Preheater Kiln	

30500706	Industrial Processes; Mineral Products; Cement Manufacturing (Wet Process); Kilns	

30500801	Industrial Processes; Mineral Products; Ceramic Clay/Tile Manufacture; Drying (use SCC 3-05-008-13)
30501001

Industrial Processes; Mineral Products; Coal Mining, Cleaning, and Material Handling (See 305310); Fluidized Bed
Industrial Processes; Mineral Products; Coal Mining, Cleaning, and Material Handling (See 305310); Truck

Loading: Overburden	

30501201 Industrial Processes; Mineral Products; Fiberglass Manufacturing; Regenerative Furnace (Wool-type Fiber)	

30501211 Industrial Processes; Mineral Products; Fiberglass Manufacturing; Regenerative Furnace (Textile-type Fiber)	

30501401	Industrial Processes; Mineral Products; Glass Manufacture; Furnace/General	

30501402	Industrial Processes; Mineral Products; Glass Manufacture; Container Glass: Melting Furnace	

30501403	Industrial Processes; Mineral Products; Glass Manufacture; Flat Glass: Melting Furnace	

30501404	Industrial Processes; Mineral Products; Glass Manufacture; Pressed and Blown Glass: Melting Furnace	

30501410 Industrial Processes; Mineral Products; Glass Manufacture; Raw Material Handling (All Types of Glass)	

30501499 Industrial Processes; Mineral Products; Glass Manufacture; See Comment	

30501602 Industrial Processes; Mineral Products; Lime Manufacture; Secondary Crushing/Screening	

30501037

30501604

Industrial Processes;
18,-19,-20,-21)

Mineral Products; Lime Manufacture; Calcining: Rotary Kiln ** (See SCC Codes 3-05-016-

30501905 Industrial Processes; Mineral Products; Phosphate Rock; Calcining

30502201 Industrial Processes; Mineral Products; Potash Production; Mine: Grinding/Drying

30502509

Industrial Processes;
Sand Coolers)

Mineral Products; Construction Sand and Gravel; Cooler ** (See 3-05-027-30 for Industrial

30600201	Industrial Processes; Petroleum Industry; Catalytic Cracking Units; Fluid Catalytic Cracking Unit	

30600402	Industrial Processes; Petroleum Industry; Blowdown Systems; Blowdown System w/o Controls	

30600503	Industrial Processes; Petroleum Industry; Wastewater Treatment; Process Drains and Wastewater Separators

30600902	Industrial Processes; Petroleum Industry; Flares; Residual Oil	

30601201	Industrial Processes; Petroleum Industry; Fluid Coking Units; General	

30700104

Industrial Processes;
Evaporator	

Pulp and Paper and Wood Products; Sulfate (Kraft) Pulping; Recovery Furnace/Direct Contact

30700110

Industrial Processes;
Contact Evaporator

Pulp and Paper and Wood Products; Sulfate (Kraft) Pulping; Recovery Furnace/Indirect

34


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Control Strategy Tool (CoST) Cost Equations

see

Description

31000401

Industrial Processes; Oil and Gas Production; Process Heaters; Distillate Oil (No. 2)

31000402

Industrial Processes; Oil and Gas Production; Process Heaters; Residual Oil

31000403

Industrial Processes; Oil and Gas Production; Process Heaters; Crude Oil

31000405

Industrial Processes; Oil and Gas Production; Process Heaters; Process Gas

31000411

Industrial Processes; Oil and Gas Production; Process Heaters; Distillate Oil (No. 2): Steam Generators

31000412

Industrial Processes; Oil and Gas Production; Process Heaters; Residual Oil: Steam Generators

31000413

Industrial Processes; Oil and Gas Production; Process Heaters; Crude Oil: Steam Generators

3.2.1.1 Annualized Capital Costs for Flowrate > 1,028,000 acfm

Capital Cost

= Retrofit Factor x Gas Flowrate Factor x Capital Cost Factor x STKFLOW x 60
Where:

Gas Flowrate Factor = 0.486 kW/acfm
Capital Cost Factor =$192/kW

STKFLOW = stack gas flowrate (ft3/s) from the emissions inventory
60 = conversion factor to convert acfs to acfm

Interest Rate x (1 + Interest Rate^EciulPment Llfe
Capital Recovery Factor =	[(l + lnterest Ratey
-------
Control Strategy Tool (CoST) Cost Equations

Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Where Capital Cost and Capital Reco very Factor we re calculated previously.

3.2.1.3	Operation and Maintenance Cost

Fixed O&M = Gas Flow Rate Factor x Fixed O&M Rate
Where:

Gas Flowrate Factor= 0.486 kW/acfm
Fixed O&M Rate = $6.9/kW-yr

Variable O&M

= Gas Flow Rate Factor x Variable O&M Cost Multiplier x Hours per Year
x STKFLOW

Where:

Gas Flowrate Factor= 0.486 kW/acfs
Variable O&M Cost Multiplier = $0.0015/kWh
Hours per Year= 8,736 hours

STKFLOW = stack gas flowrate (ft3/s) from the emissions inventory

0&.M Cost = Fixed 0&.M + Variable 0&.M

Where Fixed O&M and Variable O&M were calculated previously.

3.2.1.4	Total Annualized Cost

The following equation applies whether the annualized capital cost is calculated based on the
standard (<1,028,000 acfm) or large (>1,028,000 acfm) size:

Total Annualized Cost = Annualized Capital Cost + O&M Cost

Where Annualized Capital Cost and O&M Costweve calculated previously.

3.2.2 Equation Type 3 Example

This section provides example calculations for an application of Equation Type 3. The example
scenario is an industrial plant using FGD as the primary control technology for SO2. Information
for the equations in CoST is shown in Figure 3-2.

3.2.2.1 Example Equation Variables

Interest Rate = 7% per year
Equipment Life = 15 years
ft3

STKFLOW = 1682.7:^—
sec

36


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Control Strategy Tool (CoST) Cost Equations

Retrofit Factor =1.1
Gas Flow Rate Factor = 0.486 kW/acfm
Capital Cost Factor = $192/kW
Fixed O&M Rate = $6.90/kW-yr
Variable O&M Rate = $0.0015/kWh
Year for Cost Basis = 1995

z

Figure 3-2: Equation Type 3 Example Screenshot

View Control Measure: FGD; Bituminous Subbituminous Coal (Commercial/Institutional Boilers)



Summary^ Efficiencies f" SCCs [liquations ^ Properties | References

Equation Type:

Name:	Type 3

Description: Non-EGU S02
Inventory Fields: stack_flow_rate

Equation:

Capital Cost = Capital Cost factor x Gas Flow Rate factor x Retrofit fatorxMin. Stack flow rate Capital Cost =
((1028000/Min. stack flow rate)A0.6)x Capital Cost factor x Gas Flow Rate factor x Retrofit fator x Min. Stack Flow
rate

O&M Cost = (3.35 + (0.00729 x 8736)) x Min. stack flow rate x 0.9383	

Equation Type

Variable Name

Type 3

Pollutant

S02

Type 3

Report Close

3.2.2.2 Annualized Capital Costs for Flowrate < 1,028,000 acfm

Capital Cost

/1,028,000\

0.6

\Flowrate J
X STKFLOW X 60

x Retrofit Factor x Gas Flow Rate Factor x Capital Cost Factor

0.6

Capital Cost =

1,028,000

kW $192 	 ft3 sec



x 1.1 x 0.486—— x ——— x 1682.7-— x 60-

,1682.7^- X 60^.
sec min'

acfm kW

sec min

Capital Cost = $41,705,106 (1995$)

37


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Control Strategy Tool (CoST) Cost Equations

Interest Rate x (1 + Interest Rate~)EquivmentLl^e
Capital Recovery Factor =	[(1 + lnterest Rate)E,uipmeM u,e _ 1}	

flow rate. 07 x (1 + ,07)15

Capital Recovery Factor =	—	—-	;	

K	J	[(1 + .07)15 - 1]

Capital Recovery Factor =0.1098

Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Annualized Capital Cost = $41,705,106 x 0.1098
Annualized Capital Cost = $4,578,996 (1990$)

3.2.2.3	Operation and Maintenance Cost

Fixed O&M = Gas Flow Rate Factor x Fixed O&M Rate
Fixed O&M = 0.486 kW/acfm x $6.9/kW - yr
Fixed O&M = $3,354

Variable O&M

= Gas Flow Rate Factor x Variable O&M Cost Multiplier x Hours per Year
x STKFLOW

kW $0.0015	ft3 sec

Variable O&M = 0.486—- x ———— x 8,736 hours x 1682.7	 x 60——

acf kWh	sec min

Variable O&M = $642,980

O&M Cost = Fixed O&M + Variable O&M
0&.M Cost = $3,354 + $642,980
O&M Cost = $642,984 (1990$)

3.2.2.4	Total Annualized Cost

Total Annualized Cost = Annualized Capital Cost + O&M Cost
Total Annualized Cost = $4,578,803 + $642,983
Total Annualized Cost = $5,221,787 (1990$)

3.2.3 Equation Type 4

Equation Type 4 is applied to sulfuric acid plants. As shown in Table B-8 the sole control
technology is to increase the percent conversion to meet a predefined target. The SCCs for the
sources belonging to this type are listed in Table 3-3.

Table 3-3. SO2 Source Categories Associated with Equation Type 4

see

Description

30102306

Industrial Processes; Chemical Manufacturing; Sulfuric Acid (Contact Process); Absorber/@ 99.0% Conversion

30102308

Industrial Processes; Chemical Manufacturing; Sulfuric Acid (Contact Process); Absorber/@ 98.0% Conversion

30102310

Industrial Processes; Chemical Manufacturing; Sulfuric Acid (Contact Process); Absorber/@ 97.0% Conversion

38


-------
Control Strategy Tool (CoST) Cost Equations

see

Description

30102318

Industrial Processes; Chemical Manufacturing; Sulfuric Acid (Contact Process); Absorber/® 93.0% Conversion

30301001

Industrial Processes; Primary Metal Production; Lead Production; Sintering: Single Stream

30301006

Industrial Processes; Primary Metal Production; Lead Production; Sintering: Dual Stream Feed End

30301007

Industrial Processes; Primary Metal Production; Lead Production; Sintering: Dual Stream Discharge End

30301014

Industrial Processes; Primary Metal Production; Lead Production; Sintering Charge Mixing

30303002

Industrial Processes; Primary Metal Production; Zinc Production; Multiple Hearth Roaster

30303007

Industrial Processes; Primary Metal Production; Zinc Production; Flash Roaster

30303008

Industrial Processes; Primary Metal Production; Zinc Production; Fluid Bed Roaster

3.2.3.1	Annualized Capital Cost

Capital Cost = $990,000 + $9,836 X STKFLOW X 60
Where:

Fixed Capital Cost = $990,000
Scaled Capital Cost= $9,836

STKFLOW = stack gas flowrate (ft3/s) from the emissions inventory
60 = conversion factor to convert acfs to acfm

Interest Rate x (1 + Interest Rate^EciulPment Llfe
Capital Recovery Factor =	[C1 + lnterest Ratey^m ^	

Where:

Interest Rate = annual interest rate

Equipment Life = expected economic life of control equipment
Annualized Capital Cost = Capital Cost x Capital Recovery Factor

3.2.3.2	Operation and Maintenance Cost

Fixed 0&.M = $75,800
Where:

Fixed O&M Cost = $75,800 based on model plant data
Variable 0&.M = $12.82 x STKFLOW x 60
Where:

Variable O&M Cost Multiplier = $12.82 based on model plant data
STKFLOW = stack gas flowrate (ft3/s) from the emissions inventory
60= conversion factor to convert acfs to acfm

Total 0&.M = Fixed 0&.M + Variable 0&.M

3.2.3.3	Total Annualized Cost

Total Annualized Cost = Annualized Capital Cost + O&M Cost

39


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Control Strategy Tool (CoST) Cost Equations
3.2.4 Equation Type 4 Example

The CoST screenshot related to the Equation Type 4 example is shown in Figure 3-3.
3.2.4.1 Example Equation Variables

Interest Rate = 7%

Equipment Life =15 years (from summary tab of control measure data)
ft3

STKFLOW = 956.7-—
sec

Year for Cost Basis = 1990

Figure 3-3: Equation Type 4 Example Screenshot

3.2.4.2 Annualized Capital Cost

Capital Cost = $990,000 + $9,836 X STKFLOW X 60

ft3 sec

Capital Cost = $990,000 + $9.836/acfm x 956.7	 x 60——

sec TYiiyi

Capital Cost = $1,554,606 (1990$)

Interest Rate x (1 + Interest Rate)Eiulvment Llfe

Capital Recovery Factor =	—	——:		;	

H	7	[(1 + Interest Rate)E(iulPmentLlfe - 1]

40


-------
Control Strategy Tool (CoST) Cost Equations

0.07 X (1 + 0.07)15
Capital Recovery Factor = + Q 15 _

Capital Recovery Factor = 0.1098

Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Annualized Capital Cost = $1,554,606 x 0.1098
Annualized Capital Cost = $170,687 (1990$)

3.2.4.3	Operation and Maintenance Cost

Fixed 0&.M = $75,800

Variable 0&.M = $12.82 x STKFLOW x 60

ft^ sec

Variable 0&.M = $12.82/acfm x 956.7	 x 60	

sec min

Variable 0&.M = $735,893

Total 0&.M = Fixed 0&.M + Variable 0&.M
Total 0&.M = $75,800 + $735,894
Total 0&.M = $811,694 (1990$)

3.2.4.4	Total Annualized Cost

Total Annualized Cost = Annualized Capital Cost + 0&.M Cost
Total Annualized Cost = $170,687 + $811,694
Total Annualized Cost = $982,381(1990$)

3.2.5 Equation Type 5

Equation Type 5 is applied to chemical manufacturing related to elemental sulfur production. As
shown in Table B-8 the sole control technology is amine scrubbing. The SCCs for the sources
belonging to this type are listed in Table 3-4.

	Table 3-4. SO2 Source Categories Associated with Equation Type 5	

SCC	Description	

Industrial Processes; Chemical Manufacturing; Elemental Sulfur Production; Mod. Claus: 2 Stage w/o Control (92-

95%Removal)	

,nl	Industrial Processes; Chemical Manufacturing; Elemental Sulfur Production; Mod. Claus: 3 Stage w/o Control (95-

96% Rem0Val)	

Industrial Processes; Chemical Manufacturing; Elemental Sulfur Production; Mod. Claus: 4 Stage w/o Control (96-
91% Removal)	

3.2.5.1 Annualized Capital Cost

Capital Cost = Fixed Capital Cost + Scaled Capital Cost x STKFLOW x 60

Capital Cost = $2,882,540 + $244.74 X STKFLOW X 60

Where:

41


-------
Control Strategy Tool (CoST) Cost Equations

Fixed Capital Cost = $2,882,540
Scaled Capital Cost = $244.74

STKFLOW= stack gas flowrate (ft3/s) from the emissions inventory
60 = conversion factor to convert acfs to acfm

Interest Rate x (1 + Interest Rate)Equipment Llfe

Capital Recovery Factor =	—	——:		;	

H	7	[(1 + Interest Rate)EiulvmentLlfe - 1]

Where:

Interest Rate = annual interest rate

Equipment Life = expected economic life of the control equipment

Annualized Capital Cost = Capital Cost x Capital Recovery Factor

Where the Capital Cost and the Capital Recovery Factor were calculated previously.

3.2.5.2	Operation and Maintenance Cost
Fixed 0&.M = $749,170

Where:

$749,170 is the fixed O&M cost based on model plantdata

Variable 0&.M = $148.4 x STKFLOW x 60

Where:

Variable O&M Cost Multiplier = $148.4 based on model plant data and credit for recovered product
STKFLOW = stack gas flowrate (ft3/s) from the emissions inventory
60 = conversion factor to convert acfs to acfm

Total 0&.M = Fixed 0&.M + Variable 0&.M

Where the Fixed O&M and the Variable O&M were calculated previously.

3.2.5.3	Total Annualized Cost

Total Annualized Cost = Annualized Capital Cost + Total O&M

Where the Annualized Capital Cost and the Total O&M were calculated previously.

3.2.6 Equation Type 5 Example

This section provides example calculations for an application of Equation Type 5. The example
is an industrial process that produces elemental sulfur and requires SO2 control. Using Table B-8
the CoST code is SAMSCSRP95 and the control type being implemented is amine scrubbing.

42


-------
Control Strategy Tool (CoST) Cost Equations

3.2.6.1 Example Equation Variables

Interest Rate = 7%

Equipment Life = 15 years
ft3

STKFLOW = 541.6-—
sec

Year for Cost Basis = 1990

Figure 3-4: Equation Type 5 Example Screenshot

3.2.6.2 Annualized Capital Cost

Capital Cost = $2,882,540 + $244.74 X STKFLOW X 60

ft3 sec

Capital Cost = $2,882,540 + $244.74/acfm x 541.6	 x 60——

SCC	771171

Capital Cost = $10,835,611 (1990$)

Interest Rate x (1 + Interest Rate)Equipment Llfe

Capital Recovery Factor =	—	——:		;	

H	7	[(1 + Interest Rate)E(iulPmentLlfe - 1]

0.07 x (1 + 0.07)15
Capital Recovery Factor = + Q Qr^15 _

Capital Recovery Factor =0.1098

43


-------
Control Strategy Tool (CoST) Cost Equations

Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Annualized Capital Cost = $10,835,611 x 0.1098
Annualized Capital Cost = $1,189,750 (1990$)

3.2.6.3	Operation and Maintenance Cost

Fixed 0&.M = $749,170

Variable 0&.M = $148.4 x STKFLOW x 60

ft^ sec

Variable 0&.M = $148.4/ac/m x 541.6	 x 60	

sec min

Variable 0&.M = $4,822,406

Total 0&.M = Fixed 0&.M + Variable 0&.M
Total 0&.M = $749,170 + $4,822,406
Total 0&.M = $5,571,576 (1990$)

3.2.6.4	Total Annualized Cost

Total Annualized Cost = Annualized Capital Cost + Total 0&.M
Total Annualized Cost = $1,189,750 + $5,571,576
Total Annualized Cost = $6,761,326 (1990$)

3.2.7 Equation Type 6

Equation Type 6 is applied to primary metal production related to by-product coke
manufacturing. As shown in Table B-8 the sole control technology is coke oven gas
desulfurization. The sole SCC for sources belonging to this type is listed in Table 3-5.

	Table 3-5. SO2 Source Categories Associated with Equation Type 6	

SCC	Description	

30300306 Industrial Processes; Primary Metal Production; By-product Coke Manufacturing; Oven Underfiring

3.2.7.1 Annualized Capital Cost

Capital Cost = $3,449,803 + $135.86 X STKFLOW X 60
Where:

Fixed Capital Cost = $3,449,803

Scaled Capital Cost= $135.86 per acfm (developed from model plant data)

STKFLOW = stack gas flowrate (ft3/s) from the emissions inventory
60 = conversion factor to convert acfs to acfm

Interest Rate x (1 + Interest Rate^EciulPment Llfe
Capital Recovery Factor =	K1 + interest Ratey,utpmm, u,e _ 1}	

Where:

Interest Rate = annual interest rate

44


-------
Control Strategy Tool (CoST) Cost Equations

Equipment Life = expected economic life of the control equipment

Annualized Capital Cost = Capital Cost x Capital Recovery Factor

Where the Capital Cost and the Capital Recovery Factor were calculated previously.

3.2.7.2	Operation and Maintenance Cost
Fixed 0&.M = $797,667

Where:

Fixed O&M = $797,667 derived from model plant data

Variable 0&.M = $58.84 x STKFLOW

Where:

Variable O&M Cost Multiplier = $58.84 derived from model plantdata
STKFLOW= stack gas flowrate (ft3/s) from the emissions inventory

Total 0&.M = Fixed 0&.M + Variable 0&.M

3.2.7.3	Total Annualized Cost

Total Annualized Cost = Annualized Capital Cost + O&M Cost
3.2.8 Equation Type 6 Example

The CoST screenshot related to the Equation Type 6 example is shown in Figure 3-5. Relevant
data are found in Table B-8 for CoST abbreviation SCOGDCOP.

3.2.8.1 Example Equation Variables

Interest Rate = 7%

Equipment Life =15 years (from summary tab of control measure data)
ft3

STKFLOW = 5327.45 -—
sec

Year for Cost Basis = 1990

45


-------
Control Strategy Tool (CoST) Cost Equations

Figure 3-5. Equation Type 6 Example Screenshot

3.2.8.2	Annualized Capital Cost

Capital Cost = $3,449,803 + $135.86 X STKFLOW

ft^	SGC

Capital Cost = $3,449,803 + $135.86 x 5327.45	x 60 ——

SCC	TflVYl

Capital Cost = $46,877,044 (1990$)

Interest Rate x (1 + Interest Rate)Equipment Llfe

Capital Recovery Factor =	—	——:		;	

H	7	[(1 + Interest Rate)E(iulPmentLlfe - 1]

0.07 x (1 + 0.07)15
Capital Recovery Factor = + Q Q7^15 _

Capital Recovery Factor =0.1098

Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Annualized Capital Cost = $46,877,044 x 0.1098
Annualized Capital Cost = $5,147,099 (1990$)

3.2.8.3	Operation and Maintenance Cost

Fixed 0&.M = $797,667

Variable 0&.M = $58.84 x STKFLOW

46


-------
Control Strategy Tool (CoST) Cost Equations

ft^	SGC

Variable 0&.M = $58.84 x 5327.45-— x 60	

sec min

Variable 0&.M = $18,808,029

Total 0&.M = Fixed 0&.M + Variable 0&.M
Total 0&.M = $797,667 + $18,808,029
Total 0&.M = $19,605,696 (1990$)

3.2.8.4 Total Annualized Cost

Total Annualized Cost = Annualized Capital Cost + 0&.M Cost
Total Annualized Cost = $5,147,099 + $19,605,696
Total Annualized Cost = $24,752,705 (1990$)

3.2.9 Equation Type 11

The primary sources associated with Equation Type 11 are industrial external combustion
boilers. The list of source categories is provided in Table 3-6. Data on relevant SO2 controls are
listed in Table B-14.

	Table 3-6. SO2 Source Categories Associated with Equation Type 11	

SCC	Description	

10200201	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Pulverized Coal: Wet Bottom	

10200202	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom	

10200203	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Cyclone Furnace	

10200204	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Spreader Stoker	

10200205	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Overfeed Stoker	

10200206	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Underfeed Stoker	

10200210 External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Overfeed Stoker	

10200212	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom
	(Tangential)	

10200213	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Wet Slurry	

1 mom 17 External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed Combustion:

	Bubbling Bed (Bituminous Coal)	

1 n?nn? 1 s External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed Combustion:

Circulating Bed (Bitum. Coal)	

10200219 External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Cogeneration (Bituminous Coal)	

1 ronrm 1 External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Pulverized Coal: Wet Bottom

	(Subbituminous Coal)	

1 n?nn?9? External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom
	(Subbituminous Coal)	

10200223	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Cyclone Furnace (Subbituminous Coal)

10200224	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Spreader Stoker (Subbituminous Coal)
1 ronrms External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Traveling Grate (Overfeed) Stoker

	(Subbituminous Coal)	

1	External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom Tangential

	(Subbituminous Coal)	

10200229 External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Cogeneration (Subbituminous Coal)

10200301	External Combustion Boilers; Industrial; Lignite;Pulverized Coal: Dry Bottom, Wall Fired	

10200302	External Combustion Boilers; Industrial; Lignite;Pulverized Coal: Dry Bottom, Tangential Fired	

10200303	External Combustion Boilers; Industrial; Lignite; Cyclone Furnace	

10200304	External Combustion Boilers; Industrial; Lignite; Traveling Grate (Overfeed) Stoker	

10200306	External Combustion Boilers; Industrial; Lignite; Spreader Stoker	

10200307	External Combustion Boilers; Industrial; Lignite; Cogeneration	

47


-------
Control Strategy Tool (CoST) Cost Equations

see

Description

10200400

External Combustion Boilers; Industrial; Residual Oil; undefined

10200401

External Combustion Boilers; Industrial; Residual Oil; Grade 6 Oil

10200402

External Combustion Boilers; Industrial; Residual Oil; 10-100 Million Btu/hr

10200403

External Combustion Boilers; Industrial; Residual Oil; <10 Million Btu/hr

10200404

External Combustion Boilers; Industrial; Residual Oil; Grade 5 Oil

10200405

External Combustion Boilers; Industrial; Residual Oil; Cogeneration

10201404

External Combustion Boilers; Industrial; CO Boiler; Residual Oil

3.2.9.1	Total Annualized Cost

Total Annualized Cost = Emissions Reduction x Default Cost Per Ton
Where:

Emissions Reduction = calculated from emissions inventory and control efficiency
Default Cost per Ton = based on the specific control measure

3.2.9.2	Total Capital Cost

Capital Cost = Total Annualized Cost x Capital to Annual Ratio

Interest Rate x (1 + Interest Rate^EciulPment Llfe
Capital Recovery Factor =	[C1 + lnterest Ratey^m ^	

Where:

Interest Rate = annual interest rate

Equipment Life = expected economic life of the control equipment

Annualized Capital Cost = Capital Cost x Capital Recovery Factor

Where the Capital Cost and the Capital Recovery Factor were calculated previously.

3.2.9.3	Operation and Maintenance Cost

Total 0&.M = Total Annualized Cost — Annualized Capital Cost

Where the Total Annualized Cost and the Annualized Capital Cost were calculated previously.
3.2.10 Equation Type 11 Example

The CoST screenshot related to the Equation Type 11 example is shown in Figure 3-6. Relevant
data are found in Table B-14 for CoST abbreviation SSRTGSRP95.

3.2.10.1 Example Equation Variables

Interest Rate = 7%

Equipment Life =30 years (from summary tab of control measure data)

S02 Emissions Reductions = 68.7 tons

48


-------
Control Strategy Tool (CoST) Cost Equations

De fault Cost per Ton = 643 ($/ton)
Total Annualized Cost = 44,174
Capital to Annual Ratio = 0
Year for Cost Basis = 1990

Figure 3-6: Equation Type 11 Example Screenshot

View Control Measure: Sulfur Recovery anchor Tail Gas Treatment; Sulfur Recovery Plants - Elemental Sulfur (Claus... n* ' Bf

| Summary Efficiencies ( SCCs Equations Properties References

Row Limit 1100

Row Filter

Apply

$

T



$0(10



B
T3'

~
IT

Select

Pollutant

Locale

Effective Date Cost Year

CPT

Control Efficiency

Min Emis

Max

~

S02

1990

643.00

99.84

III

1 rows : 22 columns: 1 Selected [Filter: Hone, Sort: None]

View

Report

Close

3.2.10.2 Total Annualized Cost

Total Annualized Cost = Emissions Reduction x Default Cost Per Ton

$

Total Annualized Cost = 68.7 Tons S02 X 643	

Ton

Total Annualized Cost = $44,174 (1990$)

3.2.10.3 Total Capital Cost

Capital Cost = Total Annualized Cost x Capital to Annual Ratio
Capital Cost = $44,174 x 0
Capital Cost = $0

Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Annualized Capital Cost = $0 x Capital Recovery Factor
Annualized Capital Cost = $0

49


-------
Control Strategy Tool (CoST) Cost Equations

3.2.10.4 Operation and Maintenance Cost

Total 0&.M Cost = Total Annualized Cost — Annualized Capital Cost
Total 0&.M Cost = $44,174 — $0
Total 0&.M Cost = $44,174 (1990$)

3.2.11 ICI Boiler Control Equations Type 16 for SO2

These equations are used for wet scrubbers. This control technology provides extensive SO2
control (95%) and minimal PM reduction (50% to 94%).

The list of source categories is provided in Table 3-7.

Table 3-7. SO2 Source Categories Associated with Equation Type 16

SCC

Description

10100201

External Combustion Boilers; Electric Generation;
(Bituminous Coal)

Bituminous/Subbituminous Coal; Pulverized Coal: Wet Bottom

10100202

External Combustion Boilers; Electric Generation;
(Bituminous Coal)	

Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

10100204

External Combustion Boilers; Electric Generation;
Coal)	

Bituminous/Subbituminous Coal; Spreader Stoker (Bituminous

10100205

External Combustion Boilers; Electric Generation;
Stoker (Bituminous Coal)

Bituminous/Subbituminous Coal; Traveling Grate (Overfeed)

10100212

External Combustion Boilers; Electric Generation;
(Tangential) (Bituminous Coal)	

Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

10100217

External Combustion Boilers; Electric Generation;
Combustion: Bubbling Bed (Bituminous Coal)

Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed

10100218

External Combustion Boilers; Electric Generation;
Combustion: Circulating Bed (Bitum. Coal)

Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom
(Subbituminous Coal)	

10100222

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Spreader Stoker
(Subbituminous Coal)	

10100224

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

10100226

10100401

External Combustion Boilers

Electric Generation; Residual Oil; Grade 6 Oil: Normal Firing

10100404

External Combustion Boilers

Electric Generation; Residual Oil; Grade 6 Oil: Tangential Firing

10100501

External Combustion Boilers

Electric Generation; Distillate Oil; Grades 1 and 2 Oil

10100601

External Combustion Boilers

Electric Generation; Natural Gas; Boilers >100 Million Btu/hr except Tangential

10100602

External Combustion Boilers

Electric Generation; Natural Gas; Boilers <100 Million Btu/hr except Tangential

10100604

External Combustion Boilers

Electric Generation; Natural Gas; Tangentially Fired Units

10100701

External Combustion Boilers

Electric Generation; Process Gas; Boilers >100 Million Btu/hr

10100702

External Combustion Boilers

Electric Generation; Process Gas; Boilers <100 Million Btu/hr

10100703

External Combustion Boilers

Electric Generation; Process Gas; Petroleum Refinery Gas

10100801

External Combustion Boilers

Electric Generation; Petroleum Coke; All Boiler Sizes

10100902

External Combustion Boilers

Electric Generation; Wood/Bark Waste; Wood/Bark Fired Boiler

10100903

External Combustion Boilers
moisture)

Electric Generation; Wood/Bark Waste; Wood-fired Boiler - Wet Wood (>=20%

10100911

External Combustion Boilers

Electric Generation; Wood/Bark Waste; Stoker boilers

10101002

External Combustion Boilers

Electric Generation; Liquified Petroleum Gas (LPG); Propane

10101101

External Combustion Boilers

Electric Generation; Bagasse; All Boiler Sizes

10101201

External Combustion Boilers

Electric Generation; Solid Waste; Specify Waste Material in Comments

10101202

External Combustion Boilers

Electric Generation; Solid Waste; Refuse Derived Fuel

10101204

External Combustion Boilers

Electric Generation; Solid Waste; Tire Derived Fuel: Shredded

10101301

External Combustion Boilers

Electric Generation; Liquid Waste; Specify Waste Material in Comments

10101302

External Combustion Boilers; Electric Generation; Liquid Waste; Waste Oil

50


-------
Control Strategy Tool (CoST) Cost Equations

see

Description

10200101 External Combustion Boilers; Industrial; Anthracite Coal; Pulverized Coal

10200202 External Combustion Boilers; Industrial; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

10200204 External Combustion Boilers; Industrial

Bituminous/Subbituminous Coal; Spreader Stoker

10200205 External Combustion Boilers; Industrial

Bituminous/Subbituminous Coal; Overfeed Stoker

10200218

External Combustion Boilers; Industrial
Circulating Bed (Bitum. Coal)	

Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed Combustion:

10200224 External Combustion Boilers; Industrial

Bituminous/Subbituminous Coal; Spreader Stoker (Subbituminous Coal)

10200225

External Combustion Boilers; Industrial
(Subbituminous Coal)	

Bituminous/Subbituminous Coal; Traveling Grate (Overfeed) Stoker

10200401 External Combustion Boilers; Industrial

Residual Oil; Grade 6 Oil

10200402 External Combustion Boilers; Industrial

Residual Oil; 10-100 Million Btu/hr

10200404 External Combustion Boilers; Industrial

Residual Oil; Grade 5 Oil

10200501 External Combustion Boilers; Industrial

Distillate Oil; Grades 1 and 2 Oil

10200502 External Combustion Boilers; Industrial

Distillate Oil

10-100 Million Btu/hr

10200503 External Combustion Boilers; Industrial

Distillate Oil

<10 Million Btu/hr

10200504 External Combustion Boilers; Industrial

Distillate Oil; Grade 4 Oil

10200505 External Combustion Boilers; Industrial

Distillate Oil; Cogeneration

10200601 External Combustion Boilers; Industrial

Natural Gas; >100 Million Btu/hr

10200602 External Combustion Boilers; Industrial

Natural Gas; 10-100 Million Btu/hr

10200603 External Combustion Boilers; Industrial

Natural Gas; <10 Million Btu/hr

10200604 External Combustion Boilers; Industrial

Natural Gas; Cogeneration

10200701 External Combustion Boilers; Industrial

Process Gas; Petroleum Refinery Gas

10200704 External Combustion Boilers; Industrial

Process Gas; Blast Furnace Gas

10200707 External Combustion Boilers; Industrial

Process Gas; Coke Oven Gas

10200710 External Combustion Boilers; Industrial

Process Gas; Cogeneration

10200711 External Combustion Boilers; Industrial

Process Gas; Landfill Gas

10200799 External Combustion Boilers; Industrial

Process Gas; Other: Specify in Comments

10200901 External Combustion Boilers; Industrial

Wood/Bark Waste; Bark-fired Boiler

10200902 External Combustion Boilers; Industrial

Wood/Bark Waste

Wood/Bark-fired Boiler

10200903 External Combustion Boilers; Industrial

Wood/Bark Waste

Wood-fired Boiler - Wet Wood (>=20% moisture)

10200905 External Combustion Boilers; Industrial

Wood/Bark Waste

Wood/Bark-fired Boiler (< 50,000 Lb Steam)

10200906 External Combustion Boilers; Industrial

Wood/Bark Waste

Wood-fired Boiler (< 50,000 Lb Steam)

10200907 External Combustion Boilers; Industrial

Wood/Bark Waste

Wood Cogeneration

10200908 External Combustion Boilers; Industrial

Wood/Bark Waste

Wood-fired Boiler - Dry Wood (<20% moisture)

10200910 External Combustion Boilers; Industrial

Wood/Bark Waste; Fuel cell/Dutch oven boilers

10200911 External Combustion Boilers; Industrial

Wood/Bark Waste; Stoker boilers

10201001 External Combustion Boilers; Industrial

Liquified Petroleum Gas (LPG); Butane

10201002 External Combustion Boilers; Industrial

Liquified Petroleum Gas (LPG); Propane

10201201 External Combustion Boilers; Industrial

Solid Waste; Specify Waste Material in Comments

10201301 External Combustion Boilers; Industrial

Liquid Waste; Specify Waste Material in Comments

10201302 External Combustion Boilers; Industrial

Liquid Waste; Waste Oil

10201303 External Combustion Boilers; Industrial

Liquid Waste; Salable Animal Fat

10201401 External Combustion Boilers; Industrial

CO Boiler; Natural Gas

10201403 External Combustion Boilers; Industrial; CO Boiler; Distillate Oil

10300206

10300208

External Combustion Boilers; Commercial/Institutional; Bituminous/Subbituminous Coal; Pulverized Coal: Dry
Bottom (Bituminous Coal)	

External Combustion Boilers; Commercial/Institutional;
(Bituminous Coal)

Bituminous/Subbituminous Coal; Underfeed Stoker

10300209

External Combustion Boilers; Commercial/Institutional;
(Bituminous Coal)	

Bituminous/Subbituminous Coal; Spreader Stoker

10300214

External Combustion Boilers; Commercial/Institutional;
Coal)	

Bituminous/Subbituminous Coal; Hand-fired (Bituminous

10300217

External Combustion Boilers; Commercial/Institutional;
Bed Combustion: Bubbling Bed (Bituminous Coal)

Bituminous/Subbituminous Coal; Atmospheric Fluidized

10300218

External Combustion Boilers; Commercial/Institutional;
Bed Combustion: Circulating Bed (Bitum. Coal)	

Bituminous/Subbituminous Coal; Atmospheric Fluidized

10300401 External Combustion Boilers; Commercial/Institutional; Residual Oil; Grade 6 Oil

51


-------
Control Strategy Tool (CoST) Cost Equations

SCC	Description	

10300402	External Combustion Boilers; Commercial/Institutional; Residual Oil; 10-100 Million Btu/hr	

10300404	External Combustion Boilers; Commercial/Institutional; Residual Oil; Grade 5 Oil	

10300501	External Combustion Boilers; Commercial/Institutional; Distillate Oil; Grades 1 and 2 Oil	

10300502	External Combustion Boilers; Commercial/Institutional; Distillate Oil; 10-100 Million Btu/hr	

10300503	External Combustion Boilers; Commercial/Institutional; Distillate Oil; < 10 Million Btu/hr	

10300504	External Combustion Boilers; Commercial/Institutional; Distillate Oil; Grade 4 Oil	

10300601	External Combustion Boilers; Commercial/Institutional; Natural Gas; >100 Million Btu/hr	

10300602	External Combustion Boilers; Commercial/Institutional; Natural Gas; 10-100 Million Btu/hr	

10300603	External Combustion Boilers; Commercial/Institutional; Natural Gas; <10 Million Btu/hr	

10300701	External Combustion Boilers; Commercial/Institutional; Process Gas; POTW Digester Gas-fired Boiler	

10300799	External Combustion Boilers; Commercial/Institutional; Process Gas; Other Not Classified	

10300811	External Combustion Boilers; Commercial/Institutional; Landfill Gas; Landfill Gas	

10300902	External Combustion Boilers; Commercial/Institutional; Wood/Bark Waste; Wood/Bark-fired Boiler	

1 mnnom	External Combustion Boilers; Commercial/Institutional; Wood/Bark Waste; Wood-fired Boiler - Wet Wood

(>=20% moisture)	

10300911	External Combustion Boilers; Commercial/Institutional; Wood/Bark Waste; Stoker boilers	

10300912	External Combustion Boilers; Commercial/Institutional; Wood/Bark Waste; Fluidized bed combustion boilers

10301001	External Combustion Boilers; Commercial/Institutional; Liquified Petroleum Gas (LPG); Butane	

10301002	External Combustion Boilers; Commercial/Institutional; Liquified Petroleum Gas (LPG); Propane	

i mm nm	External Combustion Boilers; Commercial/Institutional; Liquified Petroleum Gas (LPG); Butane/Propane Mixture:
	Specify Percent Butane in Comments	

10301201	External Combustion Boilers; Commercial/Institutional; Solid Waste; Specify Waste Material in Comments	

10301202	External Combustion Boilers; Commercial/Institutional; Solid Waste; Refuse Derived Fuel	

10500105	External Combustion Boilers; Space Heaters; Industrial; Distillate Oil	

10500106	External Combustion Boilers; Space Heaters; Industrial; Natural Gas	

10500205	External Combustion Boilers; Space Heaters; Commercial/Institutional; Distillate Oil	

10500206	External Combustion Boilers; Space Heaters; Commercial/Institutional; Natural Gas	

30130201	Industrial Processes; Chemical Manufacturing; Carbon Tetrachloride; General	

30290001	Industrial Processes; Food and Agriculture; Fuel Fired Equipment; Distillate Oil (No. 2): Process Heaters	

30290003	Industrial Processes; Food and Agriculture; Fuel Fired Equipment; Natural Gas: Process Heaters	

30500105	Industrial Processes; Mineral Products; Asphalt Roofing Manufacture; General	

30500199	Industrial Processes; Mineral Products; Asphalt Roofing Manufacture; See Comment	

.......	Industrial Processes; Mineral Products; Coal Mining, Cleaning, and Material Handling (See 305310); Overburden

^ V_/ w/ V_/ ± ±	-T-v	1

	Removal	

30699999	Industrial Processes; Petroleum Industry; Petroleum Products - Not Classified; Not Classified	

31000203	Industrial Processes; Oil and Gas Production; Natural Gas Production; Compressors	

31000414	Industrial Processes; Oil and Gas Production; Process Heaters; Natural Gas: Steam Generators	

31100199	Industrial Processes; Building Construction; Construction: Building Contractors; Other Not Classified	

39999999	Industrial Processes; Miscellaneous Manufacturing Industries; Miscellaneous Industrial Processes; Other Not
Classified

The equations that are used to calculate flowrates for Equation Types 14 through 18 are provided
here. The two equations calculate flowrate in actual cubic feet per minute (acfm) and dry
standard cubic feet per minute (dscfm), respectively.

^ (VExhaust) (DC)

60

Exhaust flowrate (acfm)

Relative exhaust volume (ACF/MMBtu)
Design capacity of unit (MMBtu/hr)
Conversion factor hour to minutes

Where:

Fa

V Exhaust —
DC

60

52


-------
Control Strategy Tool (CoST) Cost Equations

J7 fT7 ^ /"^O ^
Fd ~ (Fa) ^ 460 + T



%Moist^

100 J

Where:
Fd

Fa
T

%Moist

=	Exhaust flowrate (dscfm)

=	Exhaust flowrate (acfm)

=	Assumed stack gas temperature (°F)

=	Assumed stack gas moisture content

Table B-16 lists the assumptions that were used in constructing more than one of the cost
equations for Equation Types 14 - 19. Assumptions that are specifically for Equations Type 16
are listed in Table B-17.

3.2.11.1 Total Capital Investment

TCI = [(2.88) (#5 crub) (Fa)] + [(1076.54)(#Scrub)JTa\ + [(9.759)(Fa)] + [(360.463)^]

Where:
#Scrub

if Fa < 149602, then #Scrub = 1
if 149602 < Fa < 224403, then #Scrub = 2
if 244403 < Fa < 299204, then #Scrub = 3
if 299204 < Fa < 374005, then #Scrub = 4
if Fa > 374005, then #Scrub = 5
Exhaust flowrate (acfm)

3.2.11.2 Total Annualized Costs

TAC

Scrub) (TCI)



(0(1 + i)E(,Life

V(1 + i)Eqiife - ly

+ [(0.04) (TCI)]

+ |(20.014) (#5 crub) (Fa) (OpHrs)
+ [(16.147 )(#Scrub)(OpHrs)]

Cs02 (Q

sol)

100 - 98

100- (98)(C502)

+ \ (1.17E - 5) (Fa) (OpHrs) (#Scrub)
+ [(1.33E - 5)(OpHrs)(#Scrub)(Fa)]

(™oy

1.18 '

+ (6.895)

Where:
#Scrub

TCI
i

if Fa < 149602, then #Scrub = 1
if 149602 < Fa < 224403, then #Scrub = 2
if 244403 < Fa < 299204, then #Scrub = 3
if 299204 < Fa < 374005, then #Scrub = 4
if Fa > 374005, then #Scrub = 5
Total Capital Investment ($)

Annual interest rate expressed as a fraction (i.e., percentage divided by 100)

53


-------
Control Strategy Tool (CoST) Cost Equations

Equfe =	Estimated equipment life (years)

Fa	=	Exhaust flowrate (acfm)

Cso2	=	Mole fraction of SO2 in exhaust gas

OpHrs	=	Annual operating hours of unit (hours per year)

3.2.12 ICI Boiler Control Equations Type 16 Example for SO2

This section provides example calculations for an application of Equation Type 16. The example
is a coal-fired ICI boiler with a wet scrubber for SO2 control. The values for some of the
parameters used in this equation type are shown in Tables B-16 and B-17.

Figure 3-7 illustrates the Equations tab of the View Control Measure screen for the Wet
Scrubber: ICI Boilers (Coal) emissions control device for SO2.

Figure 3-7: Equation Type 16 Example Screenshot

View Control Measure: Wet Scrubber, ICI Boilers (Coal)

Ef 13

Summary Efficiencies SCCs [ Equations I Properties References

Equation Type:

Name: Type 16
Description: Wet Scrubber Cost Equations
Inventory Fields: design_capacrty, design_capacrty_units, stkflow, stktemp, annual_avg_hours_per_year

Equations:

Equation Type

Variable Name

Value

Type 16

Pollutant

S02

Type 16

Cost Year

2008

Report

Close

3.2.12.1 Example Equation Variables

#Scrub = 1

/' = 0.07 (interest rate 7°A
Equfe =15 years

Fa = 55493 actual cubic feet per minute
Cso2= 1.15E-3 mole fraction SO2 in exhaust gas
OpHrs = 2688 operating hours per year
Year for Cost Basis = 2008

54


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Control Strategy Tool (CoST) Cost Equations

3.2.12.2	Total Capital Investment

TCI = [(2.88) (#5 crub) (Fa)] + [(1076.54)(#ScriiZ0V^] + [(9.759)(Fa)] + [(360.463)^]
= [(2.88) (1) (5 5493)] + [(1076.54)(1)V55493] + [(9.759) (5 5493)] + [(360.463)V55493]
= $1,039,890

3.2.12.3	Total Annualized Costs

TAC

(#Scrub)(TCI)

f (Q(l + j)Eq"f° N
V(1 + l)Eqiife - 1,

+ [(0.04) (TCI)]

+ j(20.014) (#S crub) (Fa) (OpHrs)
+ [(16.147 )(#Scrub)(OpHrs)]

C,

SO 2

(Csoi) ^

100 - 98

100- (98)(C502)

+ \ (1.17E - 5) (Fa) (OpHrs) (#Scrub)
+

1.18

(479.85)

(1.33E - 5)(OpHrs)(#Scrub)(Fa)]
(1)($1,309,890)

((0.07)(1 + 0.07)15n
\ (1 + 0.07)15 — 1 ,

y/KJ

+ [(0.04) ($1,309,890)]

+ (6.895)

+ |(20.014)(1) (55493) (2688)
+ [(16.147)(1)(2688)]

(1.15E - 3) - (1.15E

-3)(

100-98

100 - (98)(1.15£ - 3)/]

+ |(1.17F - 5)(55493)(2688)(1)

+ [(1.33£ - 5)(2688)(1)(55493)]
= $217,891

(479'85) (vlSff)1")+ (6'

(6.895)

3.2.13 ICI Boiler Control Equations Type 18 for SO2

These equations are used for increased caustic injection rate for existing dry injection control.
Therefore, no new capital investment is required. Two assumptions specific to increased caustic
injection systems were included when constructing these equations (Table B-19). The list of
source categories is provided in Table 3-7.

3.2.13.1	Total Capital Investment

TCI = 0

No variables are used in this calculation.

3.2.13.2	Total Annualized Costs

TAC = (3.87E - 6)(CS02)(Fd)(0pHrs)

55


-------
Control Strategy Tool (CoST) Cost Equations

Where:

Cso2 = Concentration of S02 in stack gas, dry parts per million by volume (ppmvd)

Fd = Exhaust flowrate (dscfm)

OpHrs = Annual operating hours of the unit (hrs/yr)

3.2.14 ICI Boiler Control Equations Type 18 Example for SO 2

This section provides example calculations for an application of Equation Type 18. The example
is an ICI boiler burning residual oil with an increased caustic injection rate for SO2 control. The
values for some of the parameters used in this equation type are shown in Tables B-16 and B-19.

3.2.14.1 Example Equation Variables

Cso2 = dry parts per million by volume (ppmvd)

Fd = dry standard cubic feet per minute (dscfm)

OpHrs = 8424 operating hours per year
Year for Cost Basis = 2008

Note that for the Boiler MACT rulemaking, sources that responded to the survey reported
average annual operating hours for the relevant combustion units. For facilities that did not
report annual operating hours, it was assumed that the unit was in operation for 8424 hours per
year, reflecting two weeks of boiler down time per year.

Figure 3-8 illustrates the Equations tab of the View Control Measure screen for the Increased
Caustic Injection Rate emissions control method for SO2.

56


-------
Control Strategy Tool (CoST) Cost Equations

Figure 3-8: Equation Type 18 Example Screenshot

1 View Control Measure: Increased Caustic Injection Rate for Existing Dry Injection Control; ICI Boilers (Residual Oil) v? 0





Summary Efficiencies SCCs [ Equations f Properties References

Equation Type:

Name: Type 18

Description: Increased Caustic Injection Rate for Existing Dry Injection Control Cost Equations
Inventory Fields: design_capacity, design_capacity_units, stkflow, stktemp, annual_avg_hours_per_year



Equations:











Equation Type

Variable Name

Value

Type 18

Pollutant

S02

Type 18

Cost Year

2008

Type 18

Stack Gas Moisture Content, %

9.08





Report Close

3.2.14.2	Total Capital Investment

TCI = $0

3.2.14.3	Total Annualized Costs

TAC = (3.87E - 6XCS02XFdX0pHrs)

= (3.87£-6)(C502)(Fd)(8424)

= (3.26F-2)(C502)(Fd)

3.2.15 ICI Boiler Control Equations Type 19 for SO2

These equations are for spray dryer absorbers. This control technology, which provides less-
than-extensive SO2 control (80%) and no reduction in PM, was used for the CISWI rule. The list
of source categories is provided in Table 3-7.

57


-------
Control Strategy Tool (CoST) Cost Equations

3.2.15.1 Total Capital Investment

TCI

= [(14376)(W] + [(0.610)(A)

+ (17412.26)e

(0.017)

Where:
Fd

Exhaust flowrate (dscfm)

Exhaust flowrate (acfm)

if Fd< 154042, then #Ducts = 1

if Fd > 154042, then #Ducts = Fd/154042

#Ducts

3.2.15.2 Total Annualized Costs

TAC

= (OpHrs){[(1.62E - 3)(Fd)] + [(6.84E - 7)(CS02)(Fd)] + [(3.72E - 5)(FJ] + (21.157)}

OpHrs = Annual operating hours of unit (hrs/yr)

Cso2 = Concentration of S02 in stack gas (dry parts per million by volume [ppmvd])
TCI = Total Capital Investment ($)

Equfe = Estimated equipment life (yrs)

3.2.16 ICI Boiler Control Equations Type 19 Example for SO2

This example is for addition of a spray dryer absorber onto one of the source categories listed in
Table 3-7.

3.2.16.1 Example Equation Variables

Fd = 32138 dry standard cubic feet per minute (dscfm)

Fa = 55493 actual cubic feet per minute (cfm)

#Ducts = 1

Cso2 =1.15 dry parts per million by volume (ppmvd)

OpHrs = 2688 operating hours per year
i = 0.07 annual interest rate
Equfe =15 years

Where:

Fd = Exhaust flowrate (dscfm)
Fa = Exhaust flowrate (acfm)

annual interest rate

58


-------
Control Strategy Tool (CoST) Cost Equations
Year for Cost Basis = 2008

Figure 3-9 illustrates the View Control Measure screen for the Spray Dryer Absorber emissions
control method for SO2.

Figure 3-9: Equation Type 19 Example Screenshot

View Control Measure: Spray Dryer Absorber, ICI Boilers (Gaseous Fuels) d" ~" 0





Summary Efficiencies SCCs f Equations ( Properties References

Equation Type:

Name: Type 19
Description: Spray Dryer Absorber Cost Equations
Inventory Fields: design_capacity, design_capacity_units, stkflow, stktemp, annual_avg_hours_per_year



Equations:











Equation Type

Variable Name

Value

Type 19

Pollutant

S02

Type 19

CostYear

2008

Type 19

Stack Gas Moisture Content, %

16.42





Report Cjose

3.2.16.2 Total Capital Investment

TCI

= [(143.76)(Fd)] +

(0.610)

V5_\2-

+

+

(53.973)eC0'014)^#Du"ts

#Ducts J
+ (931911.04)

(17412.26)eC0'017)^#Du"ts

= [(143.76) (32138)] +

(yj55493

/V55493X
(0.610) 	;	I

+

(53.973)e

(0.014)

V 1 /
+ (931911.04)

21 r	(0.017)f^pl

+ (17412.26)e V 1

= $6,542,689

59


-------
Control Strategy Tool (CoST) Cost Equations

3.2.16.3 Total Annualized Costs

TAC

+

= (OpHrs){[(1.62E - 3)(Fd)] + [(6.84E - 7)(CS02)(Fd)] + [(3.72E - 5)(FJ] + (21.157)}
(7.2g-2)+((^1.):;^;)](rC,))

= (2688){[(1.62£" - 3)(32138)] + [(6.84E - 7)(1.15)(32138)] + [(3.72£ - 5)(55493)]

/(0.07)(1 + 0.07)15\1	)

(7.2E - 2) +	, ($6,542,689)

+ (21.157)} +
= $1,391,860

(1 + 0.07)15 — 1

60


-------
Control Strategy Tool (CoST) Cost Equations

4 PM Control Cost Equations

This section is divided into two main sections - IPM and non-IPM sources. The types of cost
equations for point source PM controls are described in their appropriate sections.

•	Equation type 8 for IPM fabric filter (mechanical shaker, pulse jet, reverse air), ESP
(wire plate type)

•	Equation type 9 for IPM fabric filter (mechanical shaker)

•	Equation type 10 for IPM upgrades to ESPs

•	Equation type 8 for non-IPM watering, substitute for burning, ESP, catalytic
oxidizers, fabric filter, venture scrubber

•	Equation type 14 for non-IPM fabric filter

•	Equation type 15 for non-IPM ESP

•	Equation type 17 for non-IPM dry injection and fabric filter (DIFF)

Each equation type is discussed, the relevant parameters are presented, and example calculations
are provided. Appendix A includes the SQL queries that implement each CoST equation type.
Appendix B provides tables of parameters and values used with each equation type.

4.1 IPM Sector (ptipm) PM Control Cost Equations

Three types of equations are utilized in the control cost calculation for IPM sector PM controls.
Equation Type 8 uses the unit's stack flowrate (in acfm) as the primary variable for control cost
calculation. If a unit's stack flow is outside of a range of values (15,000 <= stack flowrate (cfm)
<= 1,400,000), then the control measure is not applied to the specific unit; instead a default cost
per ton value calculation is used. The second equation, Equation Type 9, is referenced in a
report prepared by EPA's Office of Research and Development (ORD). This equation also uses a
unit's stack flowrate (acfm) with capital and O&M cost factors. The third equation, Equation
Type 10, is used for control measures that are upgrades to existing ESPs.

If the unit already has PM controls applied in the emissions inventory, incremental controls are
applied only if their control efficiency value exceeds that of the input control. Control costs do
not differ in these cases and the costs associated with incremental controls are the same as those
applied on uncontrolled sources.

4.1.1 Equation Type 8

Equation Type 8 is applicable to many SCCs in the electric generation category (Table 4-1).
Table B-9 provides a list of the control cost equations assigned to various ptipm PM control
measures. The control efficiencies for both PMio and PM2.5 are provided in this table. Values are
representative of typical cost values and, although not provided as options in the CoST output,
low and high cost values are also available in the source tables.

Table B-9 also presents the default cost per ton values used when a unit's stack flowrate is
outside the recommended range of 15,000 - 1,400,000 cfm. Three variables are available for this

61


-------
Control Strategy Tool (CoST) Cost Equations

calculation; a capital cost multiplier, an O&M cost multiplier, and an annualized cost multiplier.
Equations for the cost method using the default cost per ton factors are not provided in this
document.

see

10100201

Table 4-1. PM Electric Generation Categories Associated with Equation Type 8
	Description	

External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Wet Bottom
(Bituminous Coal)

10100202

External Combustion Boilers; Electric Generation;
(Bituminous Coal)	

Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

10100203

External Combustion Boilers; Electric Generation;
Coal)	

Bituminous/Subbituminous Coal; Cyclone Furnace (Bituminous

10100204

External Combustion Boilers; Electric Generation;
Coal)

Bituminous/Subbituminous Coal; Spreader Stoker (Bituminous

10100205

External Combustion Boilers; Electric Generation;
Stoker (Bituminous Coal)	

Bituminous/Subbituminous Coal; Traveling Grate (Overfeed)

10100211

External Combustion Boilers; Electric Generation;
(Bituminous Coal)	

Bituminous/Subbituminous Coal; Wet Bottom (Tangential)

10100212

External Combustion Boilers; Electric Generation;
(Tangential) (Bituminous Coal)

Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

10100215 External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Cell Burner (Bituminous Coal)

10100217

External Combustion Boilers; Electric Generation;
Combustion: Bubbling Bed (Bituminous Coal)

Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed

10100218

External Combustion Boilers; Electric Generation;
Combustion: Circulating Bed (Bitum. Coal)	

Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed

10100221

External Combustion Boilers; Electric Generation;
(Subbituminous Coal)	

Bituminous/Subbituminous Coal; Pulverized Coal: Wet Bottom

10100222

External Combustion Boilers; Electric Generation;
(Subbituminous Coal)

Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

10100223

External Combustion Boilers; Electric Generation;
(Subbituminous Coal)	

Bituminous/Subbituminous Coal; Cyclone Furnace

10100224

External Combustion Boilers; Electric Generation;
(Subbituminous Coal)	

Bituminous/Subbituminous Coal; Spreader Stoker

10100225

External Combustion Boilers; Electric Generation;
Stoker (Subbituminous Coal)

Bituminous/Subbituminous Coal; Traveling Grate (Overfeed)

10100226

External Combustion Boilers; Electric Generation;
Tangential (Subbituminous Coal)	

Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

10100235

External Combustion Boilers; Electric Generation;
Coal)	

Bituminous/Subbituminous Coal; Cell Burner (Subbituminous

10100237

External Combustion Boilers; Electric Generation;
Combustion: Bubbling Bed (Subbitum Coal)

Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed

10100238

External Combustion Boilers; Electric Generation;
Combustion - Circulating Bed (Subbitum Coal)

Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed

10100300	External Combustion Boilers; Electric Generation; Lignite; Pulverized Coal: Wet Bottom	

10100301	External Combustion Boilers; Electric Generation; Lignite; Pulverized Coal: Dry Bottom, Wall Fired	

10100302	External Combustion Boilers; Electric Generation; Lignite; Pulverized Coal: Dry Bottom, Tangential Fired	

10100303	External Combustion Boilers; Electric Generation; Lignite; Cyclone Furnace	

10100304	External Combustion Boilers; Electric Generation; Lignite; Traveling Grate (Overfeed) Stoker	

10100306	External Combustion Boilers; Electric Generation; Lignite; Spreader Stoker	

10100316	External Combustion Boilers; Electric Generation; Lignite; Atmospheric Fluidized Bed	

10100317	External Combustion Boilers; Electric Generation; Lignite; Atmospheric Fluidized Bed Combustion - Bubbling Bed

10100318

External Combustion Boilers; Electric Generation; Lignite; Atmospheric Fluidized Bed Combustion - Circulating
Bed

10100401 External Combustion Boilers; Electric Generation; Residual Oil; Grade 6 Oil

Normal Firing

10100404 External Combustion Boilers; Electric Generation; Residual Oil; Grade 6 Oil

Tangential Firing

10100405 External Combustion Boilers; Electric Generation; Residual Oil; Grade 5 Oil

Normal Firing

10100406 External Combustion Boilers; Electric Generation; Residual Oil; Grade 5 Oil

Tangential Firing

62


-------
Control Strategy Tool (CoST) Cost Equations

4.1.1.1	Capital Cost Equations

Capital Cost = Typical Capital Cost x STKFLOW x 60
Where:

Typical Capital Cost = cost in $/acfm

STKFLOW = stack gas flowrate (ft3/s) from the emissions inventory
60 = unit conversion factor between seconds and minutes

Interest Rate x (1 + Interest Rate^EciulPment Llfe
Capital Recovery Factor =	(1 + ,nterest Ratey,ulpment ufe . t	

Where:

Interest Rate = annual interest rate

Equipment Life = expected economic life of the control equipment

Annualized Capital Cost = Capital Cost x Capital Recovery Factor

Where the Capital Cost and the Capital Recovery Factor were calculated previously.

4.1.1.2	Operation and Maintenance Cost Equation
0&.M Cost = Typical 0&.M Cost x STKFLOW x 60
Where:

Typical O&M Cost = cost in $/acfm

STKFLOW = stack gas flowrate (ft3/s) from the emissions inventory
60 = unit conversion factor between seconds and minutes

4.1.1.3	Total Annualized Cost Equation

Total Annualized Cost = Annualized Capital Cost + 0.04 x Capital Cost + O&M Cost

Where the Annualized Capital Cost, the Capital Cost, and the O&M Cost were calculated
previously.

4.1.2 Equation Type 8 Example for IPM Sector Sources

This section provides example calculations for a "typical" application (i.e., not a "default"
application) of Equation Type 8 to an EGU. The example scenario is a coal-burning utility boiler
using a fabric filter (mechanical shaker type) for PM control. Using Table B-9 the CoST code is
PFFMSUBC.

4.1.2.1 Variables for Example Equation Type 8 (ptipm)

Typical Capital Cost = $29/acfm
Typical O&M Cost = $11/acfm

63


-------
Control Strategy Tool (CoST) Cost Equations

Interest Rate = 7%

Equipment Life = 20 years (from summary tab of control measure data)

PMio Emissions Reductions =135 tons
STKFLOW = 283.69 ft3/sec
Year for Cost Basis = 1998

Figure 4-1: Equation Type 8 Example Screenshot for ptipm Source

View Control Measure: Fabric Filter (Mecti. Shaker Type); Utility Boilers - Coal

Ef M

Summary Efficiencies SCCs f Equations | Properties References

Equation Type:

Name:	Type 8

Description: Non-EGU PM
Inventory Fields: stack_flow_rate

Equation:

Capital Cost= Typical Capital CostxMin. Stack Flow Rate

O&M Cost= Typical O&M Costx Min. Stack Flow Rate

Total Cost = Capital Costx CRF + 0.04x capital cost + O&M Cost

Equation Type

Variable Name

Value

Type !

Pollutant

PM10

Type i

Cost Year

1998

Type i

Typical Capital Control Cost Factor

29.0

Type !

Typical O&M Control Cost Factor

11.0

Type !

Typical Default CPT Factor - Capital

412.0

Type !

Typical Default CPT Factor-O&M

62.0

Type i

Typical Default CPT Factor - Annualized

126.0

Report

Close

4.1.2.2 Capital Cost Equations

Capital Cost = Typical Capital Cost x STKFLOW x 60

ft^	S6C

Capital Cost = $29/acfm x 283.69^^— x 60	

sec min

Capital Cost = $493,621 (1998$)

Interest Rate X (1 + Interest Rate)Eqmpment Ll^e
Capital Recovery Factor = —

Capital Recovery Factor

i 1 + Interest Rate)Eciu^rrler,t ufe - 1

0.07 X (1 + 0.07)20
(1 + 0.07)20 - 1

64


-------
Control Strategy Tool (CoST) Cost Equations

Capital Recovery Factor = 0.094393

Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Annualized Capital Cost = $493,621 x 0.094393
Annualized Capital Cost = $46,594 (1998$)

4.1.2.3	Operation and Maintenance Cost Equation

0&.M Cost = Typical 0&.M Cost x STKFLOW x 60

ft^ sec

0&.M Cost = $ll/ac/m x 283.69	x 60——

SQC	771171

0&.M Cost = $187,235 ($1998)

4.1.2.4	Total Annualized Cost Equation

Total Annualized Cost = Annualized Capital Cost + 0.04 x Capital Cost + 0&.M Cost
Total Annualized Cost = $46,594 + 0.04 x $493,621 + $187,235
Total Annualized Cost = $253,575 (1998$)

4.1.3 Equation Type 9

Equation Type 9 applies to select SCCs in the electric generation category (Table 4-2). Table B-
12 supplies the capital and O&M factors associated with Equation Type 9. This equation type
does not appear to include any default cost per ton backup calculation in the event of stack
flowrates being outside of the acceptable range; however, note that a description of the control
measures utilizing this equation (Fabric Filter - Mechanical Shaker) is also represented in the
ptipm Equation Type 8 control measure list.

	Table 4-2. Electric Generation Categories Associated with Equation Type 9	

SCC	Description	

i m nmm External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Wet Bottom

	(Bituminous Coal)	

1 m nn?n? External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

(Bituminous Coal)	

10100203 External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Cyclone Furnace (Bituminous

	Coal)	

i m nm 17 External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

	(Tangential) (Bituminous Coal)	

1 m nn? 17 External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed

	Combustion: Bubbling Bed (Bituminous Coal)	

10100601 External Combustion Boilers; Electric Generation; Natural Gas; Boilers >100 Million Btu/hr except Tangential
10100604 External Combustion Boilers; Electric Generation; Natural Gas; Tangentially Fired Units	

Throughout this section note that the descriptions of the various parameters include the
abbreviations that are used in Table B-12. The complete parameter names were too long to fit in
the table's header.

65


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Control Strategy Tool (CoST) Cost Equations

4.1.3.1 Capital Cost Equations

Capital Cost

= [(Total Equipment Cost Factor x ST K FLOW) + Total Equipment Cost Constant]
x Equipment to Capital Cost Multiplier

Where:

Total Equipment Cost Factor (tecs) = based on the specific control measure
Total Equipment Cost Constant (teci) = based on the specific control measure
Capital Cost Multiplier (ec to cc) = based on the specific control measure
STKFLOW= stack gas flowrate (ft3/s) from the emissions inventory

Interest Rate x (1 + Interest Rate)EciulPment Llfe
Capital Recovery Factor =	(1 + ,nterest Ratey,ulpment ufe . t	

Where:

Interest Rate = annual interest rate

Equipment Life = expected economic life of the control equipment

Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Where Capital Cost and Capital Recovery Factor were calculated previously.

4.1.3.2	Operation and Maintenance Cost Equation

O&M Cost

= ^Electricity Factor x STKFLOW	+ Electricity Constant^

(	//t3\	\

+ I Dust Disposal Factor x STKFLOW I—— I + Dust Disposal Constant I

(	//t3 \

+ Baa Replacement Factor x STKFLOW —— + Baa Replacement Constant
\	\min J	/

Where:

Electricity Factor (els) = based on the specific control measure
Electricity Constant (eli) = based on the specific control measure
Dust Disposal Factor (dds) = based on the specific control measure
Dust Disposal Constant (ddi) = based on the specific control measure
Bag Replacement Factor (brs) = based on the specific control measure
Bag Replacement Constant (bri) = are control measure specific
STKFLOW = stack gas flowrate (ft3/s) from the emissions inventory

4.1.3.3	Total Annualized Cost Equation

Total Annualized Cost = Annualized Capital Cost + O&M Cost

66


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Control Strategy Tool (CoST) Cost Equations

Where the Annualized Capital Cost and the O&M Cost were calculated previously.
4.1.4 Equation Type 9 Example

This section provides example calculations for an application of Equation Type 9. The example
scenario is a coal-fired, utility boiler that requires PM control. The control technology is a fabric
filter with a mechanical shaker. Using Table B-12 the code is PFFMSUBC2 and the control
efficiency is 99% for both PMio and PM2.5. The values are shown in Figure 4-2.

4.1.4.1 Example Equation Variables

Total Equipment Cost Factor (tecs) = 5.7019

Total Equipment Cost Constant (teci) = 77489

Equipment to Capital Cost Multiplier (ec to cc) = 2.17

Electricity Factor (els) = 0.1941

Electricity Constant (eli) = -14.956

Dust Disposal Factor (dds) = 0.7406

Dust Disposal Constant (ddi) = 1.1461

Bag Replacement Factor (brs) = 0.2497

Bag Replacement Constant (bri) = 1220.7

Interest Rate = 7%

Equipment Life = 20 years (from summary tab of control measure data)

STKFLOW=16,354 ft3/min
Year for Cost Basis = 1990

67


-------
Control Strategy Tool (CoST) Cost Equations

Figure 4-2: Equation Type 9 Example Screenshot

View Control Measure: Fabric Filter - Mechanical Shaker: Utility Boilers - Coal r11 S





Suniniaiy Efficiencies SCCs [ Equations ] Properties References

Equation Type:

Name: Type 9

Description: EGU PM Control Equations

Inventory Fields: stack_flow_rate



Equation:











Equation Type

Variable Name

Value

Type 9

Pollutant

PM10

Type 9

Cost Year

1990

Type 9

Total Equipment Cost Factor

5.7019

Type 9

Total Equipment Cost Constant

77489.0

Type 9

EquipmentTo Capital Cost Multiplier

2.17

Type 9

Electricity Factor

0.1941

Type 9

Electricity Constant

-15.956

Type 9

Dust Disposal Factor

0.7406

Type 9

Dust Disposal Constant

1.1461

Type 9

Bag Replacement Factor

0.2497

Type 9

Bag Replacement Constant

1220.7





Report Close

4.1.4.2 Annualized Capital Cost

Capital Cost

( ft3 \

= ((Total Equipment Cost Factor x STKFLOW 	

\min J

+ Total Equipment Cost Constant) x Equipment to Capital Cost Multiplier

/S5.7019	/ ft3 \	\

Capital Cost = 		— x 16,354 	 + $77,489 x 2.17

y acfm	yminy	J

Capital Cost = $370,501 (1990$)

68


-------
Control Strategy Tool (CoST) Cost Equations

Interest Rate x (1 + Interest Rate~)EquivmentLl^e
Capital Recovery Factor = —

Capital Recovery Factor =

(1 + Interest Rate)EciuiPment Life
0.07 x (1 + 0.07)20

(1 + 0.07)20
Capital Recovery Factor = 0.094393

Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Annualized Capital Cost = $370,504 x 0.094393
Annualized Capital Cost = $34,973 (1990$)

4.1.4.3 Operation and Maintenance Cost

0&.M Cost

( / ft3 \	\

= Electricity Factor x STKFLOW 	 + Electricity Constant

V	Vmin/	J

( / ft3 \	\

+ Dust Disposal Factor x STKFLOW 	 + Dust Disposal Constant

v	Vmin/

(	/ ft3 \	\

+ I Bag Replacement Factor x STKFLOW I——I + Bag Replacement Constant I

0&.M Cost

$0.1941	/ ft3 \	\ /	/ ft3 \	\

		— x 16,354 	 - $15,956 + $0.7406/acfm x 16,354 	 + $1.1461

acfm	ymin)	) \	ymin)	)

+ ($0.2497/acfm X 16,354	+ $1220.7

0&.M Cost = $20,576 (1990$)

4.1.4.4 Total Annualized Cost

Total Annualized Cost = Annualized Capital Cost + 0&.M Cost
Total Annualized Cost = $34,973 + $20,576
Total Annualized Cost = $55,549 (1990$)

4.1.5 Equation Type 10

In addition to add-on control measures, there are control measures included in CoST that are
upgrades to control measures already in operation on a unit. CoST includes control measures
that are upgrades to ESPs on ptipm sources. These control measures are costed using Equation
Type 10 and the variable values are presented in Table B-13. The SCCs using Equation Type 10
are listed in Table 4-3. Also, note that Equation Type 10 is specifically for PM2.5.

	Table 4-3. Electric Generation Categories Associated with Equation Type 10	

SCC	Description	

1 m nn?m External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Pulverized Coal: Wet Bottom
	(Bituminous Coal)	

69


-------
Control Strategy Tool (CoST) Cost Equations

see

Description

10100202

External Combustion Boilers; Electric Generation;
(Bituminous Coal)

Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

10100203

External Combustion Boilers; Electric Generation;
Coal)	

Bituminous/Subbituminous Coal; Cyclone Furnace (Bituminous

10100204

External Combustion Boilers; Electric Generation;
Coal)	

Bituminous/Subbituminous Coal; Spreader Stoker (Bituminous

10100205

External Combustion Boilers; Electric Generation;
Stoker (Bituminous Coal)

Bituminous/Subbituminous Coal; Traveling Grate (Overfeed)

10100211

External Combustion Boilers; Electric Generation;
(Bituminous Coal)	

Bituminous/Subbituminous Coal; Wet Bottom (Tangential)

10100212

External Combustion Boilers; Electric Generation;
(Tangential) (Bituminous Coal)	

Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

10100215 External Combustion Boilers; Electric Generation; Bituminous/Subbituminous Coal; Cell Burner (Bituminous Coal)

10100217

External Combustion Boilers; Electric Generation;
Combustion: Bubbling Bed (Bituminous Coal)

Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed

10100218

External Combustion Boilers; Electric Generation;
Combustion: Circulating Bed (Bitum. Coal)

Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed

10100221

External Combustion Boilers; Electric Generation;
(Subbituminous Coal)	

Bituminous/Subbituminous Coal; Pulverized Coal: Wet Bottom

10100222

External Combustion Boilers; Electric Generation;
(Subbituminous Coal)	

Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

10100223

External Combustion Boilers; Electric Generation;
(Subbituminous Coal)

Bituminous/Subbituminous Coal; Cyclone Furnace

10100224

External Combustion Boilers; Electric Generation;
(Subbituminous Coal)	

Bituminous/Subbituminous Coal; Spreader Stoker

10100225

External Combustion Boilers; Electric Generation;
Stoker (Subbituminous Coal)	

Bituminous/Subbituminous Coal; Traveling Grate (Overfeed)

10100226

External Combustion Boilers; Electric Generation;
Tangential (Subbituminous Coal)

Bituminous/Subbituminous Coal; Pulverized Coal: Dry Bottom

10100235

External Combustion Boilers; Electric Generation;
Coal)	

Bituminous/Subbituminous Coal; Cell Burner (Subbituminous

10100237

External Combustion Boilers; Electric Generation;
Combustion: Bubbling Bed (Subbitum Coal)

Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed

10100238

External Combustion Boilers; Electric Generation;
Combustion - Circulating Bed (Subbitum Coal)

Bituminous/Subbituminous Coal; Atmospheric Fluidized Bed

10100300	External Combustion Boilers; Electric Generation; Lignite; Pulverized Coal: Wet Bottom	

10100301	External Combustion Boilers; Electric Generation; Lignite; Pulverized Coal: Dry Bottom, Wall Fired	

10100302	External Combustion Boilers; Electric Generation; Lignite; Pulverized Coal: Dry Bottom, Tangential Fired	

10100303	External Combustion Boilers; Electric Generation; Lignite; Cyclone Furnace	

10100304	External Combustion Boilers; Electric Generation; Lignite; Traveling Grate (Overfeed) Stoker	

10100306	External Combustion Boilers; Electric Generation; Lignite; Spreader Stoker	

10100316	External Combustion Boilers; Electric Generation; Lignite; Atmospheric Fluidized Bed	

10100317	External Combustion Boilers; Electric Generation; Lignite; Atmospheric Fluidized Bed Combustion - Bubbling Bed

10100318

External Combustion Boilers; Electric Generation; Lignite; Atmospheric Fluidized Bed Combustion - Circulating
Bed

10100401 External Combustion Boilers; Electric Generation; Residual Oil; Grade 6 Oil

Normal Firing

10100404 External Combustion Boilers; Electric Generation; Residual Oil; Grade 6 Oil

Tangential Firing

10100405 External Combustion Boilers; Electric Generation; Residual Oil; Grade 5 Oil

Normal Firing

10100406 External Combustion Boilers; Electric Generation; Residual Oil; Grade 5 Oil

Tangential Firing

4.1.5.1 Capital Cost Equations

/250 MW\

Capital Cost Scaling Factor = 	

\Capacity)

Capital Scaling Factor Exponent

Where:

70


-------
Control Strategy Tool (CoST) Cost Equations

Capital Scaling Factor Exponent = based on the specific control measure
Capacity = the boiler capacity (MW) obtained from the emissions inventory

Capital Cost

= Capital Cost Multiplier x Capacity x Capital Cost Scaling Factor x 1,000
Where:

Capital Cost Multiplier =based on the specific control measure
Capacity = obtained from the emissions inventory
1000 = conversion factor between kW and MW

Interest Rate x (1 + Interest Rate)Equipment Llfe

Capital Recovery Factor =		——:		

H	y	(1 + Interest Rate)EciulPment Llfe - 1

Where:

Interest Rate = annual interest rate

Equipment Life = expected economic life of the control equipment
Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Where the Capital Cost and the Capital Recovery Factor were calculated previously.
4.1.5.2 Operation and Maintenance Cost Equations

(250 MW \ F^xec^ Scaling Factor Exponent

	)

Capacity/

Where:

Fixed O&M Scaling Factor Exponent = based on the specific control measure
Capacity (MW) = boiler capacity obtained from the emissions inventory

Fixed O&M

= Fixed O&M Cost Scaling Factor x Fixed O&M Cost Multiplier x Capacity x 1,000
Where:

Fixed O&M Cost Multiplier = based on the specific control measure
Capacity (MW) = obtained from the emissions inventory
1000 = conversion factor between kW and MW

Variable O&M

= Variable O&M Cost Multiplier x Capacity x Capacity Factor
x Annual Operating Hours

Where:

Variable O&M Cost Multiplier = based on the specific control measure
Capacity Factor = based on the specific control measure

71


-------
Control Strategy Tool (CoST) Cost Equations

Capacity = obtained from the emissions inventory

Annual Operating Hours = obtained from the emissions inventory

O&M Cost = Fixed O&M + Variable O&M

Where the Fixed O&M and the Variable O&M costs were calculated previously.

4.1.5.3 Total Annualized Cost Equation

Total Annualized Cost

= Annualized Capital Cost + .04 x Total Capital Cost + O&M Cost
Where:

0.04 (4%) = portion of the Total Capital Cost that is the fixed annual charge for taxes, insurance
and administrative costs

4.1.6 Equation Type 10 Example

This section provides example calculations for an application of Equation Type 10. The example
scenario is a coal-fired utility boiler that requires PM2.5 control. Using Table B-13 the control
technology is adding surface area of two ESP fields and the CoST code is PDESPM2FLD.

4.1.6.1 Example Equation Variables

Capital Cost Multiplier =17.5
Capital Scaling Factor Exponent = 0.3
Fixed O&M Cost Multiplier = 0.31
Fixed O&M Scaling Factor Exponent = 0.3
Variable O&M Cost Multiplier = 0.013
Capacity = 58.068 MW
Interest Rate = 7%

Equipment Life = 5 years (from summary tab of control measure data)

Year for Cost Basis = 2005

72


-------
Control Strategy Tool (CoST) Cost Equations

Figure 4-3: Equation Type 10 Example Screenshot

View Control Measure: Adding Surface Area of Two ESP Fields u 0" H





Summary Efficiencies SCCs f Equations | Properties References

Equation Type:

Name: Type 10

Des cri ption: E S P U pgrade

Inventory Fields: design_capacity, design_capacity_unit_numerator, design_capacity_unit_denominator, annual_avg_hours_per_yea

Equation:











Equation Type

Variable Name

Value

Type 10

Pollutant

PM2_5

Type 10

Cost Year

2005

Type 10

Capital Cost Multiplier

17.5

Type 10

Capital Cost Exponent

0.3

Type 10

Variable O&M Cost Multiplier

0.013

Type 10

Fixed O&M Cost Multiplier

0.31

Type 10

Fixed O&M Cost Exponent

0.3



4.1.6.2 Capital Cost Equations

Capital Scaling Factor Exponent

\Capacity)

0.3

/250 MW\C

Capital Cost Scaling Factor = —	:—

\CapacityJ

( 250 MW \

Capital Cost Scaling Factor = I	MWJ

Capital Cost Scaling Factor = 1.55
Capital Cost

= Capital Cost Multiplier x Capacity x Capital Cost Scaling Factor x 1,000

$17.50	kW

Capital Cost = —	x 58.068 MW x 1.55 x 1,000 	

kW	MW

Capital Cost = $1,575,095

Interest Rate x (1 + Interest Rate^EciulPment Llfe
Capital	Recovery Factor =	(1 +/nterMt 	

73


-------
Control Strategy Tool (CoST) Cost Equations

0.07 X (1 + 0.07)5
Capital Recovery Factor = ^ + q gy-^s		

Capital Recovery Factor = 0.2439

Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Annualized Capital Cost = $1,575,095 x 0.2439
Annualized Capital Cost = $384,166 (2005$)

4.1.6.3 Operation and Maintenance Cost Equations

/250 MW\

Fixed O&M Cost Scaling Factor = 	

\CapacityJ

Fixed 0&.M Scaling Factor Exponent

( 250 MW \03
Fixed O&M Cost Scalinq Factor = ——————

w	V58.068 MW)

Fixed O&M Cost Scaling Factor = 1.55

Fixed O&M

= Fixed O&M Cost Scaling Factor x Fixed O&M Cost Multiplier x Capacity x 1,000

$ kW
Fixed O&M = 1.55 x $0.31—	 x 58.068MW x 1,000——

kW-year	MW

Fixed O&M = $27,901
Variable O&M

= Variable O&M Cost Multiplier x Capacity x Capacity Factor
x Annual Operating Hours

$	Hours

Variable O&M = $0.013-—- x 58.068 MW x 0.85 x 8,760	

kWh	Year

Variable O&M = $5,620

O&M Cost = Fixed O&M + Variable O&M
O&M Cost = $27,901 + $5,620
O&M Cost = $33,522 (2005$)

74


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Control Strategy Tool (CoST) Cost Equations

4.1.6.4 Total Annualized Cost Equation

Total Annualized Cost

= Annualized Capital Cost + .04 x Total Capital Cost + O&M Cost
Total Annualized Cost = $384,166 + .04 x $1,575,095 + $33,522
Total Annualized Cost = $480,692 (2005$)

4.2 Non-IPM Sector (ptnonipm) PM Control Cost Equations

Non-IPM point sources utilizing control cost equations for PM emission reductions are Equation
Types 8, 14, 15, and 17. Equation Type 8 uses the unit's stack flowrate (in scfm) as the primary
variable for control cost calculation. If a unit's stack flow is less than 5 cubic feet per minute
(cfm), then the control cost equation is not applied to the specific unit and instead a default cost
per ton calculation is used.

Equations 14, 15 and 18 were developed for the industrial, commercial, and institutional boilers
and processes heater NESHAP for major sources (Boiler MACT). The equations to calculate
flowrates for Equation Types 14 through 18 are provided in section 3.2.11 (above). Also, the
costs are based on the calendar year 2008.

Although applicability and control costs are based on PMio emissions, PM2.5 reductions also
occur when the above limits are met. A revision is scheduled to change the primary pollutant for
all PM control measures from PM10 to PM2.5 and recalculate all the control costs. This will be
available in a future version of the Control Measures Database (CMDB).

If the unit already has PM controls applied in the input inventory, incremental controls are
applied only if their control efficiency value exceeds that of the input control. Control costs do
not differ in these cases and the costs associated with incremental controls are the same as those
applied on uncontrolled sources.

Table B-lOError! Reference source not found, provides a list of the control cost equations
assigned to various PM control measures. Both the control efficiencies for PM10 and PM2.5 are
provided in this table. Values are representative of typical cost values and low and high cost
values are also available in the source tables. These typical costs are presented in terms of
$/acfm. Table B-l lError! Reference source not found, presents the default cost per ton values
used when a unit's stack flowrate is outside of the recommended range. Three variables are
available for this calculation: a capital cost multiplier, an O&M cost multiplier, and an
annualized cost multiplier. These are expressed in terms of $/ton PM10 reduced.

4.2.1 Equation Type 8 for PM

There are 2915 SCCs in the CoST CMDB database for this category. Listing all of the SCCs in a
table would be too large for this document, so the major categories of SCCs are listed in Table
4-4. Parameters for the cost control equations are from Table B-10.

Table 4-4. PM ptnonipm Categories Associated with Equation Type 8
	Primary SCC		Secondary SCC

75


-------
Control Strategy Tool (CoST) Cost Equations

Primary SCC

Secondary SCC

External Combustion Boilers

Industrial

External Combustion Boilers

Commercial/Institutional

Industrial Processes

Chemical Manufacturing

Industrial Processes

Food & Agriculture: Grain Milling

Industrial Processes

Primary Metal Production

Industrial Processes

Secondary Metal Production

Industrial Processes

Mineral Products

Industrial Processes

Pulp and Paper and Wood Products

Industrial Processes

Fabricated Metal Products

Waste Disposal

Municipal Incineration

4.2.1.1	Capital Cost Equation

Total Capital Cost = Typical Capital Cost x STKFLOW
Where:

Typical Capital Cost = based on the specific control measure
STKFLOW = stack gas flowrate (ft3/s) from the emissions inventory

Interest Rate x (1 + Interest Rate)Equipment Llfe

Capital Recovery Factor =	—	——:	;	

H	7	[(1 + Interest Rate)EiulvmentLlfe - 1]

Where:

Interest Rate = annual interest rate

Equipment Life = expected economic life of the control equipment

Annualized Capital Cost = Capital Cost x Capital Recovery Factor

Where the Capital Cost and the Capital Recovery Factor were calculated previously.

4.2.1.2	Operation and Maintenance Cost Equation
0&.M Cost = Typical 0&.M Cost x STKFLOW
Where:

Typical O&M Cost = based on the specific control measure
STKFLOW = stack gas flowrate (ft3/s) from the emissions inventory

4.2.1.3	Total Annualized Cost Equation

When stackflow is available and in range,

Total Annualized Cost = Annualized Capital Cost + 0.04 x Capital Cost + O&M Cost
Where:

0.04 = 4% of the Capital Cost; fixed annual charge for taxes, insurance, and administrative cost
Annualized Capital Cost and O&M Cost were calculated previously.

76


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Control Strategy Tool (CoST) Cost Equations

When stackflow is unavailable in the inventory,

Total Annualized Cost = Emission Reduction x Default Cost Per Ton
Where:

Emission Reduction = calculated by CoST

Default Cost per Ton = based on the specific control measure

4.2.2 Equation Type 8 Example with Inventory Stackflow

This section provides example calculations for a "typical" application of Equation Type 8 to a
non-EGU plant; see Section 4.2.3 for an example of a "default" application. The example
scenario is non-ferrous metal processor of aluminum using a dry ESP - plate type for PM
control. Using Table B-10 the CoST code is PDESPMPAM.

4.2.2.1 Example Equation Variables

Typical Capital Cost = 27.0 $/acfm

Typical O&MCost = $16.0/acfm

Interest Rate = 7%

Equipment life = 20 years

PMio Emissions Reductions = 162.78 tons

STKFLOW = 283.69 ft3/sec

Year for Cost Basis = 1995

77


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Control Strategy Tool (CoST) Cost Equations

Figure 4-4: Equation Type 8 Example Screenshot

View Control Measure: Dry ESP-Wire Plate Type;(PM10) NonFerrous Metals Processing - Aluminum u S |





Summary Efficiencies SCCs f Equations } Properties References

Equation Type:

Name: Type 8
Description: Non-EGU PM
Inventory Fields: stack_flow_rate



Equation:

Capital Cost= Typical Capital Costx Min. Stack Flow Rate

O&M Cost= Typical O&M Costx Min. Stack Flow Rate

Total Cost= Capital Costx CRF + 0.04 x capital cost + O&M Cost

A.
T









Equation Type

Variable Name

Value

Type 8

Pollutant

PM10

Type 8

Cost Year

1995

Type 8

Typical Capital Control Cost Factor

27.0

Type 8

Typical O&M Control Cost Factor

16.0

Type 8

Typical Default CPT Factor- Capital

710.0

Type 8

Typical Default CPT Factor- 0&.M

41.0

Type 8

Typical Default CPT Factor - Annualized

110.0





Report Close

	 " 	

4.2.2.2 Capital Cost Equation

Capital Cost = Typical Capital Cost x STKFLOW x 60

ft^	SGC

Capital Cost = $27/acfm x 283.69	x 60	

sec min

Capital Cost = $459,578 (1995$)

Interest Rate x (1 + Interest Rate^EciulPment Llfe
Capital	Recovery Factor =	(1 + )ntere5t	t	

0.07 X (1 + 0.07)20
Capital Recovery Factor = ^1 + 007yo_1

Capital Recovery Factor = 0.094393

Annualized Capital Cost = Capital Cost x Capital Recovery Factor
Annualized Capital Cost = $459,578 x 0.094393
Annualized Capital Cost = $43,381 (1995$)

78


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Control Strategy Tool (CoST) Cost Equations

4.2.2.3	Operation and Maintenance Cost Equation

0&.M Cost = Typical 0&.M Cost x STKFLOW x 60

ft^	SGC

0&.M Cost = $16/acfm x 283.69	x 60——

SQC	771171

0&.M Cost = $272,342 ($1995)

4.2.2.4	Total Annualized Cost Equation

Total Annualized Cost = Annualized Capital Cost + 0.04 x Capital Cost + 0&.M Cost
Total Annualized Cost = $43,381 + 0.04 x $459,578 + $272,342
Total Annualized Cost = $637,851 (1995$)

4.2.3 Equation Type 8 Example without Inventory Stackflow

This example gets its values for a coal-burning utility boiler with a Dry ESP - Wire Plate Type
control from Table B-9. This is an example of using ptipm values for the same type of control
equipment when needing default values. The CoST code is PDESPWPUBC.

4.2.3.1	Example Equation Variables

Default Cost per Ton - Capital=710 $/ton
Default Cost per Ton - 0&M= 41 $/ton
Default Cost per Ton Annualized =110$/ton

UncontrolledPMio =15 tons (from inventory record without stack parameters)

PMio control efficiency = 98%

PMio reduction = 14.7 tons
Year for Cost Basis = 1995

4.2.3.2	Capital Cost

Total Capital Cost = Emission Reduction x Default Cost Per Ton — Capital

$

Total Capital Cost = 14.7 tons x 710	

ton

Total Capital Cost = $10,437 (1995$)

4.2.3.3	Operating and Maintenance Cost

Total 0&.M Cost = Emission Reduction x Default Cost Per Ton — 0&.M

$

Total 0&.M Cost = 14.7 tons x 41	

ton

Total 0&.M Cost = $603 (1995$)

4.2.3.4	Total Annualized Cost Equation

Total Annualized Cost = Emission Reduction x Default Cost Per Ton — Annualized

$

Total Annualized Cost = 14.7 tons x 110	

ton

Total Annualized Cost = $1,617 (1995$)

79


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Control Strategy Tool (CoST) Cost Equations

4.2.4 ICI Boiler Control Equations Type 14 for PM

These equations are used for fabric filters when PM control on the order of 99% is required and
no SO2 reduction is needed. The applicable SCCs for this equation type are the same as those
listed in Table 3-7.

4.2.4.1 Total Capital Investment

TCI

= (105.91 )(Fd) + 699754.7 +

yfFa

V KJ.KJ J.** )\ —	

+

(0.560)

' m y

#Ducts )

+

(1096.141)eCa017)^#Du"ts

(33.977)eC°'014)uDucts

Where:
Fd

Fa

#Ducts

Exhaust flowrate (dscfm)

Exhaust flowrate (acfm)

if Fd < 154042, then #Ducts = 1

if Fd > 154042, then #Ducts = Fd / 154042

4.2.4.2 Total Annualized Costs

TAC

= [(17.44) (0pHrs)] + \(TCI)

+ (Fa)

( (i)(l + i)Eqafe V
(0.072) +	nF„ 	

VC1 + 0' qufe ~ 1/

/ (0(i + i)Equfe V

(4.507) + (1.24JT - 5)(OpHrs) - (4.184) ((1 + i)EqLife _ J

+ {(FdXOpHrs)[(3.76E - 3) + (1.81 E - 3)(CPM)]}

Where
Fd

OpHrs

TCI

Fa

CpM

=	Exhaust flowrate (dscfm)

=	Annual operating hours of unit (hrs/yr)

=	Total Capital Investment ($)

=	Exhaust flowrate (acfm)

=	Concentration of PM in stack gas (grains per dry standard cubic foot [gr/dscf])

i =	Interest rate expressed as a fraction (i.e., percentage divided by 100)

Equfe =	Estimated equipment life (yrs)

4.2.5 ICI Boiler Control Equations Type 14 Example for PM

The example scenario for Equation Type 14 is for an ICI boiler that is burning residual oil. It
needs to use a fabric filter as its emissions control equipment for PM. Assumptions that were
used in constructing Equations Type 14 are listed in Table B-16.

80


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Control Strategy Tool (CoST) Cost Equations

4.2.5.1 Example Equation Variables

#Ducts = 1

/' = 0.07 (annual interest rate 7%)

Equfe =15 years
Fa = 55493 acfm
Fd = 32138 dscfm

OpHrs = 2688 operating hours per year
Cpm = 2.68E-3 gr/dscf
Year for Cost Basis = 2008

Figure 4-5 illustrates the View Control Measure screen for the Fabric Filter emissions control
method for ICI Boilers (Residual Oil) emitting PM.

Figure 4-5: Equation Type 14 Example Screenshot

View Control Measure: Fabric Filter, ICI Boilers (Residual Oil) n [f [Hi





Summary Efficiencies SCCs f Equations Properties References

Equation Type:

Name: Type 14
Description: Fabric Filter Cost Equations
Inventory Fields: design_capacity, design_capacity_units, stkflow, stktemp, annual_avg_hours_per_year



Equations:











Equation Type

Variable Name

Value

Type 14

Pollutant

PH25-PRI

Type 14

Cost Year

2003

Type 14

Stack Gas Moisture Content, %

9.08





Report Close

81


-------
Control Strategy Tool (CoST) Cost Equations

4.2.5.2 Total Capital Investment

TCI

= (105.91 )(Fd) + 699754.7 +

(0.560)

' m y

#Ducts I

+

(1096.141)e



+

(33.977)eC°'014)^#Du"ts

= (105.91)(32138) + (699754.7) +

V55493s

(0.560) (^)

+

(1096.141)e

(0.017)(^H)

+

(33.977)eC°'014)' 1

= $4,195,619

4.2.5.3 Total Annualized Costs

TAC

= [(17.44) (0pHrs)] + \ (TCI)

((0(i + i)Equfe \~n

+ (Fa)

I (0(1 ~l~ i)E
-------
Control Strategy Tool (CoST) Cost Equations

Where:
ECi

Fa

ec2

#Ducts =

First equipment cost factor for ESP

if Fa> 9495, ECi = 57.87

ifFa<9495, ECi = 614.55

Exhaust flowrate (acfm)

Second equipment cost factor for ESP

ifFa> 9495, ECz = 0.8431

if Fa < 9495, EC2 = 0.6276

if Fa < 308084, #Ducts = 1

if 308084 < Fa <462126, #Ducts = 2

if 462126 < Fa < 616168, #Ducts = 3

if Fa > 616168, #Ducts = 4

4.2.6.2 Total Annualized Costs

vvwrnrivj 1	/va/J

(6.56 E - 3) fl.04 + (((1')^1.)^t-i)) ((eCi)[(S.266)(Fa)]^)l

TAC

= [(10.074) (0pHrs)] + [(0.052)(Fa)]
+

+ [(0.021) (0pHrs) (Epm) (DC)]
+ j(1.17£-5)(Fa)(Op„„)
+ K7.1SE-4XOpHrsXFa)]

+ IV	V(1 + i)uliLi

yfFa

(1.895) + | (479.85)

1.18

/ (0(1 + i)Equfe \\

(0.783)

+ (2237.44) e

(0.0165)

#Ducts I

+ (69.355) e

(0.0140)

+ (17591.15)

Where:
OpHrs

Fa
i

EqLife
ECi

EC2

Epm
DC

#Ducts

Annual operating hours of unit (hrs/yr)

Exhaust flowrate (acfm)

Interest rate expressed as a fraction of 1 (percentage divided by 100)

Estimated equipment life, years

First equipment cost factor for ESP

If Fa > 9495, ECi = 57.87

IfFa<9495, ECi = 614.55

Second equipment cost factor for ESP

IfFa> 9495, EC = 0.8431

If Fa < 9495, EC2 = 0.6276

PM emission rate, pounds per million British thermal units (lb/MMBtu)
Design capacity of boiler, (MMBtu/hr)

IfFa< 308084, #Ducts = 1
If 308084 < Fa < 462126, #Ducts = 2

83


-------
Control Strategy Tool (CoST) Cost Equations

If 462126 < Fa < 616168, #Ducts = 3
IfFa> 616168, #Ducts = 4

4.2.7 ICI Boiler Control Equations Type 15 Example for PM

The example scenario for Equation Type 15 is for an ICI boiler. It needs to use an ESP as its
emissions control equipment for PM. Assumptions that were used in constructing Equations
Type 15 are listed in Table B-16.

4.2.7.1 Example Equation Variables

ECi = 57.87
Fa = 55493
EC2 = 0.8431
#Ducts = 1

Opiirs = 2688

Equfe = 15
Epm = 4.10E-3
DC= 180

Year for Cost Basis = 2008

Figure 4-6 illustrates information for the Electrostatic Precipitator control equipment for ICI
Boilers controlling PM.

Figure 4-6: Equation Type 15 Example Screenshot

View Control Measure: Electrostatic Precipitator; ICI Boilers

r/Ef

Summary Efficiencies SCCs Equations | Properties References

Equation Type:

Name: Type 15
Description: Electrostatic Precipitator Cost Equations
Inventory Fields: design_capacity, design_capacity_units, stkflow, stktemp, annual_avg_hours_per_year

Equations:

Equation Type

Variable Name

Value

Type 15

Pollutant

PM25-PRI

Type 15

Cost Year

2008

Report

Close

84


-------
Control Strategy Tool (CoST) Cost Equations

4.2.7.2 Total Capital Investment

TCI

= {(12.265)(£'C1)[(5.266)(Fa)] 2} +

(0J84) (w5ucts)

+ (#Ducts)

(2237.13) I eC° 017)(#Du"ts)

+

= {(12.265) (57.87) [(5.266) (55493)]a8431} +

(V55493\

(69.345) I eC°'014)Uoucts

/55493V
(0.784) [—j—J

+ (1) | (2237.13)[ eC°'017)V 1 J
= $28,977,485

4.2.7.3 Total Annualized Costs

+

(69.345) fe

(0.014)(

+ (17588.69)

+ (17588.69)



TAC

= [(10.074) (0pHrs)] + [(0.052)(Fa)]
+

+ [(0.021) (OpHrs) (£pw) (DC)]

v^rnri/J '	/va/J

(6.56 E - 3) fl.04 +	((£Ca)[(5.266)(Fa)]^)j

(1.895) + (479.85)

+ |(1.17£-5)(Fa)(OpH„)
+ [(7.15£-4)(Op„„)(Fa)]
+ < | 0.04 + (^f.^C-l))

0^)

1.18

(0.783)

#Ducts,

+ (2237.44) I /°0165)(#Du"ts)^ + (69-355) (eiom40)(#Ductsj | + (17591 15)

85


-------
Control Strategy Tool (CoST) Cost Equations

15N

= [(10.074)(2688)] + [(0.052)(55493)]

f	( ((0.07)(1 + 0.07)

+ (6.56E - 3) 1.04 +	„

\ (1 + 0.07)15 - 1

+ [(0.021)(2688)(4.10£" - 3)(180)]

((57.87) [(5.266)(55493)]°-8431)

+ j(1.17£ - 5)(55493)(2688)

+ [(7.15£" - 4) (2688) (55493)]
'(0.07)(1 + 0.07)15n

(1.895) + (479.85) |



1.18

V55493

1

+ 0.04 +

(1)

((0.0140)

e

(1 + 0.07)15 — 1

V55493A

1 /] +(17591.15)

A/55493\	/

(0.783)(	;	) +(2237.44) e

(o.i

o165)(^fMY

V 1 /

= $184,770

4.2.8 ICIBoiler Control Equations Type 17for PM

These equations are used for dry injection and fabric filter (DIFF) systems when both extensive
PM control on the order of 99% and SO2 reduction of approximately 70% are required. Equation
Type 17 is presented in this section instead of section 3.2 because the primary reduction is
achieved for PM. Two assumptions specific to DIFF systems were included when constructing
these equations (Table B-18Error! Reference source not found.). Other assumptions in these
equations are included in Table B-16.

The applicable SCCs for this equation type are the same as those listed in Table 3-7.
4.2.8.1 Total Capital Investment

TCI

= [(143.76)(Fd)] +

(0.610)

#Ducts,

2-i

+

(1757.65) I e(a°17)UoUct5j

+

(59.973) ^eC°'014)Uouctsj

+ (931911.04)

Where:
Fd

Fa

#Ducts

Exhaust flowrate (dscfm)

Exhaust flowrate (acfm)
ifFd< 154042, #Ducts= 1
if Fd > 154042, #Ducts = Fd/154042

86


-------
Control Strategy Tool (CoST) Cost Equations

4.2.8.2 Total Annualized Costs

TAC

+
+

+
+

[(1.62E - 3)(OpHrs)(Fd)] + [(17.314)(Op„„)] + [(1.05£ - 6)(CS02)(Fd)(0pHrs)]
(3.72E - 5)(OpHrs)(Fa)] + [(1.81 E - 4)(OpHrs)(CPM)(Fd)]



( (0(1 + i)Equfe V

(0-04) + (d+0^ -1)

(1757.65)1 e(0-017)(#Ducts j

[(0.032)(rC/)] +

(0.606)

#Ducts,

+

(53.973) I eC° 014)l#oUct5j

+ (13689.81)

Where:

Fd	=	Exhaust flowrate (dscfm)

OpHrs	=	Annual operating hours of unit (hrs/yr)

Cso2	=	Concentration of S02 in stack gas, dry ppm by volume (ppmvd)

Fa	=	Exhaust flowrate (acfm)

Cpm	=	Concentration of PM in the stack gas (gr/dscf)

i	=	Interest rate expressed as a fraction of 1 (percentage divided by 100)

Equfe	=	Estimated equipment life (yrs)

#Ducts	=	If Fd < 154042, #Ducts = 1

If Fd > 154042, #Ducts = Fd/154042

4.2.9 ICI Boiler Control Equations Type 17 Example for PM

Figure 4-7 illustrates information in the CoST View Control Measures tool showing the Dry
Injection/Fabric Filter (DIFF) System for ICI Boilers (Bituminous Coal) for Equation Type 17.

4.2.9.1 Example Equation Variables

Fd = 32138
Fa= 55493
#Ducts = 1
OpHrs = 2688
Equfe = 15
i = 0.07
Cpm = 2.68E-3
Cso2 =1.15

Year for Cost Basis = 2008

87


-------
Control Strategy Tool (CoST) Cost Equations

Figure 4-7: Equation Type 17 Example Screenshot

View Control Measure: Dry Injection / Fabric Filter System (DIFF); ICI Boilers (Bituminous Coal) oL 0* [3





Summary Efficiencies SCCs [ Equations f Properties References

Equation Type:

Name: Type 17

Description: Dry Injection/Fabric Filter System (Diff) Cost Equations
Inventory Fields: design_capacity, design_capacity_units, stKflow, stktemp, annual_avg_hours_per_year



Equations:











Equation Type

Variable Name

Value

Type 17

Pollutant

PM25-PRI

Type 17

Cost Year

2008

Type 17

Stack Gas Moisture Content, %

4.68







Report Cjose



4.2.9.2 Total Capital Investment

TCI

= [(143.76)(Fd)] +

(0.610)

VM2-

+

+

(59.973) ^eCa014Wa*

#Ducts J
+ (931911.04)

(1757.65) e



= [(143.76) (32138)] +

A/55493\
(0.610) 	;	I

21	( (0.017)f^fH

+ (1757.65) [e V 1

+

( (0.014)f^fHV
(59.973) e V 1 /

V 1 /

+ (931911.04) = $5,683,965

88


-------
Control Strategy Tool (CoST) Cost Equations

4.2.9.3 Total Annualized Costs

TAC

+
+

+
+

+
+

+

+

[(1.62E - 3)(OpHrs)(Fd)] + [(17.314)(Op„„)] + [(1.05£ - 6)(CS02)(Fd)(0pHrs)]
(3.72E - 5)(OpHrs)(Fa)] + [(1.81 E - 4)(OpHrs)(CPM)(Fd)]



( (0(1 + i)Equfe V

(0-04) + (d+0^ -1)

(1757.65)1 e(0-017)(#Ducts j

[(0.032)(rC/)] +

(0.606)

#Ducts,

+

(53.973) I 6(0-° 14)| #DiictsJ

+ (13689.81)

[(1.62£ - 3)(2688)(32138)] + [(17.314)(2688)] + [(1.05£ - 6)(1.15)(32138)(2688)]
(3.72E - 5)(2688)(55493)] + [(1.81 E - 4)(2688)(2.68E - 3)(32138)]

( (0.07)(l + 0.07)]

(0.847) (l-('f1+nn7VS_

(0.04) +

(1 + 0.07)]

'(0.07)(1 + 0.07)15n
(1 + 0.07)15 — 1 ,

Lv-LilJ-

3)

(55493)

[(0.032)(5683965)] +

(1757.65) e

(o.oi7)(

+

((0.014)

e

A/55493X

(0.606) (	-	J

v'5 5493 V



+ (13689.81)

= $283,064

89


-------
Control Strategy Tool (CoST) Cost Equations

Appendix A. CoST Source Code

A.l Equation Type 1 CoST Code for NOx

-- Type 1

CREATE OR REPLACE FUNCTION public.get_typel_equation_costs(
control_measure_id integer,

measure_abbreviation character varying(10),
discount_rate double precision,
equipment_life double precision,
capital_recovery_factor double precision,
emis_reduction double precision,
design_capacity double precision,
capital_cost_multiplier double precision,
fixed_om_cost_multiplier double precision,
variable_om_cost_multiplier double precision,
scaling_factor_model_size double precision,
scaling_factor_exponent double precision,
capacity_factor double precision,

OUT annual_cost double precision,

OUT capital_cost double precision,

OUT operation_maintenance_cost double precision,

OUT annualized_capital_cost double precision,

OUT computed_cost_per_ton double precision) AS $$

DECLARE

cap_recovery_factor double precision := capital_recovery_factor;
scaling_factor double precision;

fixed_operation_maintenance_cost double precision;
variable_operation_maintenance_cost double precision;

BEGIN

— NOTES:

-- design capacity must in the units MW

-- get capital recovery factor, calculate if it wasn't passed in...

IF coalesce(discount_rate, 0) != 0 and coalesce(equipment_life, 0) != 0 THEN
cap_recovery_factor :=
public.calculate_capital_recovery_factor(discount_rate, equipment_life);

END IF;

-- calculate scaling factor
scaling_factor :=
case

when (measure_abbreviation = 'NSCR_UBCW' or measure_abbreviation =
'NSCR_UBCT') and design_capacity >= 600.0 then 1.0
when design_capacity >= 5 00.0 then 1.0

else scaling_factor_model_size A scaling_factor_exponent
end;

-- calculate capital cost

capital_cost := capital_cost_multiplier * design_capacity * scaling_factor * 1000;

-- calculate operation maintenance cost
-- calculate fixed operation maintenance cost

fixed_operation_maintenance_cost := fixed_om_cost_multiplier * design_capacity *
1000;

-- calculate variable operation maintenance cost

variable_operation_maintenance_cost := variable_om_cost_multiplier *
design_capacity * capacity_factor * 8760;

-- calculate total operation maintenance cost

A-l


-------
Control Strategy Tool (CoST) Cost Equations

operation_maintenance_cost := coalesce(fixed_operation_maintenance_cost, 0) +
coalesce(variable_operation_maintenance_cost, 0);

-- calculate annualized capital cost

annualized_capital_cost := capital_cost * cap_recovery_factor;

-- calculate annual cost

annual_cost := annualized_capital_cost + operation_maintenance_cost;

-- calculate computed cost per ton
computed_cost_per_ton :=
case

when coalesce(emis_reduction, 0) <> 0 then annual_cost / emis_reduction
else null
end;

END;

$$ LANGUAGE plpgsql IMMUTABLE;

-- Cost Equation Factory Method

CREATE OR REPLACE FUNCTION public.get_strategy_costs(
use_cost_equations boolean,
control_measure_id integer,

measure_abbreviation character varying(10),
discount_rate double precision,
equipment_life double precision,
capital_annualized_ratio double precision,
capital_recovery_factor double precision,
ref_yr_cost_per_ton double precision,
emis_reduction double precision,

ref_yr_chained_gdp_adjustment_factor double precision,
equation_type character varying(255),
variable_coefficientl double precision,
variable_coefficient2 double precision,
variable_coefficient3 double precision,
variable_coefficient4 double precision,
variable_coefficient5 double precision,
variable_coefficient6 double precision,
variable_coefficient7 double precision,
variable_coefficient8 double precision,
variable_coefficient9 double precision,
variable_coefficientlO double precision,
stack_flow_rate double precision,
design_capacity double precision,

design_capacity_unit_numerator character varying,
design_capacity_unit_denominator character varying,
ceff double precision,

ref_yr_incremental_cost_per_ton double precision,

OUT annual_cost double precision,

OUT capital_cost double precision,

OUT operation_maintenance_cost double precision,

OUT annualized_capital_cost double precision,

OUT computed_cost_per_ton double precision,

OUT actual_equation_type character varying(255)

-- ,OUT valid_cost boolean

) AS $$

DECLARE

converted_design_capacity double precision;
valid_cost boolean;

BEGIN

-- at first, we can only assume that everything is right...
valid cost := true;

A-2


-------
Control Strategy Tool (CoST) Cost Equations

-- Each Cost Equation Function will return costs in the cost year that is specified
in the emf.control_measure_equations table,

-- after the costs are calculated we can adjust the costs to the reference cost
year.

-- try cost equations first, then maybe use default approach, if needed
IF use_cost_equations THEN

IF equation_type is not null THEN

-- Type 1

IF equation_type = 'Type 1' THEN

converted_desiqn_capacity :=
public.convert_desiqn_capacity_to_mw(desiqn_capacity, desiqn_capacity_unit_numerator,
desiqn_capacity_unit_denominator);

IF coalesce(desiqn_capacity, 0) <> 0 THEN
select costs.annual_cost,
costs.capital_cost,
costs.operation_maintenance_cost,
costs.annualized_capital_cost,
costs.computed_cost_per_ton
from public.qet_typel_equation_costs(control_measure_id,
measure_abbreviation,
discount_rate,
equipment_life,
capital_recovery_factor,
emis_reduction,
converted_desiqn_capacity,
variable_coefficientl,
variable_coefficient2,
variable_coefficient3,
variable_coefficient4,
variable_coefficient5,
variable_coefficient6) as costs
into annual_cost,
capital_cost,

operation_maintenance_cost,
annualized_capital_cost,
computed_cost_per_ton;

IF annual_cost is not null THEN
valid_cost := true;
actual_equation_type := 'Type 1";

ELSE

valid_cost := false;
actual_equation_type := '-Type 1";

END IF;

-- adjust costs to the reference cost year

annual_cost := ref_yr_chained_qdp_adjustment_factor * annual_cost;
capital_cost := ref_yr_chained_qdp_adjustment_factor * capital_cost;
operation_maintenance_cost := ref_yr_chained_qdp_adjustment_factor *
operation_maintenance_cost;

annualized_capital_cost := ref_yr_chained_qdp_adjustment_factor *
annualized_capital_cost;

computed_cost_per_ton := ref_yr_chained_qdp_adjustment_factor *
computed_cost_per_ton;

return;

END IF;

valid_cost := false;

actual_equation_type := '-Type 1";

END IF;

A-3


-------
Control Strategy Tool (CoST) Cost Equations
A.2 Equation Type 2 CoST Code

-- plpgsql script code funneling to Type 2 cost equations...

converted_design_capacity := public.convert_design_capacity_to_mw(design_capacity,
design_capacity_unit_numerator, design_capacity_unit_denominator);

-- convert design capacity to mmBtu/hr

converted_design_capacity := 3.412 * converted_design_capacity;
IF coalesce(converted_design_capacity, 0) <> 0 THEN

-- design capacity must be less than or equal to 2000 MMBTU/hr (or 586.1665 MW/hr))
IF (converted_design_capacity <= 2000.0) THEN
select costs.annual_cost,
costs.capital_cost,
costs.operation_maintenance_cost,
costs.annualized_capital_cost,
costs.computed_cost_per_ton
from public.get_type2_equation_costs(control_measure_id,
discount_rate,
equipment_life,
capital_recovery_factor,
emis_reduction,
converted_design_capacity,
variable_coefficientl,
variable_coefficient2,
variable_coefficient3,
variable_coefficient4) as costs
into annual_cost,
capital_cost,

operation_maintenance_cost,
annualized_capital_cost,
computed_cost_per_ton;

IF annual_cost is not null THEN
valid_cost := true;
actual_equation_type := 'Type 2';

ELSE

valid_cost := false;
actual_equation_type := '-Type 2";

END IF;

-- adjust costs to the reference cost year

annual_cost := ref_yr_chained_gdp_adjustment_factor * annual_cost;
capital_cost := ref_yr_chained_gdp_adjustment_factor * capital_cost;
operation_maintenance_cost := ref_yr_chained_gdp_adjustment_factor *
operation_maintenance_cost;

annualized_capital_cost := ref_yr_chained_gdp_adjustment_factor *
annualized_capital_cost;

computed_cost_per_ton := ref_yr_chained_gdp_adjustment_factor *
computed_cost_per_ton;
return;

END IF;

END IF;

valid_cost := false;
actual_equation_type := '-Type 2";

-- Next the code will call the default CPT approach

A-4


-------
Control Strategy Tool (CoST) Cost Equations

-- Type 2

CREATE OR REPLACE FUNCTION public.get_type2_equation_costs(
control_measure_id integer,
discount_rate double precision,
equipment_life double precision,
capital_recovery_factor double precision,
emis_reduction double precision,
design_capacity double precision,
capital_cost_multiplier double precision,
capital_cost_exponent double precision,
annual_cost_multiplier double precision,
annual_cost_exponent double precision,

OUT annual_cost double precision,

OUT capital_cost double precision,

OUT operation_maintenance_cost double precision,

OUT annualized_capital_cost double precision,

OUT computed_cost_per_ton double precision) AS $$

DECLARE

cap_recovery_factor double precision := capital_recovery_factor;

BEGIN

— NOTES:

-- design capacity must in the units mmBtu/hr

-- get capital recovery factor, calculate if it wasn't passed in...
IF coalesce(discount_rate, 0) != 0 and coalesce(equipment_life, 0) != 0 THEN
cap_recovery_factor := public.calculate_capital_recovery_factor(discount_rate,
equipment_life);

END IF;

-- calculate capital cost

capital_cost := capital_cost_multiplier * (design_capacity A
capital_cost_exponent);

-- calculate annualized capital cost

annualized_capital_cost := capital_cost * cap_recovery_factor;

-- calculate annual cost

annual_cost := annual_cost_multiplier * design_capacity A annual_cost_exponent;
-- calculate operation maintenance cost

operation_maintenance_cost := annual_cost - annualized_capital_cost;

-- calculate computed cost per ton
computed_cost_per_ton :=
case

when coalesce(emis_reduction, 0) <> 0 then annual_cost / emis_reduction
else null
end;

END;

$$ LANGUAGE plpgsql IMMUTABLE;

CREATE OR REPLACE FUNCTION public.convert_design_capacity_to_mw(design_capacity double
precision, design_capacity_unit_numerator character varying,

design_capacity_unit_denominator character varying) returns double precision AS $$
DECLARE

converted_design_capacity double precision;
unit_numerator character varying;
unit_denominator character varying;

BEGIN

--default if not known

unit_numerator := coalesce(trim(upper(design_capacity_unit_numerator)), ' ');
unit_denominator := coalesce(trim(upper(design_capacity_unit_denominator)), ' ');

A-5


-------
Control Strategy Tool (CoST) Cost Equations

--if you don't know the units then you assume units are MW
IF length(unit_numerator) = 0 THEN

return converted_design_capacity;

END IF;

/* FROM Larry Sorrels at the EPA
1) E6BTU does mean ittmBTU.

2) 1 MW = 3.412 million BTU/hr (or mmBTU/hr)
mmBTU/hr = 1/3.412 (or 0.2931) MW.

And conversely, 1

3) All of the units listed below are convertible, but some of the
conversions will be more difficult than others. The ft3, lb, and ton
will require some additional conversions to translate mass or volume
into an energy term such as MW or mmBTU/hr. Applying some density
measure (which is mass/volume) will likely be necessary.

--capacity is already in the right units...

--no conversion is necessary, these are the expected units.
IF (unit_numerator = 'MW' and unit_denominator = '') THEN

return design_capacity;

END IF;

IF (unit_numerator = 'MMBTU'

or unit_numerator = 'E6BTU'
or unit_numerator = 'BTU'
or unit_numerator = 'HP'
or unit_numerator = 'BLRHP') THEN

--convert numerator unit
IF (unit_numerator = 'MMBTU'

or unit_numerator = 'E6BTU') THEN

converted_design_capacity := design_capacity / 3.412;

END IF;

IF (unit_numerator = 'BTU') THEN

converted_design_capacity := design_capacity / 3.412 / 1000000.0;
END IF;

IF (unit_numerator = 'HP') THEN

converted_design_capacity := design_capacity * 0.000746;

END IF;

IF (unit_numerator = 'BLRHP') THEN

converted_design_capacity := design_capacity * 0.000981;

END IF;

--convert denominator unit, if missing ASSUME per hr
IF (unit_denominator = '' or unit_denominator = 'HR'
or unit_denominator = 'H') THEN
return converted_design_capacity;

END IF;

IF (unit_denominator = 'D' or unit_denominator = 'DAY') THEN

return converted_design_capacity * 24.0;

END IF;

IF (unit_denominator = 'M' or unit_denominator = 'MIN') THEN

return converted_design_capacity / 60.0;

END IF;

IF (unit_denominator = 'S' or unit_denominator = 'SEC') THEN

return converted_design_capacity / 3600.0;

END IF;

END IF;
return null;

END;

A-6


-------
Control Strategy Tool (CoST) Cost Equations
$$ LANGUAGE plpgsql IMMUTABLE;

A-7


-------
Control Strategy Tool (CoST) Cost Equations
A.3 Equation Type 3 CoST Code

-- Code that funnels the source to the correct control measure cost equations.
— NOTES:

-- stack flowrate was converted from cfs to cfm prior to getting here.

-- Type 3

IF equation_type = 'Type 3' THEN

IF coalesce(STKFLOW, 0) <> 0 THEN
select costs.annual_cost,
costs.capital_cost,
costs.operation_maintenance_cost,
costs.annualized_capital_cost,
costs.computed_cost_per_ton
from public.get_type3_equation_costs(control_measure_id,
discount_rate,
equipment_life,
capital_recovery_factor,
emis_reduction,

STKFLOW) as costs
into annual_cost,
capital_cost,

operation_maintenance_cost,
annualized_capital_cost,
computed_cost_per_ton;

IF annual_cost is not null THEN
valid_cost := true;
actual_equation_type := 'Type 3";

ELSE

valid_cost := false;
actual_equation_type := '-Type 3";

END IF;

-- adjust costs to the reference cost year

annual_cost := ref_yr_chained_gdp_adjustment_factor * annual_cost;
capital_cost := ref_yr_chained_gdp_adjustment_factor * capital_cost;
operation_maintenance_cost := ref_yr_chained_gdp_adjustment_factor *
operation_maintenance_cost;

annualized_capital_cost := ref_yr_chained_gdp_adjustment_factor *
annualized_capital_cost;

computed_cost_per_ton := ref_yr_chained_gdp_adjustment_factor *
computed_cost_per_ton;
return;

END IF;

valid_cost := false;
actual_equation_type := '-Type 3";

END IF;

-- Next the code will call the default CPT approach

-- Type 3

CREATE OR REPLACE FUNCTION public.get_type3_equation_costs(
control_measure_id integer,
discount_rate double precision,
equipment_life double precision,
capital_recovery_factor double precision,

A-8


-------
Control Strategy Tool (CoST) Cost Equations

emis_reduction double precision,

STKFLOW double precision,

OUT annual_cost double precision,

OUT capital_cost double precision,

OUT operation_maintenance_cost double precision,

OUT annualized_capital_cost double precision,

OUT computed_cost_per_ton double precision) AS $$

DECLARE

cap_recovery_factor double precision := capital_recovery_factor;
capital_cost_factor double precision := 192;
gas_flow_rate_factor double precision := 0.48 6;
retrofit_factor double precision := 1.1;

BEGIN

-- get capital recovery factor, calculate if it wasn't passed in...
IF coalesce(discount_rate, 0) != 0 and coalesce(equipment_life, 0) != 0 THEN

cap_recovery_factor :=
public.calculate_capital_recovery_factor(discount_rate, equipment_life);

END IF;

-- calculate capital cost
capital_cost :=
case

when STKFLOW < 1028000 then

(1028000/ STKFLOW) A 0.6 * capital_cost_factor * gas_flow_rate_factor *
retrofit_factor * STKFLOW
else

capital_cost_factor * gas_flow_rate_factor * retrofit_factor * STKFLOW

end;

-- calculate annualized capital cost

annualized_capital_cost := capital_cost * cap_recovery_factor;

-- calculate operation maintenance cost

operation_maintenance_cost := (3.35 + (0.000729 * 8736)) * STKFLOW;

-- calculate annual cost

annual_cost := annualized_capital_cost + operation_maintenance_cost;

-- calculate computed cost per ton
computed_cost_per_ton :=
case

when coalesce(emis_reduction, 0) <> 0 then annual_cost / emis_reduction
else null
end;

END;

$$ LANGUAGE plpgsql IMMUTABLE;

A-9


-------
Control Strategy Tool (CoST) Cost Equations
A.4 Equation Type 4 CoST Code

-- Code that funnels the source to the correct control measure cost equations.
— NOTES:

-- stack flowrate was converted from cfs to cfm prior to getting here.

-- Type 4

IF equation_type = 'Type 4' THEN

IF coalesce(STKFLOW, 0) <> 0 THEN
select costs.annual_cost,
costs.capital_cost,
costs.operation_maintenance_cost,
costs.annualized_capital_cost,
costs.computed_cost_per_ton
from public.get_type4_equation_costs(control_measure_id,
discount_rate,
equipment_life,
capital_recovery_factor,
emis_reduction,

STKFLOW) as costs
into annual_cost,
capital_cost,

operation_maintenance_cost,
annualized_capital_cost,
computed_cost_per_ton;

IF annual_cost is not null THEN
valid_cost := true;
actual_equation_type := 'Type 4";

ELSE

valid_cost := false;
actual_equation_type := '-Type 4";

END IF;

-- adjust costs to the reference cost year

annual_cost := ref_yr_chained_gdp_adjustment_factor * annual_cost;
capital_cost := ref_yr_chained_gdp_adjustment_factor * capital_cost;
operation_maintenance_cost := ref_yr_chained_gdp_adjustment_factor *
operation_maintenance_cost;

annualized_capital_cost := ref_yr_chained_gdp_adjustment_factor *
annualized_capital_cost;

computed_cost_per_ton := ref_yr_chained_gdp_adjustment_factor *
computed_cost_per_ton;
return;

END IF;

valid_cost := false;
actual_equation_type := '-Type 4";

END IF;

-- Next the code will call the default CPT approach

-- Type 4

CREATE OR REPLACE FUNCTION public.get_type4_equation_costs(
control_measure_id integer,
discount_rate double precision,
equipment_life double precision,

A-10


-------
Control Strategy Tool (CoST) Cost Equations

capital_recovery_factor double precision,
emis_reduction double precision,

STKFLOW double precision,

OUT annual_cost double precision,

OUT capital_cost double precision,

OUT operation_maintenance_cost double precision,

OUT annualized_capital_cost double precision,

OUT computed_cost_per_ton double precision) AS $$

DECLARE

cap_recovery_factor double precision := capital_recovery_factor;

BEGIN

-- get capital recovery factor, calculate if it wasn't passed in...

IF coalesce(discount_rate, 0) != 0 and coalesce(equipment_life, 0) != 0 THEN
cap_recovery_factor :=
public.calculate_capital_recovery_factor(discount_rate, equipment_life);

END IF;

-- calculate capital cost

capital_cost := (990000 + 9.836 * STKFLOW);

-- calculate annualized capital cost

annualized_capital_cost := capital_cost * cap_recovery_factor;

-- calculate operation maintenance cost

operation_maintenance_cost := (75800 + 12.82 * STKFLOW);

-- calculate annual cost

annual_cost := annualized_capital_cost + operation_maintenance_cost;

-- calculate computed cost per ton
computed_cost_per_ton :=
case

when coalesce(emis_reduction, 0) <> 0 then annual_cost / emis_reduction
else null
end;

END;

$$ LANGUAGE plpgsql IMMUTABLE;

A.5 Equation Type 5 CoST Code

-- Code that funnels the source to the correct control measure cost equations.

— NOTES:

-- stack flowrate was converted from cfs to cfm prior to getting here.

-- Type 5

IF equation_type = 'Type 5' THEN

IF coalesce(STKFLOW, 0) <> 0 THEN
select costs.annual_cost,
costs.capital_cost,
costs.operation_maintenance_cost,
costs.annualized_capital_cost,
costs.computed_cost_per_ton
from public.get_type5_equation_costs(control_measure_id,
discount_rate,
equipment_life,
capital_recovery_factor,
emis_reduction,

A-ll


-------
Control Strategy Tool (CoST) Cost Equations

STKFLOW) as costs
into annual_cost,
capital_cost,

operation_maintenance_cost,
annualized_capital_cost,
computed_cost_per_ton;

IF annual_cost is not null THEN
valid_cost := true;
actual_equation_type := 'Type 5';

ELSE

valid_cost := false;
actual_equation_type := '-Type 5';

END IF;

-- adjust costs to the reference cost year

annual_cost := ref_yr_chained_gdp_adjustment_factor * annual_cost;
capital_cost := ref_yr_chained_gdp_adjustment_factor * capital_cost;
operation_maintenance_cost := ref_yr_chained_gdp_adjustment_factor *
operation_maintenance_cost;

annualized_capital_cost := ref_yr_chained_gdp_adjustment_factor *
annualized_capital_cost;

computed_cost_per_ton := ref_yr_chained_gdp_adjustment_factor *
computed_cost_per_ton;
return;

END IF;

valid_cost := false;
actual_equation_type := '-Type 5";

END IF;

-- Next the code will call the default CPT approach

-- Type 5

CREATE OR REPLACE FUNCTION public.get_type5_equation_costs(
control_measure_id integer,
discount_rate double precision,
equipment_life double precision,
capital_recovery_factor double precision,
emis_reduction double precision,

STKFLOW double precision,

OUT annual_cost double precision,

OUT capital_cost double precision,

OUT operation_maintenance_cost double precision,

OUT annualized_capital_cost double precision,

OUT computed_cost_per_ton double precision) AS $$

DECLARE

cap_recovery_factor double precision := capital_recovery_factor;

BEGIN

-- get capital recovery factor, calculate if it wasn't passed in...

IF coalesce(discount_rate, 0) != 0 and coalesce(equipment_life, 0) != 0 THEN
cap_recovery_factor :=
public.calculate_capital_recovery_factor(discount_rate, equipment_life);

END IF;

-- calculate capital cost

capital_cost := (2882540 + 244.74 * STKFLOW);

-- calculate annualized capital cost

annualized_capital_cost := capital_cost * cap_recovery_factor;

-- calculate operation maintenance cost

operation_maintenance_cost := (749170 + 148.40 * STKFLOW);

A-12


-------
Control Strategy Tool (CoST) Cost Equations

-- calculate annual cost

annual_cost := annualized_capital_cost + operation_maintenance_cost;

-- calculate computed cost per ton
computed_cost_per_ton :=
case

when coalesce(emis_reduction, 0) <> 0 then annual_cost / emis_reduction
else null
end;

END;

$$ LANGUAGE plpgsql IMMUTABLE;

A.6 Equation Type 6 CoST Code

-- Code that funnels the source to the correct control measure cost equations.
— NOTES:

-- stack flowrate was converted from cfs to cfm prior to getting here.

IF equation_type = 'Type 6' THEN

IF coalesce(STKFLOW, 0) <> 0 THEN
select costs.annual_cost,
costs.capital_cost,
costs.operation_maintenance_cost,
costs.annualized_capital_cost,
costs.computed_cost_per_ton
from public.get_type6_equation_costs(control_measure_id,
discount_rate,
equipment_life,
capital_recovery_factor,
emis_reduction,

STKFLOW) as costs
into annual_cost,
capital_cost,

operation_maintenance_cost,
annualized_capital_cost,
computed_cost_per_ton;

IF annual_cost is not null THEN
valid_cost := true;
actual_equation_type := 'Type 6';

ELSE

valid_cost := false;
actual_equation_type := '-Type 6";

END IF;

-- adjust costs to the reference cost year

annual_cost := ref_yr_chained_gdp_adjustment_factor * annual_cost;
capital_cost := ref_yr_chained_gdp_adjustment_factor * capital_cost;
operation_maintenance_cost := ref_yr_chained_gdp_adjustment_factor *
operation_maintenance_cost;

annualized_capital_cost := ref_yr_chained_gdp_adjustment_factor *
annualized_capital_cost;

computed_cost_per_ton := ref_yr_chained_gdp_adjustment_factor *
computed_cost_per_ton;
return;

END IF;

valid_cost := false;
actual_equation_type := '-Type 6";

END IF;

A-13


-------
Control Strategy Tool (CoST) Cost Equations

-- Next the code will call the default CPT approach

-- Type 6

CREATE OR REPLACE FUNCTION public.get_type6_equation_costs(
control_measure_id integer,
discount_rate double precision,
equipment_life double precision,
capital_recovery_factor double precision,
emis_reduction double precision,

STKFLOW double precision,

OUT annual_cost double precision,

OUT capital_cost double precision,

OUT operation_maintenance_cost double precision,

OUT annualized_capital_cost double precision,

OUT computed_cost_per_ton double precision) AS $$

DECLARE

cap_recovery_factor double precision := capital_recovery_factor;

BEGIN

-- get capital recovery factor, calculate if it wasn't passed in...

IF coalesce(discount_rate, 0) != 0 and coalesce(equipment_life, 0) != 0

THEN

cap_recovery_factor :=
public.calculate_capital_recovery_factor(discount_rate, equipment_life);

END IF;

-- calculate capital cost

capital_cost := (3449803 + 135.86 * STKFLOW);

-- calculate annualized capital cost

annualized_capital_cost := capital_cost * cap_recovery_factor;

-- calculate operation maintenance cost

operation_maintenance_cost := (797667 + 58.84 * STKFLOW);

-- calculate annual cost

annual_cost := annualized_capital_cost + operation_maintenance_cost;

-- calculate computed cost per ton
computed_cost_per_ton :=
case

when coalesce(emis_reduction, 0) <> 0 then annual_cost / emis_reduction
else null
end;

END;

$$ LANGUAGE plpgsql IMMUTABLE;

A.7 Equation Type 7 CoST Code

Equation Type 7 has not been implemented in CoST.

A-14


-------
Control Strategy Tool (CoST) Cost Equations
A.8 Equation Type 8 CoST Code

-- Code that funnels the source to the correct control measure cost equations.
— NOTES:

-- Type 8

IF equation_type = 'Type 8' THEN

IF coalesce(STKFLOW, 0) <> 0 THEN
select costs.annual_cost,
costs.capital_cost,
costs.operation_maintenance_cost,
costs.annualized_capital_cost,
costs.computed_cost_per_ton
from public.get_type8_equation_costs(control_measure_id,
discount_rate,
equipment_life,
capital_recovery_factor,
emis_reduction,

STKFLOW,

variable_coefficientl,
variable_coefficient2,
variable_coefficient3,
variable_coefficient4,
variable_coefficient5) as costs

into annual_cost,
capital_cost,

operation_maintenance_cost,
annualized_capital_cost,
computed_cost_per_ton;

IF annual_cost is not null THEN
valid_cost := true;
actual_equation_type := 'Type 8";

ELSE

valid_cost := false;
actual_equation_type := '-Type 8";

END IF;

-- adjust costs to the reference cost year

annual_cost := ref_yr_chained_gdp_adjustment_factor * annual_cost;
capital_cost := ref_yr_chained_gdp_adjustment_factor * capital_cost;
operation_maintenance_cost := ref_yr_chained_gdp_adjustment_factor *
operation_maintenance_cost;

annualized_capital_cost := ref_yr_chained_gdp_adjustment_factor *
annualized_capital_cost;

computed_cost_per_ton := ref_yr_chained_gdp_adjustment_factor *
computed_cost_per_ton;
return;

END IF;

valid_cost := false;
actual_equation_type := '-Type 8";

END IF;

-- Next the code will call the default CPT approach

-- Type 8

A-15


-------
Control Strategy Tool (CoST) Cost Equations

CREATE OR REPLACE FUNCTION public.get_type8_equation_costs(
control_measure_id integer,
discount_rate double precision,
equipment_life double precision,
capital_recovery_factor double precision,
emis_reduction double precision,

STKFLOW double precision,

capital_control_cost_factor double precision,
om_control_cost_factor double precision,
default_capital_cpt_factor double precision,
default_om_cpt_factor double precision,
default_annualized_cpt_factor double precision,

OUT annual_cost double precision,

OUT capital_cost double precision,

OUT operation_maintenance_cost double precision,

OUT annualized_capital_cost double precision,

OUT computed_cost_per_ton double precision) AS $$

DECLARE

cap_recovery_factor double precision := capital_recovery_factor;

BEGIN

-- get capital recovery factor, calculate if it wasn't passed in...

IF coalesce(discount_rate, 0) != 0 and coalesce(equipment_life, 0) != 0

THEN

cap_recovery_factor :=
public.calculate_capital_recovery_factor(discount_rate, equipment_life);

END IF;

-- calculate capital cost
capital_cost :=
case

when coalesce(STKFLOW, 0) = 0 then null

when STKFLOW >= 5.0 then capital_control_cost_factor * STKFLOW
else default_capital_cpt_factor * emis_reduction
end;

-- calculate operation maintenance cost
operation_maintenance_cost :=
case

when coalesce(STKFLOW, 0) = 0 then null

when STKFLOW >= 5.0 then om_control_cost_factor * STKFLOW
else default_om_cpt_factor * emis_reduction
end;

-- calculate annualized capital cost

annualized_capital_cost := capital_cost * cap_recovery_factor;

-- calculate annual cost
annual_cost :=
case

when coalesce(STKFLOW, 0) = 0 then null

when STKFLOW >= 5.0 then annualized_capital_cost + 0.04 * capital_cost +
operation_maintenance_cost

else default_annualized_cpt_factor * emis_reduction
end;

-- calculate computed cost per ton
computed_cost_per_ton :=
case

when coalesce(emis_reduction, 0) <> 0 then annual_cost / emis_reduction
else null
end;

END;

$$ LANGUAGE plpgsql IMMUTABLE;

A-16


-------
Control Strategy Tool (CoST) Cost Equations
A.9 Equation Type 9 CoST Code

-- Code that funnels the source to the correct control measure cost equations.
— NOTES:

-- Type 9

IF equation_type = 'Type 9' THEN

IF coalesce(STKFLOW, 0) <> 0 THEN
select costs.annual_cost,
costs.capital_cost,
costs.operation_maintenance_cost,
costs.annualized_capital_cost,
costs.computed_cost_per_ton
from public.get_type9_equation_costs(control_measure_id,
discount_rate,
equipment_life,
capital_recovery_factor,
emis_reduction,

STKFLOW,

variable_coefficientl,
variable_coefficient2,
variable_coefficient3,
variable_coefficient4,
variable_coefficient5,
variable_coefficient6,
variable_coefficient7,
variable_coefficient8,
variable_coefficient9) as costs
into annual_cost,
capital_cost,

operation_maintenance_cost,
annualized_capital_cost,
computed_cost_per_ton;

IF annual_cost is not null THEN
valid_cost := true;
actual_equation_type := 'Type 9";

ELSE

valid_cost := false;
actual_equation_type := '-Type 9";

END IF;

-- adjust costs to the reference cost year

annual_cost := ref_yr_chained_gdp_adjustment_factor * annual_cost;
capital_cost := ref_yr_chained_gdp_adjustment_factor * capital_cost;
operation_maintenance_cost := ref_yr_chained_gdp_adjustment_factor *
operation_maintenance_cost;

annualized_capital_cost := ref_yr_chained_gdp_adjustment_factor *
annualized_capital_cost;

computed_cost_per_ton := ref_yr_chained_gdp_adjustment_factor *
computed_cost_per_ton;
return;

END IF;

valid_cost := false;
actual_equation_type := '-Type 9";

END IF;

-- Next the code will call the default CPT approach

A-17


-------
Control Strategy Tool (CoST) Cost Equations

-- Type 9 - ptipm PM Control Equations

CREATE OR REPLACE FUNCTION public.get_type9_equation_costs(
control_measure_id integer,
discount_rate double precision,
equipment_life double precision,
capital_recovery_factor double precision,
emis_reduction double precision,

STKFLOW double precision, -- in cfm
total_equipment_cost_factor double precision,
total_equipment_cost_constant double precision,
equipment_to_capital_cost_multiplier double precision,
electricity_factor double precision,
electricity_constant double precision,
dust_disposal_factor double precision,
dust_disposal_constant double precision,
bag_replacement_factor double precision,
bag_replacement_constant double precision,

OUT annual_cost double precision,

OUT capital_cost double precision,

OUT operation_maintenance_cost double precision,

OUT annualized_capital_cost double precision,

OUT computed_cost_per_ton double precision) AS $$

DECLARE

cap_recovery_factor double precision := capital_recovery_factor;

BEGIN

-- get capital recovery factor, calculate if it wasn't passed in...

IF coalesce(cap_recovery_factor, 0) = 0 and coalesce(discount_rate, 0) != 0
and coalesce(equipment_life, 0) != 0 THEN

cap_recovery_factor :=
public.calculate_capital_recovery_factor(discount_rate, equipment_life);

END IF;

-- calculate capital cost

capital_cost := ((total_equipment_cost_factor * STKFLOW) +
total_equipment_cost_constant) * equipment_to_capital_cost_multiplier;

-- calculate operation maintenance cost
operation_maintenance_cost :=

((electricity_factor * STKFLOW) + electricity_constant) +

((dust_disposal_factor * STKFLOW) + dust_disposal_constant) + ((bag_replacement_factor
* STKFLOW) + bag_replacement_constant);

-- calculate annualized capital cost

annualized_capital_cost := capital_cost	* cap_recovery_factor;

-- calculate annual cost

annual_cost := annualized_capital_cost	+ operation_maintenance_cost;

-- calculate computed cost per ton
computed_cost_per_ton :=
case

when coalesce(emis_reduction, 0) <> 0 then annual_cost / emis_reduction
else null
end;

END;

$$ LANGUAGE plpgsql IMMUTABLE;

A-18


-------
Control Strategy Tool (CoST) Cost Equations
A.10 Equation Type 10 CoST Code

-- Code that funnels the source to the correct control measure cost equations.
— Type 10

IF equation_type = 'Type 10' THEN
--default units numerator to MW
converted_design_capacity :=

public.convert_design_capacity_to_mw(design_capacity,
case

when length(coalesce(design_capacity_unit_numerator, '')) =0 then
'MW'::character varying
else

design_capacity_unit_numerator

end

, design_capacity_unit_denominator);

IF coalesce(design_capacity, 0) <> 0 THEN
select costs.annual_cost,
costs.capital_cost,

costs.variable_operation_maintenance_cost,
costs.fixed_operation_maintenance_cost,
costs.operation_maintenance_cost,
costs.annualized_capital_cost,
costs.computed_cost_per_ton
from public.get_typelO_equation_costs(
discount_rate,
equipment_life,
capital_recovery_factor,
emis_reduction,
converted_design_capacity,
annual_avg_hour s_pe r_ye ar,
variable_coefficientl,
variable_coefficient2,
variable_coefficient3,
variable_coefficient4,
variable_coefficient5) as costs
into annual_cost,
capital_cost,

variable_operation_maintenance_cost,
fixed_operation_maintenance_cost,
operation_maintenance_cost,
annualized_capital_cost,
computed_cost_per_ton;

IF annual_cost is not null THEN
valid_cost := true;
actual_equation_type := 'Type 10';

ELSE

valid_cost := false;
actual_equation_type := '-Type 10';

END IF;

-- adjust costs to the reference cost year

annual_cost := ref_yr_chained_gdp_adjustment_factor * annual_cost;
capital_cost := ref_yr_chained_gdp_adjustment_factor * capital_cost;
variable_operation_maintenance_cost := ref_yr_chained_gdp_adjustment_factor *
variable_operation_maintenance_cost;

fixed_operation_maintenance_cost := ref_yr_chained_gdp_adjustment_factor *
fixed_operation_maintenance_cost;

A-19


-------
Control Strategy Tool (CoST) Cost Equations

operation_maintenance_cost := ref_yr_chained_gdp_adjustment_factor *
operation_maintenance_cost;

annualized_capital_cost := ref_yr_chained_gdp_adjustment_factor *
annualized_capital_cost;

computed_cost_per_ton := ref_yr_chained_gdp_adjustment_factor *
computed_cost_per_ton;
return;

END IF;

valid_cost := false;
actual_equation_type := '-Type 10';

END IF;

-- Next the code will call the default CPT approach

— Type 10

CREATE OR REPLACE FUNCTION public.get_typelO_equation_costs(
discount_rate double precision,
equipment_life double precision,
capital_recovery_factor double precision,
emis_reduction double precision,
design_capacity double precision,
annual_avg_hours_per_year double precision,
capital_cost_multiplier double precision,
capital_cost_exponent double precision,

variable_operation_maintenance_cost_multiplier double precision,
fixed_operation_maintenance_cost_multiplier double precision,
fixed_operation_maintenance_cost_exponent double precision,

OUT annual_cost double precision,

OUT capital_cost double precision,

OUT variable_operation_maintenance_cost double precision,
OUT fixed_operation_maintenance_cost double precision,
OUT operation_maintenance_cost double precision,

OUT annualized_capital_cost double precision,

OUT computed_cost_per_ton double precision) AS $$

DECLARE

cap_recovery_factor double precision := capital_recovery_factor;

BEGIN

— NOTES:

-- design capacity must be in the units, MW

-- get capital recovery factor, calculate if it wasn't passed in...

IF coalesce(cap_recovery_factor, 0) =0 and coalesce(discount_rate, 0) != 0
and coalesce(equipment_life, 0) != 0 THEN

cap_recovery_factor :=
public.calculate_capital_recovery_factor(discount_rate, equipment_life);

END IF;

-- calculate capital cost

capital_cost := design_capacity * capital_cost_multiplier * 1000 * (250.0 /
design_capacity) A capital_cost_exponent;

-- calculate annualized capital cost

annualized_capital_cost := capital_cost * cap_recovery_factor;

-- calculate variable_operation_maintenance_cost
variable_operation_maintenance_cost :=
variable_operation_maintenance_cost_multiplier * design_capacity * 0.85 *
annual_avg_hour s_pe r_ye ar;

-- calculate fixed_operation_maintenance_cost

A-20


-------
Control Strategy Tool (CoST) Cost Equations

fixed_operation_maintenance_cost := design_capacity * 1000 *
fixed_operation_maintenance_cost_multiplier * (25 0 / design_capacity) A
fixed_operation_maintenance_cost_exponent;

-- calculate operation maintenance cost

operation_maintenance_cost := variable_operation_maintenance_cost +
fixed_operation_maintenance_cost;

-- calculate annual cost

annual_cost := annualized_capital_cost + operation_maintenance_cost;

-- calculate computed cost per ton
computed_cost_per_ton :=
case

when coalesce(emis_reduction, 0) <> 0 then annual_cost / emis_reduction
else null
end;

END;

$$ LANGUAGE plpgsql IMMUTABLE;

A.ll Equation Type 11 CoST Code

-- Code that funnels the source to the correct control measure cost equations.

—	NOTES:

-- design_capacity must be in the correct units, MW/hr is assumed if no units are
specified

—	Type 11

IF equation_type = 'Type 11' THEN

-- convert design capacity to mmBTU/hr
converted_design_capacity := 3.412 *
public.convert_design_capacity_to_mw(design_capacity, design_capacity_unit_numerator,
design_capacity_unit_denominator);

IF coalesce(converted_design_capacity, 0) <> 0 THEN
select costs.annual_cost,
costs.capital_cost,
costs.operation_maintenance_cost,
costs.annualized_capital_cost,
costs.computed_cost_per_ton
from public.get_typell_equation_costs(discount_rate,
equipment_life,
capital_recovery_factor,
capital_annualized_ratio,
emis_reduction,
converted_design_capacity,
variable_coefficientl,
variable_coefficient2,
variable_coefficient3,
variable_coefficient4,
variable_coefficient5) as costs
into annual_cost,
capital_cost,

operation_maintenance_cost,
annualized_capital_cost,
computed_cost_per_ton;

IF annual cost is not null THEN

A-21


-------
Control Strategy Tool (CoST) Cost Equations

valid_cost := true;
actual_equation_type := 'Type 11';

ELSE

valid_cost := false;
actual_equation_type := '-Type 11';

END IF;

-- adjust costs to the reference cost year

annual_cost := ref_yr_chained_gdp_adjustment_factor * annual_cost;
capital_cost := ref_yr_chained_gdp_adjustment_factor * capital_cost;
operation_maintenance_cost := ref_yr_chained_gdp_adjustment_factor *
operation_maintenance_cost;

annualized_capital_cost := ref_yr_chained_gdp_adjustment_factor *
annualized_capital_cost;

computed_cost_per_ton := ref_yr_chained_gdp_adjustment_factor *
computed_cost_per_ton;
return;

END IF;

valid_cost := false;
actual_equation_type := '-Type 11';

END IF;

-- Next the code will call the default CPT approach

-- Type 11 - SO2 Non-IPM Control Equations

CREATE OR REPLACE FUNCTION public.get_typell_equation_costs(
discount_rate double precision,
equipment_life double precision,
capital_recovery_factor double precision,
capital_annualized_ratio double precision,
emis_reduction double precision,

design_capacity double precision, -- needs to be in units of ittmBTU/hr
low_default_cost_per_ton double precision,
low_boiler_capacity_range double precision,
medium_default_cost_per_ton double precision,
medium_boiler_capacity_range double precision,
high_default_cost_per_ton double precision,

OUT annual_cost double precision,

OUT capital_cost double precision,

OUT operation_maintenance_cost double precision,

OUT annualized_capital_cost double precision,

OUT computed_cost_per_ton double precision) AS $$

DECLARE

cap_recovery_factor double precision := capital_recovery_factor;

BEGIN

-- get capital recovery factor, calculate if it wasn't passed in...

IF coalesce(cap_recovery_factor, 0) =0 and coalesce(discount_rate, 0) != 0
and coalesce(equipment_life, 0) != 0 THEN

cap_recovery_factor :=
public.calculate_capital_recovery_factor(discount_rate, equipment_life);

END IF;

-- figure out cost per ton
computed_cost_per_ton :=
case

when design_capacity <= low_boiler_capacity_range then low_default_cost_per_ton

when design_capacity > low_boiler_capacity_range and design_capacity <
medium_boiler_capacity_range then medium_default_cost_per_ton

when design_capacity >= medium_boiler_capacity_range then
hi gh_de fault_cos t_p e r_t on
end;

A-22


-------
Control Strategy Tool (CoST) Cost Equations

-- calculate annual cost

annual_cost := emis_reduction * computed_cost_per_ton;

-- calculate capital cost

capital_cost := annual_cost * capital_annualized_ratio;

-- calculate annualized capital cost

annualized_capital_cost := capital_cost * cap_recovery_factor;
-- calculate operation maintenance cost

operation_maintenance_cost := annual_cost - annualized_capital_cost;
END;

$$ LANGUAGE plpgsql IMMUTABLE;

A.12 Equation Type 12 CoST Code

-- Code that funnels the source to the correct control measure cost equations.
— NOTES:

-- stack flowrate was converted from cfs to cfm prior to getting here.
IF equation_type = 'Type 12' THEN

IF coalesce(stack_flow_rate, 0) <> 0 and coalesce(stack_temperature, 0) <> 0 THEN
select costs.annual_cost,
costs.capital_cost,

costs.variable_operation_maintenance_cost,
costs.fixed_operation_maintenance_cost,
costs.operation_maintenance_cost,
costs.annualized_capital_cost,
costs.computed_cost_per_ton
from public.get_typel2_equation_costs(
emis_reduction,
stack_flow_rate,
stack_temperature,
capital_recovery_factor,
variable_coefficientl,
variable_coefficient2,
variable_coefficient3,
variable_coefficient4) as costs
into annual_cost,
capital_cost,

variable_operation_maintenance_cost,
fixed_operation_maintenance_cost,
operation_maintenance_cost,
annualized_capital_cost,
computed_cost_per_ton;

IF annual_cost is not null THEN
valid_cost := true;
actual_equation_type := 'Type 12';

ELSE

valid_cost := false;
actual_equation_type := '-Type 12';

END IF;

-- adjust costs to the reference cost year

annual_cost := ref_yr_chained_gdp_adjustment_factor * annual_cost;
capital_cost := ref_yr_chained_gdp_adjustment_factor * capital_cost;
variable_operation_maintenance_cost := ref_yr_chained_gdp_adjustment_factor *
variable_operation_maintenance_cost;

fixed_operation_maintenance_cost := ref_yr_chained_gdp_adjustment_factor *
fixed_operation_maintenance_cost;

A-23


-------
Control Strategy Tool (CoST) Cost Equations

operation_maintenance_cost := ref_yr_chained_gdp_adjustment_factor *
operation_maintenance_cost;

annualized_capital_cost := ref_yr_chained_gdp_adjustment_factor *
annualized_capital_cost;

computed_cost_per_ton := ref_yr_chained_gdp_adjustment_factor *
computed_cost_per_ton;
return;

END IF;

valid_cost := false;
actual_equation_type := '-Type 12';

END IF;

-- Next the code will call the default CPT approach

— Type 12

CREATE OR REPLACE FUNCTION public.get_typel2_equation_costs(
emis_reduction double precision,	-- ton/yr

stack_flow_rate double precision, -- cfm
stack_temperature double precision, -- F
capital_recovery_factor double precision,
total_capital_investment_fixed_factor double precision,
total_capital_investment_variable_factor double precision,
annual_operating_cost_fixed_factor double precision,
annual_operating_cost_variable_factor double precision,

OUT annual_cost double precision,

OUT capital_cost double precision,

OUT variable_operation_maintenance_cost double precision,
OUT fixed_operation_maintenance_cost double precision,
OUT operation_maintenance_cost double precision,

OUT annualized_capital_cost double precision,

OUT computed_cost_per_ton double precision) AS $$

DECLARE

cap_recovery_factor double precision := capital_recovery_factor;

BEGIN

-- calculate capital cost

capital_cost := (coalesce(total_capital_investment_fixed_factor, 0.0) +
coalesce(total_capital_investment_variable_factor, 0.0)) * ((stack_flow_rate * 520 /
(stack_temperature + 460.0)) / 150000) A 0.6;

-- calculate fixed operation maintenance cost

fixed_operation_maintenance_cost := (coalesce(annual_operating_cost_fixed_factor,
0.0)) * ((stack_flow_rate * 520 / (stack_temperature + 460.0)) / 150000);

-- calculate variable operation maintenance cost
variable_operation_maintenance_cost :=
(coalesce(annual_operating_cost_variable_factor,0.0)) * ((stack_flow_rate * 520 /
(stack_temperature + 460.0)) / 150000);

-- calculate operation maintenance cost

operation_maintenance_cost := fixed_operation_maintenance_cost +
variable_operation_maintenance_cost;

-- calculate annualized capital cost

annualized_capital_cost := capital_cost *	cap_recovery_factor;

-- calculate annual cost

annual_cost := operation_maintenance_cost + annualized_capital_cost;

-- calculate computed cost per ton
computed_cost_per_ton :=
case

A-24


-------
Control Strategy Tool (CoST) Cost Equations

when coalesce(emis_reduction, 0) <> 0 then annual_cost / emis_reduction
else null
end;

END;

$$ LANGUAGE plpgsql IMMUTABLE;

A.13 Equation Type 13 CoST Code

Equation Type 13 has not been implemented in CoST.

A.14 Equation Type 14 CoST Code

This is the portion of the source code that is specific for Equation Type 14. The complete source
code with overall logic is not included here.

--type 14 variables
tl4_use_equation text;
tl4_fa text;
tl4_fd text;
tl4_noducts text;
tl4_cpm text;
tl4_tci text;
tl4_tac text;

-- TYPE 14 definition Fabric Filter 	

/*

F_a=(V_Exhaust )(DC)/60 Equation 1
Where:

Fa = Exhaust flowrate, ACFM

VExhaust = Relative Exhaust Volume, ACF/MMBtu --> ' | |
control_measure_equation_table_alias || '.valuel

DC = Design Capacity of Unit, MMBtu/hr --> convert_design_capacity_expression

tl4_fa	|| control_measure_equation_table_alias || '.value5 * (' ||

convert_design_capacity_expression || ') / 60.0 || ') ';

F_a = ' || control_measure_equation_table_alias || '.value5 * (' ||
convert_design_capacity_expression || ') / 60.0

F_d=F_a ( (460 + 68)/ (460+T)) (l-%_Moist/100)	Equation 2

tl4_fd := '((' || tl4_fa II ') * ((460.0 + 68.0)/(460.0 + ' II inv_table_alias ||
'.stktemp)) * (1.0 - ' || control_measure_equation_table_alias || '.value2 / 100.0))';

F_d = (' II control_measure_equation_table_alias || '.value5 * (' ||
convert_design_capacity_expression || ') / 60.0) * ((4 60.0 + 68.0)/(4 60.0 + ' ||
inv_table_alias || '.stktemp)) * (1.0 - ' || control_measure_equation_table_alias ||
'.value2 / 100.0)

Where:

Fd = Exhaust flowrate, DSCFM
Fa = Exhaust flowrate, ACFM

T = Assumed Stack Gas Temperature, A°F --> ' || inv_table_alias || '.stktemp
%Moist = Assumed Stack Gas Moisture Content, % --> ' ||
control_measure_equation_table_alias || '.valuel

A-25


-------
Control Strategy Tool (CoST) Cost Equations

tl4_noducts := '(case when ' || tl4_fd || ' <= 154042.0 then 1 else ceiling(' ||
tl4_fd II ' / 154042.0) end)';

TCI=(105.91) (F_d ) + (699754.7) + [ (0.560) (a's(F_a )/#_Ducts )A2 ] + [ (1096.141)
eA (0 . 017) (a"s(F_a )/#_Ducts ) ] + [ (33.977) eA (0 . 014) (a"s(F_a )/#_Ducts ) ]

tl4_tci := '((105.91) * (' II tl4_fd || ') + (699754.7) + ( (0.560) * (sqrt(' || tl4_fa ||
')/' || tl4_noducts || ' )A2) + ((1096.141) * exp((0.017) * (sqrt(' || tl4_fa || ')/'
II tl4_noducts || ' ))) + ((33.977) * exp((0.014) * (sqrt(' || tl4_fa || ')/' ||
tl4_noducts || ' ))))';

Where:

Fd = Exhaust Flowrate, dry standard cubic feet per minute (DSCFM)

Fa = Exhaust Flowrate, actual cubic feet per minute (ACFM)

#Ducts = If Fd aVon 154 042, #Ducts = 1;

If Fd > 154042, #Ducts = Fd / 154042

select case when 154044.0 <= 154042.0 then 1 else ceiling(1540404.0 / 154042.0) end
B-lb: TOTAL ANNUALIZED COSTS (TAC)

TAC=[ (17. 44) (a€-Opa€-_Hrs )] + { (TCI) [ ( 0.072) + ( ( (i) (1+i)A(a€-Eqa€-_Life ))/((1+i)A(a€-
Eqa€—_Life )-1))] } + {(F_a ) [ (4.507) + (0 . 0000124) (a€-Opa€-_Hrs )-(4.184) ( ( (i) (l+i)A(a€-
Eqa€—_Life ))/((1+i)A(a€-Eqa€—_Life )-1))]}+{(F_d )(a€-Opa€—_Hrs
)[(0.00376) + (0.00181) (C_PM )]}

tl4_tac := ' [(17.44) (' || inv_table_alias || '.annual_avg_hours_per_year || ')]+{(' II
tl4_tci || ') [ (0.072) + ( ' || capital_recovery_factor_expression || ')]} + {(' II tl4_fa
I I ') [ (4.507) + (0.0000124) (' | | inv_table_alias | | ' .annual_avg_hours_per_year | | ')-
(4.184) (' || capital_recovery_factor_expression | | ')]} + {(' I I tl4_fd | | ') (' II
inv_table_alias | | '.annual_avg_hours_per_year | | ') [(0.00376) + (0.00181) (C_PM )]}';

Where:

Fd = Exhaust Flowrate, dry standard cubic feet per minute (DSCFM)

OpHrs = Annual operating hours of unit (hrs/yr)

TCI= Total Capital Investment ($)

Fa = Exhaust Flowrate, actual cubic feet per minute (ACFM)

CPM= Concentration of PM in stack gas, grains per dry standard cubic foot (gr/dscf)
i = Interest rate expressed as a fraction of 1 (percentage divided by 100)

EqLife = Estimated equipment life, years

Equation Type Definition:

Measure Specific Equation Type Variable Inputs: valuel --> % Moisture
Inventory Inputs:
design capacity
design capacity units
stack temperature
stack flow rate (in cfm)
operating hours (in hrs/yr)

*/

tl4_use_equation := 'coalesce ( ' | | equation_type_table_alias | | ' .name, ' ' ' ') = ' 'Type
14'' and coalesce(' || convert_design_capacity_expression || ', 0) <> 0 and coalesce('
I | inv_table_alias | | ' .stktemp, 0) <> 0 and coalesce ( ' | | stkflow_expression | | ', 0)
<> 0 and coalesce ( ' | | inv_table_alias | | ' .annual_avg_hours_per_year, 0.0) <> 0.0';

--use brenda shines approach

tl4_fa := '(' || stkflow_expression || ')';

tl4_fd := '((' || tl4_fa II ') * ((460.0 + 68.0)/(460.0 + ' II inv_table_alias ||
' .stktemp)) * (1.0 - ' | | control_measure_equation_table_alias | | ' .valuel / 100.0)) ' ;

A-26


-------
Control Strategy Tool (CoST) Cost Equations

tl4_noducts := '(case when ' || tl4_fd || ' <= 154042.0 then 1 else round(' || tl4_fd
II'/ 154042.0) end)';

tl4_cpm ¦.= '(' || emis_sql || ') * 1.725 * 15.4323584 / (' || tl4_fd || ' )';

/*1 ton/year = 1.725 grams/minute (from David) 1 gram = 15.4323584 grains */

tl4_tci := '((105.91) * (' II tl4_fd || ') + (699754.7) + ( (0.560) * (sqrt(' || tl4_fa ||
')/' || tl4_noducts || ' )A2) + ((1096.141) * exp((0.017) * (sqrt(' || tl4_fa || ')/'
II tl4_noducts || ' ))) + ((33.977) * exp((0.014) * (sqrt(' || tl4_fa || ')/' ||
tl4_noducts || ' ))))';

tl4_tac := ' ( (17.44) * (' | | inv_table_alias | | ' .annual_avg_hours_per_year)) + ((' II
tl4_tci || ') * ( (0.072) +(' || capital_recovery_factor_expression || '))) + ((' II
tl4_fa || ') * ( (4.507) + (0.0000124) * (' || inv_table_alias ||

' .annual_avg_hours_per_year)-(4.184) * (' I I capital_recovery_factor_expression | |
')))+((' || tl4_fd || ') * (' || inv_table_alias || '.annual_avg_hours_per_year) *
( (0.00376) +(0.00181) * (' II tl4_cpm || ')))';

A.15 Equation Type 15 CoST Code

This is the portion of the source code that is specific for Equation Type 15. The complete source
code with overall logic is not included here.

--type 15 variables
tl5_use_equation text;
tl5_fa text;
tl5_noducts text;
tl5_ecl text;
tl5_ec2 text;
tl5_pm_emis_rate text;
tl5_tci text;
tl5_tac text;

-- TYPE 15 definition Electrostatic Precipitator 	

/*

TCI = { (12.265) (a€-ECa€-_l ) [(5.266) (F_a )]A(a€-ECa€-_2 ) }+[ ( 0.784) (F_a/#_Ducts
)] + (#_Ducts ){[ (2237.13) (eA (0.017) (a's(F_a )/#_Ducts ) )] + [ ( 69 . 345) (e^ (0.014) (a"s(F_a
)/#_Ducts ) )] + (17588.69)}

Where:

EC1= First equipment cost factor for ESP;

If Fa aV„¥ 9495, EC1 = 57.87;

If Fa < 9495, EC1 = 614.55

Fa = Exhaust Flowrate, actual cubic feet per minute (ACFM)

EC2 = Second equipment cost factor for ESP;

If Fa aV„¥ 9495, EC2 = 0.8431;

If Fa < 9495, EC2 = 0.6276

#Ducts = If Fa < 308084, #Ducts = 1;

If 308084 aVon Fa < 462126, #Ducts = 2;

If 462126 aVon Fa < 616168, #Ducts = 3;

If Fa aVo¥ 616168, #Ducts = 4

B-2b: TOTAL ANNUALIZED COSTS (TAC)

TAC=[ (10. 074) (a€-Opa€-_Hrs )] + [ (0 . 052) (F_a )]+{ (0.00656) (1.04+ ( ( (i) (1+i)A(a€-Eqa€-
_Life ) )/((1+i)A(a€-Eqa€-_Life )-1) )) ((a€-ECa€-_l ) [ (5.266) (F_a )]A(a€-ECa€-_2 )
)}+[ (0.021) (a€-Opa€—_Hrs ) (E_PM ) (DC)] + {(0.0000117) (F_a ) (a€-Opa€-_Hrs
)[ (1.895) + ( (479.85) (l/a"s(F_a ))A1.18 )]}+[(0.000715)(a€-Opa€-_Hrs ) (F_a
)] + { (0.04+( ( (i) (1+i)A(a€-Eqa€—_Life ))/( (1+i)A(a€-Eqa€-_Life )-1)) ) (#_Ducts ) [(0.783)

A-27


-------
Control Strategy Tool (CoST) Cost Equations

(a~s(F_a )/#_Ducts )^2+(2237.44) (eA(0.0165) (a~s(F_a )/#_Ducts )

) + (69.355) (eA (0.0140) (a's(F_a )/#_Ducts ) ) + (17591.15)] }

Where:

OpHrs = Annual operating hours of unit (hrs/yr)

Fa = Exhaust Flowrate, actual cubic feet per minute (ACFM)

i = Interest rate expressed as a fraction of 1 (percentage divided by 100)

EgLife = Estimated eguipment life, years
EC1= First eguipment cost factor for ESP;

If Fa aV„¥ 9495, EC1 = 57.87;

If Fa < 9495, EC1 = 614.55

EC2 = Second eguipment cost factor for ESP;

If Fa aV„¥ 9495, EC2 = 0.8431;

If Fa < 9495, EC2 = 0.6276

EPM= PM emission rate, pounds per million British thermal units (lb/MMBtu)

DC = Design capacity of boiler, million British thermal units per hour (MMBtu/hr)

#Ducts = If Fa < 308084, #Ducts = 1;

If 308084 aVon Fa < 462126, #Ducts = 2;

If 462126 aVon Fa < 616168, #Ducts = 3;

If Fa aVo¥ 616168, #Ducts = 4

Eguation Type Definition:

Measure Specific Eguation Type Variable Inputs: valuel --> % Moisture
Inventory Inputs:
design capacity
design capacity units
stack temperature
stack flow rate (in cfm)
operating hours (in hrs/yr)

*/

tl5_use_eguation := 'coalesce(' || eguation_type_table_alias || '.name,'''') = ''Type
15'' and coalesce(' || convert_design_capacity_expression || ', 0) <> 0 and coalesce('

I	| inv_table_alias | | ' .stktemp, 0) <> 0 and coalesce ( ' | | stkflow_expression | | ', 0)
<> 0 and coalesce ( ' | | inv_table_alias | | ' .annual_avg_hours_per_year, 0.0) <> 0.0';

--use brenda shines approach

tl5_fa := '(' || stkflow_expression	||	')';

tl5_ecl := '(case when ' || tl5_fa	||	' < 9495.0 then 614.55 else 57.87 end)';

tl5_ec2 := '(case when ' || tl5_fa	||	' < 9495.0 then 0.6276 else 0.8431 end)';

tl5_noducts := '(case when ' || tl5_fa || ' < 308084.0 then 1 when ' || tl5_fa || '
>= 308084.0 and ' || tl5_fa II ' < 462126.0 then 2 when ' || tl5_fa I I ' >= 462126.0
and ' | | tl5_fa I I ' < 616168.0 then 3 else 4 end)';

tl5_pm_emis_rate ¦.= '(' || emis_sgl II ') * 2000.0 / 365.0 / 24.0 / (3.412 * ' II
convert_design_capacity_expression || ')';

tl5_tci := '((12.265) * (' II tl5_ecl II ') * ((5.266) * (' II tl5_fa || ' ))A(' II
tl5_ec2 || ') ) + ( (0.784) * (' || tl5_fa || '/' || tl5_noducts || ')) + (' II tl5_noducts

II	') * (((2237.13) * (exp( (0.017) * (sgrt(' || tl5_fa || ')/' || tl5_noducts ||
')))) + ( (69.345) * (exp((0.014) * (sgrt(' || tl5_fa || ')/' || tl5_noducts ||

'))))+(17588.69))';

tl5_tac := ' ((10.074) * (' | | inv_table_alias | |

',annual_avg_hours_per_year))+((0.052) * (' II tl5_fa || '))+((0.00656) * (1.04+(C ||
capital_recovery_factor_expression || '))) * ((' II tl5_ecl || ') * ((5.266) * (' ||
tl5_fa || ' ))A(' II tl5_ec2 || ') )) + ( (0.021) * (' || inv_table_alias ||
'.annual_avg_hours_per_year) * (' || tl5_pm_emis_rate || ') * (3.412 * ' ||
convert_design_capacity_expression | | ')) + ((0.0000117) * (' | | tl5_fa | | ') * (' | |

A-28


-------
Control Strategy Tool (CoST) Cost Equations

inv_table_alias | | '.annual_avg_hours_per_year) * ( (1.895) + ( (479.85) * (l/sqrt(' | |
tl5_fa || '))A1.18 ))) + ( (0.000715) * (' || inv_table_alias ||
' .annual_avg_hours_per_year) * (' | | tl5_fa | | ')) + ((0.04+(( ' | |

capital_recovery_factor_expression || '))) * (' II tl5_noducts || ') * ((0.783) *
(sqrt(' || tl5_fa || ')/(' II tl5_noducts || '))^2 + (2237.44) * (exp ( (0.0165) * (sqrt('
II tl5_fa || ')/(' II tl5_noducts || ')))) + (69.355) * (exp((0.0140) * (sqrt(' ||
tl5_fa || ')/(' II tl5_noducts || '))))+(17591.15)))';

A-29


-------
Control Strategy Tool (CoST) Cost Equations

A.16 Equation Type 16 CoST Code

This is the portion of the source code that is specific for Equation Type 16. The complete source
code with overall logic is not included here.

--type 16 variables
tl6_use_equation text;
tl6_fa text;
tl6_noscrubbers text;
tl6_so2_mole_conc text;
tl6_tci text;
tl6_tac text;

— TYPE 16 definition WET SCRUBBER 	

/*

APPENDIX B-3: WET SCRUBBER COST EQUATIONS

B-3a: TOTAL CAPITAL INVESTMENT (TCI)

TCI=[ (2.88) (#_Scrub ) (F_a )] + [ (1076 . 54) (#_Scrub ) V((F_a ) )] + [ (9.759) (F_a
)] + [ (360.463) V((F_a ) )]

Where:

#Scrub = If Fa < 149602, #Scrub = 1;

If 149602 < Fa < 224403, #Scrub = 2;

If 224403 < Fa < 299204, #Scrub = 3;

If 299204 < Fa < 374005, #Scrub = 4;

If Fa > 374005, #Scrub = 5

Fa = Exhaust Flowrate, actual cubic feet per minute (ACFM)

B-3b: TOTAL ANNUALIZED COSTS (TAC)

TAC=[(#_Scrub )(TCI)(((i) (1+i)A([Eq]_Life ))/((1+i)A([Eq]_Life )-

1))] + [ (0.04) (TCI)] + { (20.014) (#_Scrub ) (F_a )([Op]_Hrs ) [C_S02-(C_S02 )((100-98)/(100-
(98) (C_S02 ) ))]} + [ (16.147) (#_Scrub ) ([Op]_Hrs )]+{(0.0000117)(F_a )([Op]_Hrs
)(#_Scrub )[((479.85) (l/V(F_a ))A1.18 )+(6.895)]}+[(0.0000133)([Op]_Hrs )(#_Scrub
) (F_a )]

Where:

#Scrub = If Fa < 149602, #Scrub = 1;

If 149602 < Fa < 224403, #Scrub = 2;

If 224403 < Fa < 299204, #Scrub = 3;

If 299204 < Fa < 374005, #Scrub = 4;

If Fa > 374005, #Scrub = 5
TCI= Total Capital Investment ($)

i = Interest rate expressed as a fraction of 1 (percentaqe divided by 100)

EqLife = Estimated equipment life, years

Fa = Exhaust Flowrate, actual cubic feet per minute (ACFM)

CS02 = Mole fraction of S02 in exhaust qas
OpHrs = Annual operatinq hours of unit (hrs/yr)

CS02 calculation:

Calculate volume (ft3/lb-mole) of NOx in qaseous form under standard conditions (60 F,
1 atm) usinq Ideal Gas Law, pV = nRT or V/n = RT/p, where:

V = volume in ft3

n = molecular weiqht of S02 (64.06 lb/lb-mole)

A-30


-------
Control Strategy Tool (CoST) Cost Equations

R = gas constant (0.7302 atm-ft3/lb-mole R)

T = absolute temperature in Rankin (F + 460) = 60 + 460 = (520 R)
p = pressure in atmospheres (1 atm)

Ideal Gas Law approximates the volume of a gas under certain conditions.

V/n = (0.7302 x 520) / (1) = 379.7 ft3/lb-mole

Calculate S02 emissions (lb-mole/yr):

n = 53.33 tons/yr S02 x 2000 lb/ton x 1 lb-mole / 64.06 lbs S02 = 1,665 lb-
mole/ yr

Convert S02 emissions (lb-mole/yr) to S02 volumetric flowrate (ft3/min):

1,665 lb-mole/yr x 1 yr/8736 hrs x 1 hr/60 min x 379.7ft3/lb-mole = 1.206 ft3/min

Calculate outlet concentration of S02 (ppmv):
ppmv S02 = ( S02 emissions (ft3/min) / Stack vol flowrate scfm ) x 10^6
ppmv S02 = ( 1.206 ft3/min / 20,170 ft3/min ) x 10^6 = 59.79 ppmv
mole fraction S02 = 59.79 ppmv / 10^6 = 5.979e-5 mole fraction S02
Eguation Type Definition:

Measure Specific Eguation Type Variable Inputs: NONE
Inventory Inputs:

stack flowrate (in cfm)
operating hours (in hrs/yr)

*/

tl6_use_eguation := 'coalesce(' || eguation_type_table_alias || '.name,'''') = ''Type
16' ' and coalesce ( ' | | stkflow_expression | | ', 0) <> 0 and coalesce(' | |
inv_table_alias || '.annual_avg_hours_per_year, 0.0) <> 0.0';
tl6_fa := '(' || stkflow_expression || ')';

tl6_noscrubbers := '(case when ' || tl6_fa || ' < 149602.0 then 1 when ' || tl6_fa

I	I ' >= 149602.0 and ' | | tl6_fa I I ' < 224403.0 then 2 when ' | | tl6_fa I I ' >=
224403.0 and ' || tl6_fa II ' < 299204.0 then 3 when ' || tl6_fa I I ' >= 299204.0 and
' || tl6_fa II ' < 374005.0 then 4 else 5 end)';

tl6_so2_mole_conc :='((' II emis_sgl || ') * 2000.0 / (64.06) / ' || inv_table_alias
I| '.annual_avg_hours_per_year / 60 * ((0.7302 * 520) / (1.0)) / ( (' || tl6_fa || ')
* 520 / ((' || inv_table_alias || '.stktemp) + 460.0)))';

tl6_tci := '((2.88) * (' || tl6_noscrubbers || ') * (' || tl6_fa || ')) + ((1076.54) *
(' || tl6_noscrubbers || ') * sgrt(' || tl6_fa || ')) + ( (9.759) * (' || tl6_fa ||
')) + ( (360.463) * sgrt(' || tl6_fa ||

tl6_tac := '((' || tl6_noscrubbers || ') * (' || tl6_tci || ') * (' ||
capital_recovery_factor_expression || ")) + ((0.04) * (' II tl6_tci || ')) + ( (20 . 014) *
(' II tl6_noscrubbers || ') * (' || tl6_fa || ') * (' || inv_table_alias ||
' .annual_avg_hours_per_year) * ((' | | tl6_so2_mole_conc | | ' )-(' II tl6_so2_mole_conc

II	') * ( (100.0-98.0)/(100.0-(98.0) * (' II tl6_so2_mole_conc || ') )))) + ((16.147) *
(' II tl6_noscrubbers || ') * (' || inv_table_alias ||

'.annual_avg_hours_per_year)) + ((0.0000117) * (' I I tl6_fa | | ') * (' | |
inv_table_alias || '.annual_avg_hours_per_year) * (' || tl6_noscrubbers || ') *
(((479.85) * (1/sgrt(' || tl6_fa || '))A1.18 ) + (6.895))) + ((0.0000133) * (' ||
inv_table_alias || '.annual_avg_hours_per_year) * (' || tl6_noscrubbers || ') * (' ||
tl6 fa II '))';

A-31


-------
Control Strategy Tool (CoST) Cost Equations

A.17 Equation Type 17 CoST Code

This is the portion of the source code that is specific for Equation Type 17. The complete source
code with overall logic is not included here.

--type 17 variables
tl7_use_equation text;
tl7_fa text;
tl7_fd text;
tl7_noducts text;
tl7_pm_conc text;
tl7_so2_conc text;
tl7_tci text;
tl7_tac text;

-- TYPE 17 definition Dry Injection/fabric Filter System (DIFF) 	

/*

APPENDIX B-4: DRY INJECTION/FABRIC FILTER SYSTEM (DIFF) COST EQUATIONS

B-4a: TOTAL CAPITAL INVESTMENT (TCI)

TCI=[ (143.76) (F_d )] + [(0.610) (a"s(F_a )/#_Ducts )A2 ] + [(1757.65) e'M 0 . 017) (a"s(F_a
)/#_Ducts ) ] + [ (59.973) e^ (0.014) (a"s(F_a )/#_Ducts ) ] + (931911.04)

Where:

Fd = Exhaust Flowrate, dry standard cubic feet per minute (DSCFM)

Fa = Exhaust Flowrate, actual cubic feet per minute (ACFM)

#Ducts = If Fd aVon 154 042, #Ducts = 1;

If Fd > 154042, #Ducts = Fd / 154042

B-4b: TOTAL ANNUALIZED COSTS (TAC)

TAC=[ (0.00162) (a€-Opa€-_Hrs ) (F_d )] + [ (17 . 314) (a€-Opa€-_Hrs )] + [( 0 . 00000105) (C_S02
) (F_d ) (a€-Opa€—_Hrs )] + [ (0 . 0000372) (a€-Opa€—_Hrs ) (F_a )] + [( 0.000181) (a€-Opa€—_Hrs
) (C_PM ) (F_d )] + [ (0.847) (1-(( (i) (1+i)A(a€-Eqa€-_Life ))/((1+i)A(a€-Eqa€-_Life )-
1)) ) (F_a )] + [ (0.04) + ( ( (i) (1+i)A(a€-Eqa€—_Life ))/((1+i)A(a€-Eqa€-_Life )-
1))]{[ (0.032) (TCI)] + [ (0.606) (a's(F_a )/#_Ducts )A2 ] + [(1757.65) e^ (0.017) (a"s(F_a
)/#_Ducts ) ] + [ (53.973) e^ (0.014) (a"s(F_a )/#_Ducts ) ] + (13689.81)}

Where:

Fd = Exhaust Flowrate, dry standard cubic feet per minute (DSCFM)

OpHrs = Annual operating hours of unit (hrs/yr)

CS02 = Concentration of S02 in stack gas, dry parts per million by volume (ppmvd)
Fa = Exhaust Flowrate, actual cubic feet per minute (ACFM)

CPM= Concentration of PM in stack gas, grains per dry standard cubic foot (gr/dscf)
i = Interest rate expressed as a fraction of 1 (percentage divided by 100)

EqLife = Estimated equipment life, years
#Ducts = If Fd aVon 154 042, #Ducts = 1;

If Fd > 154042, #Ducts = Fd / 154042

Equation Type Definition:

Measure Specific Equation Type Variable Inputs: valuel --> % Moisture
Inventory Inputs:

stack temperature

stack flow rate (in cfm)

operating hours (in hrs/yr)

*/

A-32


-------
Control Strategy Tool (CoST) Cost Equations

tl7_use_equation := 'coalesce ( ' | | equation_type_table_alias | | ' .name, ' ' ' ') = ' 'Type
11' ' and coalesce(' || inv_table_alias || '.stktemp, 0) <> 0 and coalesce(' ||
stkflow_expression || ', 0) <> 0 and coalesce(' || inv_table_alias ||
'.annual_avg_hours_per_year, 0.0) <> 0.0';

--use brenda shines approach

tl7_fa	|| stkflow_expression || ' ) ';

tl7_fd :='((' II tl7_fa || ') * ((4 60.0 + 68.0)/(4 60.0 + ' || inv_table_alias ||
' .stktemp)) * (1.0 - ' | | control_measure_equation_table_alias | | ' .valuel / 100.0)) ' ;

tl7_noducts := '(case when ' || tl7_fd || ' <= 154042.0 then 1 else round(' || tl7_fd
II'/ 154042.0) end)';

tl7_pm_conc := '(' || emis_sql || ') * 1.725 * 15.4323584 / (' || tl7_fd || ')'; /*1
ton/year = 1.725 grams/minute (from David) 1 gram = 15.4323584 grains */

tl7_so2_conc :='((' II so2_emis_sql || ') * 2000.0 / (64.06) / ' || inv_table_alias
I| '.annual_avg_hours_per_year / 60 * ((0.7302 * 520) / (1.0)) / ( (' || tl7_fa || ')
* 520 / ((' || inv_table_alias || '.stktemp) + 460.0))) * 10A6';

tl7_tci := '((143.76) * (' II tl7_fd || '))+((0.610) * (sqrt(' || tl7_fa || ')/' ||
tl7_noducts || ')A2 )+((1757.65) * exp((0.017) * (sqrt(' || tl7_fa || ')/' ||
tl7_noducts || "))) + ((59.973) * exp ((0.014) * (sqrt(' | | tl7_fa | | ')/' II tl7_noducts
II '))) + (931911.04) ' ;

tl7_tac := ' ( (0.00162) * (' | | inv_table_alias | | ' .annual_avg_hours_per_year) * (' | |
tl7_fd || ')) + ( (17.314) * (' || inv_table_alias ||

'.annual_avg_hours_per_year))+((0.00000105) * (' || tl7_so2_conc || ' ) * (' II tl7_fd
II ') * (' || inv_table_alias || '.annual_avg_hours_per_year))+((0.0000372) * (' ||
inv_table_alias | | '.annual_avg_hours_per_year) * (' | | tl7_fa | | ')) + ( (0.000181) * ('
I| inv_table_alias || '.annual_avg_hours_per_year) * (' || tl7_pm_conc || ') * (' ||
tl7_fd || ')) + ( (0.847) * (l-(' II capital_recovery_factor_expression || ')) * (' ||
tl7_fa || ')) + ((0.04) + ( ' || capital_recovery_factor_expression || ')) * (((0.032) * ('
II tl7_tci || ')) + ( (0.606) * (sqrt(' || tl7_fa || ')/' || tl7_noducts || ')A2
) + ( (1757.65) * exp((0.017) * (sqrt(' || tl7_fa || ')/' || tl7_noducts ||

'))) + ( (53.973) * exp( (0.014) * (sqrt(' || tl7_fa || ')/' || tl7_noducts ||
'))) + (13689.81)) ';

A.18 Equation Type 18 CoST Code

This is the portion of the source code that is specific for Equation Type 18. The complete source
code with overall logic is not included here.

--type 18 variables
tl8_use_equation text;
tl8_fa text;
tl8_fd text;
tl8_so2_conc text;
tl8_tci text;
tl8_tac text;

— TYPE 18 definition INCREASED CAUSTIC INJECTION RATE FOR EXISTING DRY INJECTION

CONTROL 	

/*

APPENDIX B-5: INCREASED CAUSTIC INJECTION RATE FOR EXISTING DRY INJECTION CONTROL
COST EQUATIONS

A-33


-------
Control Strategy Tool (CoST) Cost Equations

B-5a: TOTAL CAPITAL INVESTMENT (TCI)

TCI=0

Where:

N/A

B-5b: TOTAL ANNUALIZED COSTS (TAC)

TAC=(0.00000387)(C_S02 )(F_d )(a€-Opa€-_Hrs )

Where:

CS02 = Concentration of S02 in stack gas, dry parts per million by volume (ppmvd)
Fd = Exhaust Flowrate, dry standard cubic feet per minute (DSCFM)

OpHrs = Annual operating hours of unit (hrs/yr)

Eguation Type Definition:

Measure Specific Eguation Type Variable Inputs: valuel --> % Moisture
Inventory Inputs:

stack temperature
stack flowrate (in cfm)
operating hours (in hrs/yr)

*/

tl8_use_eguation := 'coalesce ( ' | | eguation_type_table_alias | | ' .name, ' ' ' ') = ' 'Type
18'' and coalesce(' || inv_table_alias || '.stktemp, 0) <> 0 and coalesce(' ||
stkflow_expression || ', 0) <> 0 and coalesce(' || inv_table_alias ||
'.annual_avg_hours_per_year, 0.0) <> 0.0';

--use brenda shines approach

tl8_fa := '(' || stkflow_expression || ')';

tl8_fd := '((' || tl8_fa II ') * ((460.0 + 68.0)/(460.0 + ' II inv_table_alias ||
' .stktemp)) * (1.0 - ' | | control_measure_eguation_table_alias | | ' .valuel / 100.0)) ' ;

tl8_so2_conc :='((' II emis_sgl || ') * 2000.0 / (64.06) / ' || inv_table_alias ||
'.annual_avg_hours_per_year / 60 * ((0.7302 * 520) / (1.0)) / ( ('II tl8_fa || ')
* 520 / ((' || inv_table_alias || '.stktemp) + 460.0))) * 10A6';

tl8_tci := '0.0';

tl8_tac := '(0.00000387) * (' || tl8_so2_conc || ') * (' || tl8_fd || ') * (' ||
inv_table_alias || '.annual_avg_hours_per_year)';

A.19 Equation Type 19 CoST Code

This is the portion of the source code that is specific for Equation Type 19. The complete source
code with overall logic is not included here.

--type 19 variables
tl9_use_eguation text;
tl9_fa text;
tl9_fd text;
tl9_noducts text;
tl9_so2_conc text;
tl9_tci text;
tl9 tac text;

A-34


-------
Control Strategy Tool (CoST) Cost Equations

— TYPE 19 definition SPRAY DRYER ABSORBER 	

/*

APPENDIX B-6: SPRAY DRYER ABSORBER COST EQUATIONS

B-6a: TOTAL CAPITAL INVESTMENT (TCI)

TCI=[(143.76) (F_d )] + [(0.610) (a"s(F_a )/#_Ducts )A2 ] + [ (17412.26) (0.017) (a"s(F_a
)/#_Ducts ) ] + [ (53.973) (0.014) (a"s(F_a )/#_Ducts ) ] + (931911.04)

Where:

Fd = Exhaust Flowrate, dry standard cubic feet per minute (DSCFM)

Fa = Exhaust Flowrate, actual cubic feet per minute (ACFM)

#Ducts = If Fd aVon 154 042, #Ducts = 1;

If Fd > 154042, #Ducts = Fd / 154042

B-6b: TOTAL ANNUALIZED COSTS (TAC)

TAC=(a€-Opa€—_Hrs ){[ (0.00162) (F_d )] + [ (0 . 000000684) (C_S02 )(F_d )] + [ (0 . 0000372) (F_a
)] + (21.157) } + { [0.072+( ( (i) (1+i)A(a€-Eqa€-_Life ) )/((1+i)A(a€-Eqa€-_Life )-l))](TCI)}

Where:

Fd = Exhaust Flowrate, dry standard cubic feet per minute (DSCFM)

Fa = Exhaust Flowrate, actual cubic feet per minute (ACFM)

OpHrs = Annual operating hours of unit (hrs/yr)

CS02 = Concentration of S02 in stack gas, dry parts per million by volume (ppmvd)
TCI= Total Capital Investment ($)

i = Interest rate expressed as a fraction of 1 (percentage divided by 100)

EqLife = Estimated equipment life, years

Equation Type Definition:

Measure Specific Equation Type Variable Inputs: valuel --> % Moisture
Inventory Inputs:

stack temperature
stack flowrate (in cfm)
operating hours (in hrs/yr)

*/

tl9_use_equation := 'coalesce ( ' | | equation_type_table_alias | | ' .name, ' ' ' ') = ' 'Type
19'' and coalesce(' || inv_table_alias || '.stktemp, 0) <> 0 and coalesce(' ||
stkflow_expression || ', 0) <> 0 and coalesce(' || inv_table_alias ||
'.annual_avg_hours_per_year, 0.0) <> 0.0';

--use brenda shines approach

tl9_fa := '(' || stkflow_expression || ')';

tl9_fd :='((' II tl9_fa || ') * ((4 60.0 + 68.0)/(4 60.0 + ' || inv_table_alias ||
' .stktemp)) * (1.0 - ' | | control_measure_equation_table_alias | | ' .valuel / 100.0)) ' ;

tl9_noducts := '(case when ' || tl9_fd || ' <= 154042.0 then 1 else round(' || tl9_fd
II'/ 154042.0) end)';

tl9_so2_conc :='((' II emis_sql || ') * 2000.0 / (64.06) / ' || inv_table_alias ||
'.annual_avg_hours_per_year / 60 * ((0.7302 * 520) / (1.0)) / ( ('II tl9_fa || ')
* 520 / ((' || inv_table_alias || '.stktemp) + 460.0))) * 10A6';

tl9_tci := '((143.76) * (' II tl9_fd || '))+((0.610) * (sqrt(' || tl9_fa || ')/' ||
tl9_noducts || ')A2 ) + ( (17412.26) * exp((0.017) * (sqrt(' || tl9_fa || ')/' ||
tl9_noducts || ")))+((53.973) * exp((0.014) * (sqrt(' || tl9_fa || ')/' || tl9_noducts
II '))) + (931911. 04) ' ;

A-35


-------
Control Strategy Tool (CoST) Cost Equations

tl9_tac	|| inv_table_alias || '.annual_avg_hours_per_year) * (((0.00162) * ('

II tl9_fd || ')) + ( (0.000000684) * (' II tl9_so2_conc II ') * (' II tl9_fd II
')) + ( (0.0000372) * (' II tl9_fa || ')) + (21.157)) + ( (0.072+( ' II
capital_recovery_factor_expression || ')) * (' || tl9_tci || '))';

A.20 NOx Ptnonipm CoST Code - Default Cost per Ton Equations

CREATE OR REPLACE FUNCTION public.get_default_costs(
discount_rate double precision,
equipment_life double precision,
capital_annualized_ratio double precision,
capital_recovery_factor double precision,
ref_yr_cost_per_ton double precision,
emis_reduction double precision,

OUT annual_cost double precision,

OUT capital_cost double precision,

OUT operation_maintenance_cost double precision,

OUT annualized_capital_cost double precision,

OUT computed_cost_per_ton double precision) AS $$

DECLARE

cap_recovery_factor double precision := capital_recovery_factor;

BEGIN

-- get capital recovery factor, calculate if it wasn't passed in...
IF coalesce(discount_rate, 0) != 0 and coalesce(equipment_life, 0) != 0 THEN
cap_recovery_factor :=
public.calculate_capital_recovery_factor(discount_rate, equipment_life);

END IF;

-- calculate annual cost

annual_cost := emis_reduction * ref_yr_cost_per_ton;

-- calculate capital cost

capital_cost := annual_cost * capital_annualized_ratio;

-- calculate annualized capital cost

annualized_capital_cost := capital_cost * cap_recovery_factor;

-- calculate operation maintenance cost

operation_maintenance_cost := annual_cost - coalesce(annualized_capital_cost, 0);
-- calculate computed cost per ton
computed_cost_per_ton :=
case

when coalesce(emis_reduction, 0) <> 0 then annual_cost / emis_reduction
else null
end;

END;

$$ LANGUAGE plpgsql IMMUTABLE;

A-36


-------
Control Strategy Tool (CoST) Cost Equations

Appendix B. CoST Equation Control Parameters

Table B-l. ptipm Sector NOx Control Technology Parameters (Equation Type 1)

cost cm
Abbreviation



Source Group

Control Technology

CE

NLNBOUBCW

Util

ty Boiler-Coal/Wall

LNBO

55.9

NLNBOUBCW2

Util

ty Boiler - Coal/Wall2

LNBO

55.3

NLNBUUBCW

Util

ty Boiler-Coal/Wall

LNB

41

NLNBUUBCW2

Util

ty Boiler - Coal/Wall2

LNB

40.3

NLNC1UBCT

Util

ty Boiler - Coal/Tangential

LNC1

33.1

NLNC1UBCT2

Util

ty Boiler - Coal/Tangential1

LNC1

43.3

NLNC2UBCT

Util

ty Boiler - Coal/Tangential

LNC2

12.71

NLNC2UBCT2

Util

ty Boiler - Coal/Tangential2

LNC2

48.3

NLNC3UBCT

Util

ty Boiler - Coal/Tangential

LNC3

53.1

NLNC3UBCT2

Util

ty Boiler - Coal/Tangential3

LNC3

58.3

NNGR UBCT

Util

ty Boiler - Coal/Tangential

NGR

50

NNGR UBCW

Util

ty Boiler-Coal/Wall

NGR

50

NNGR UBCY

Util

ty Boiler - Cyclone

NGR

50

NNGR UBOT

Util

ty Boiler - Oil-Gas/Tangential

NGR

50

NNGR UBOW

Util

ty Boiler - Oil-Gas/Wall

NGR

50

NSCR UBCT*

Util

ty Boiler - Coal/Tangential

SCR

90

NSCR UBCW*

Util

ty Boiler-Coal/Wall

SCR

90

NSCR UBCY

Util

ty Boiler - Cyclone

SCR

90

NSCR UBOT

Util

ty Boiler - Oil-Gas/Tangential

SCR

80

NSCR UBOW

Util

ty Boiler - Oil-Gas/Wall

SCR

80

NSNCRUBCT

Util

ty Boiler - Coal/Tangential

SNCR

35

NSNCRUBCW

Util

ty Boiler-Coal/Wall

SNCR

35

NSNCRUBCY

Util

ty Boiler - Cyclone

SNCR

35

NSNCRUBOT

Util

ty Boiler - Oil-Gas/Tangential

SNCR

50

NSNCRUBOW

Util

ty Boiler - Oil-Gas/Wall

SNCR

50

* Represents measures that use a scaling factor for units < 600 MW. All other measures use a scaling factor for units <500 MW.

B-l


-------
Control Strategy Tool (CoST) Cost Equations

Table B-2. ptipm Sector NOx Control Cost Equation Parameters (Equation Type 1)

Control Cost Equation Variables

cost cm

Capital

O&M Cost Multiplier

Scaling Factor



Interest
Rate

Equipment
Life

Cost Year ($
Year)

Abbreviation

Cost
Multiplier

Fixed

Variable

Model Size
(MW)

Exponent

vapaClly

Factor

NLNBOUBCW

23.4

0.36

0.07

300

0.36

0.85

7

15

1999

NLNBOUBCW2

23.4

0.36

0.07

300

0.36

0.85

7

15

1999

NLNBUUBCW

17.3

0.26

0.05

300

0.36

0.85

7

15

1999

NLNBUUBCW2

17.3

0.26

0.05

300

0.36

0.85

7

15

1999

NLNC1UBCT

9.1

0.14

0

300

0.36

0.85

7

15

1999

NLNC1UBCT2

9.1

0.14

0

300

0.36

0.85

7

15

1999

NLNC2UBCT

12.7

0.19

0.02

300

0.36

0.85

7

15

1999

NLNC2UBCT2

12.7

0.19

0.02

300

0.36

0.85

7

15

1999

NLNC3UBCT

14.5

0.22

0.02

300

0.36

0.85

7

15

1999

NLNC3UBCT2

14.5

0.22

0.02

300

0.36

0.85

7

15

1999

NNGR UBCT

26.9

0.41

0

200

0.35

0.65

7

20

1990

NNGR UBCW

26.9

0.41

0

200

0.35

0.65

7

20

1990

NNGR UBCY

26.9

0.41

0

200

0.35

0.65

7

20

1990

NNGR UBOT

16.4

0.25

0.02

200

0.35

0.65

7

20

1990

NNGR UBOW

16.4

0.25

0.02

200

0.35

0.65

7

20

1990

NSCR UBCT*

100

0.66

0.6

243

0.27

0.65

7

20

1999

NSCR UBCW*

100

0.66

0.6

243

0.27

0.65

7

20

1999

NSCR UBCY

90

0.53

0.37

200

0.35

0.65

7

20

1999

NSCR UBOT

23.3

0.72

0.08

200

0.35

0.65

7

20

1990

NSCR UBOW

23.3

0.72

0.08

200

0.35

0.65

7

20

1990

NSNCRUBCT

15.8

0.24

0.73

100

0.68

0.65

7

20

1990

NSNCRUBCW

15.8

0.24

0.73

100

0.68

0.65

7

20

1990

NSNCRUBCY

8

0.12

1.05

100

0.58

0.65

7

20

1990

NSNCRUBOT

7.8

0.12

0.37

200

0.58

0.65

7

20

1990

NSNCRUBOW

7.8

0.12

0.37

200

0.58

0.65

7

20

1990

B-2


-------
Control Strategy Tool (CoST) Cost Equations

Table B-3. ptipm Sector SO2 Control Technology Parameters (Equation Type 1)

CoST CM Abbreviation



Source Group

Control Technology

CE (%)

SFGDWUBMS

Ut

lity Boilers - Medium Sulfur Content

FGD Wet Scrubber

90

SFGDWUBHS

Ut

lity Boilers - High Sulfur Content

FGD Wet Scrubber

90

SFGDWUBVHS

Ut

lity Boilers - Very High Sulfur Conte

FGD Wet Scrubber

90

SLSDUBC1

Ut

lity Boilers - Bituminous/Subbituminous Coal (100 to 299 MW)*

Lime Spray Dryer

95

SLSDUBC2

Ut

lity Boilers - Bituminous/Subbituminous Coal (300 to 499 MW)

Lime Spray Dryer

95

SLSDUBC3

Ut

lity Boilers - Bituminous/Subbituminous Coal (500 to 699 MW)

Lime Spray Dryer

95

SLSDUBC4

Ut

lity Boilers - Bituminous/Subbituminous Coal (700 to 999 MW)

Lime Spray Dryer

95

SLSDUBC5

Ut

lity Boilers - Bituminous/Subbituminous Coal (Over 1000 MW)

Lime Spray Dryer

95

SLSFOUBC1

Ut

lity Boilers - Bituminous/Subbituminous Coal (100 to 299 MW)

Limestone Forced Oxidation

90

SLSFOUBC2

Ut

lity Boilers - Bituminous/Subbituminous Coal (300 to 499 MW)

Limestone Forced Oxidation

90

SLSFOUBC3

Ut

lity Boilers - Bituminous/Subbituminous Coal (500 to 699 MW)

Limestone Forced Oxidation

90

SLSFOUBC4

Ut

lity Boilers - Bituminous/Subbituminous Coal (700 to 999 MW)

Limestone Forced Oxidation

90

SLSFOUBC5

Ut

lity Boilers - Bituminous/Subbituminous Coal (Over 1000 MW)

Limestone Forced Oxidation

90

* MW = Boiler Capacity in MW

Table B-4. ptipm Sector SO2 Control Cost Equation Parameters (Equation Type 1)

Control Cost Equation Variables

cost cm

Capital Cost
Multiplier

O&M Cost Multiplier



Scaling Factor



Capacity
Factor

Interest
Rate

Equipment
Life

Cost

Abbreviation

Fixed

Variable

Model Size
(MW)

Exponent

Restriction*

Year
($ Year)

SFGDWUBMS

149

5.4

0.83

500



0.6

%S <=2*

0.65

7

15

1990

SFGDWUBHS

166

6

6.3

500



0.6

2< %S <=3

0.65

7

15

1990

SFGDWUBVHS

174

6.3

1.8

500



0.6

3< %S

0.65

7

15

1990

SLSDUBC1

286

13

2.4

0



0

100
-------
Control Strategy Tool (CoST) Cost Equations

Table B-5. ptipm Sector SO2 Control Cost Parameter for Low Sulfur Coal Fuel Switching Options

cost cm
Abbreviation

Source Group

Control Technology

CE (%)

Applicable Sulfur
Content Level

Cost per Ton
Reduced ($/ton)

Cost
Year
($ Year)

SCWSHUBCF

Utility Boilers - Coal Fired

Coal Washing

35

All

320

1997

SFWHLUBHS

Utility Boilers - High Sulfur
Content

Fuel Switch - High to
Low S Content

60

2< %S

140

1995

Table B-6. ptnonipm Sector NOx Control Technology Parameters (Equation Type 2)

cost cm
Abbreviation

Source Group

Control Technology

CE

CRF

NLNBUGTNG

Gas Turbines - Natural Gas

LNB

68

0.1098

NLNBUGTNG

Gas Turbines - Natural Gas

LNB

843

0.1098

NLNBUIBCW

ICI Boilers - Coal/Wall

LNB

50

0.1424

NSCRIBCW

ICI Boilers - Coal/Wall

SCR

90

0.0944

NSCRIBDO

ICI Boilers - Distillate Oil

SCR

80

0.0944

NSCRIBDO

ICI Boilers - Distillate Oil

SCR

902

0.0944

NSCRIBNG

ICI Boilers - Natural Gas

SCR

90

0.0944

NSCRLGTNG

Gas Turbines - Natural Gas

SCR + LNB

94

0.1098

NSCRSGTNG

Gas Turbines - Natural Gas

SCR + Steam Injection

95

0.1098

NSCRWGTNG

Gas Turbines - Natural Gas

SCR + Water Injection

95

0.1098

NSCRWGTOL

Gas Turbines - Oil

SCR + Water Injection

90

0.1098

NSNCRIBCF

ICI Boilers - Coal/FBC

SNCR - Urea

75

0.0944

NSNCRIBCS

ICI Boilers - Coal/Stoker

SNCR

40

0.0944

NSNCRIBCW

ICI Boilers - Coal/Wall

SNCR

40

0.0944

NSNCRIBDO

ICI Boilers - Distillate Oil

SNCR

50

0.0944

NSNCRIBNG

ICI Boilers - Natural Gas

SNCR

50

0.0944

NSNCRIBRO

ICI Boilers - Residual Oil

SNCR

50

0.0944

NSNCRIBWF

ICI Boilers - Wood/Bark/FBC

SNCR - Ammonia

55

0.0944

NSNCRIBWS

ICI Boilers - Wood/Bark/Stoker

SNCR - Urea

55

0.0944

NSTINGTNG

Gas Turbines - Natural Gas

Steam Injection

80

0.1098

NWTINGTNG

Gas Turbines - Natural Gas

Water Injection

76

0.1098

NWTINGTOL

Gas Turbines - Oil

Water Injection

68

0.1098

2 Emissions cutoff < 365 tons/yr

B-4


-------
Control Strategy Tool (CoST) Cost Equations

Table B-7. ptnonipm Sector NOx Control Cost Equation Parameters (Equation Type 2)

Control Cost Equation Application Parameters

cost cm
Abbreviation



Default Application





Incremental Application





Emissions

Cutoff
(Tons/yr)

Capital Cost
Variables

Annual Cost Variables

Capital Cost
Variables

Annual Cost
Variables

Cost Year
($ Year)



Mult*

Exp*

Mult

Exp

Mult

Exp

Mult

Exp



NLNBUGTNG

71281.1

0.51

7826.3

0.51

71281.1

0.51

7826.3

0.51

1990

< 365

NLNBUGTNG

71281.1

0.51

7826.3

0.51

71281.1

0.51

7826.3

0.51

1990

> 365

NLNBUIBCW

53868.7

0.6

11861.1

0.6

53868.7

0.6

11861.1

0.6

1990

> 365

NLNBUIBCW

53868.7

0.6

11861.1

0.6

53868.7

0.6

11861.1

0.6

1990

< 365

NSCRIBCW

82400.9

0.65

5555.6

0.79

79002.2

0.65

8701.5

0.65

1990

> 365

NSCRIBCW

82400.9

0.65

5555.6

0.79

79002.2

0.65

8701.5

0.65

1990

< 365

NSCRIBDO

33206.3

0.65

2498.1

0.73

40891.3

0.65

4481.5

0.65

1999

> 365

NSCRIBDO

33206.3

0.65

2498.1

0.73

40891.3

0.65

4481.5

0.65

1999

< 365

NSCRIBNG

33206.3

0.65

2498.1

0.73

40891.3

0.65

4481.5

0.65

1999

< 365

NSCRIBNG

33206.3

0.65

2498.1

0.73

40891.3

0.65

4481.5

0.65

1999

> 365

NSCRLGTNG

86461.8

0.64

19916.7

0.66

33203.7

0.73

13920

0.69

1990

> 365

NSCRLGTNG

86461.8

0.64

19916.7

0.66

33203.7

0.73

13920

0.69

1990

< 365

NSCRSGTNG

90606.2

0.67

25936.7

0.69

15278.8

0.85

5477.9

0.84

1990

< 365

NSCRSGTNG

90606.2

0.67

25936.7

0.69

15278.8

0.85

5477.9

0.84

1990

> 365

NSCRWGTNG

121119

0.59

36298.9

0.63

18026.5

0.82

7607

0.78

1990

< 365

NSCRWGTNG

121119

0.59

36298.9

0.63

18026.5

0.82

7607

0.78

1990

> 365

NSCRWGTOL

123980.2

0.59

36100.2

0.66

70538.9

0.61

28972.5

0.58

1990

> 365

NSCRWGTOL

123980.2

0.59

36100.2

0.66

70538.9

0.61

28972.5

0.58

1990

< 365

NSNCRIBCF

15972.8

0.6

4970.5

0.6

15972.8

0.6

3059.2

0.6

1990

> 365

NSNCRIBCF

15972.8

0.6

4970.5

0.6

15972.8

0.6

3059.2

0.6

1990

< 365

NSNCRIBCS

110487.6

0.42

3440.9

0.73

67093.8

0.42

7514.2

0.42

1990

> 365

NSNCRIBCS

110487.6

0.42

3440.9

0.73

67093.8

0.42

7514.2

0.42

1990

< 365

NSNCRIBCW

110487.6

0.42

3440.9

0.73

67093.8

0.42

7514.2

0.42

1990

> 365

NSNCRIBCW

110487.6

0.42

3440.9

0.73

67093.8

0.42

7514.2

0.42

1990

< 365

NSNCRIBDO

62148.8

0.42

2012.4

0.72

48002.6

0.42

5244.4

0.42

1990

< 365

NSNCRIBDO

62148.8

0.42

2012.4

0.72

48002.6

0.42

5244.4

0.42

1990

> 365

NSNCRIBNG

62148.8

0.42

2012.4

0.72

48002.6

0.42

5244.4

0.42

1990

< 365

NSNCRIBNG

62148.8

0.42

2012.4

0.72

48002.6

0.42

5244.4

0.42

1990

> 365

NSNCRIBRO

62148.8

0.42

2012.4

0.72

48002.6

0.42

5244.4

0.42

1990

> 365

NSNCRIBRO

62148.8

0.42

2012.4

0.72

48002.6

0.42

5244.4

0.42

1990

< 365

NSNCRIBWF

9855.6

0.6

4185.4

0.6

9855.6

0.6

4185.4

0.6

1990

> 365

NSNCRIBWF

9855.6

0.6

4185.4

0.6

9855.6

0.6

4185.4

0.6

1990

< 365

NSNCRIBWS

65820.1

0.36

17777.1

0.35

65820.1

0.36

17777.1

0.35

1990

> 365

NSNCRIBWS

65820.1

0.36

17777.1

0.35

65820.1

0.36

17777.1

0.35

1990

< 365

NSTINGTNG

9693.1

0.92

764.3

1.15

9693.1

0.92

764.3

1.15

1990

< 365

B-5


-------
Control Strategy Tool (CoST) Cost Equations



Control Cost Equation Application Parameters







cost cm
Abbreviation

Default Application Incremental Application



Emissions
Cutoff

Capital Cost . ... . Capital Cost Annual Cost
¦ ... Annual Cost Variables ... ... . .
Variables Variables Variables

Cost Year
($ Year)



Mult* Exp* Mult Exp Mult

Exp Mult Exp







NSTINGTNG

9693.1 0.92 764.3 1.15 9693.1

0.92 764.3 1.15

1990

> 365



NWTINGTNG

4284.2 1.01 145.7 1.47 4284.2

1.01 145.7 1.47

1990

> 365



NWTINGTNG

4284.2 1.01 145.7 1.47 4284.2

1.01 145.7 1.47

1990

< 365



NWTINGTOL

54453.5 0.57 9687.9 0.76 54453.5

0.57 9687.9 0.76

1990

< 365



NWTINGTOL

54453.5 0.57 9687.9 0.76 54453.5

0.57 9687.9 0.76

1990

> 365



*Mult = multiplier, Exp = exponent











Table B-8. ptnonipm Sector SO2 Control Measure Cost Assignments (Equation Types 3-6)





Cost cm
Abbreviation

Source Group

Control Technology

CE

Cost
Equation
Type #

Cost
Year
($Year)

SNS99SACA

Sulfuric Acid Plants - Contact Absorber (99% Conversion)

Increase % Conversion to Meet
NSPS (99.7)

75

4

1990

SNS98SACA

Sulfuric Acid Plants - Contact Absorber (98% Conversion)

Increase % Conversion to Meet
NSPS (99.7)

85

4

1990

SNS97SACA

Sulfuric Acid Plants - Contact Absorber (97% Conversion)

Increase % Conversion to Meet
NSPS (99.7)

90

4

1990

SNS93SACA

Sulfuric Acid Plants - Contact Absorber (93% Conversion)

Increase % Conversion to Meet
NSPS (99.7)

95

4

1990

SAMSCSRP95

Sulfur Recovery Plants - Elemental Sulfur (Claus: 2 Stage w/o
control (92-95% removal))

Amine Scrubbing

98.4

5

1990

SAMSCSRP96

Sulfur Recovery Plants - Elemental Sulfur (Claus: 3 Stage w/o
control (95-96% removal))

Amine Scrubbing

97.8

5

1990

SAMSCSRP97

Sulfur Recovery Plants - Elemental Sulfur (Claus: 3 Stage w/o
control (96-97% removal))

Amine Scrubbing

97.1

5

1990

SFGDSCMOP

By-Product Coke Manufacturing (Other Processes)

FGD

90

3

1995

SFGDSPHOG

Process Heaters (Oil and Gas Production Industry)

FGD

90

3

1995

SSADPPRMTL

Primary Metals Industry

Sulfuric Acid Plant

70

3

1995

SFGDSMIPR

Mineral Products Industry

FGD

50

3

1995

SFGDSPPSP

Pulp and Paper Industry (Sulfate Pulping)

FGD

90

3

1995

SFGDSPETR

Petroleum Industry

FGD

90

3

1995

SFGDSIBBC

Bituminous/Subbituminous Coal (Industrial Boilers)

FGD

90

3

1995

SFGDSIBRO

Residual Oil (Industrial Boilers)

FGD

90

3

1995

B-6


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation

Source Group

Control Technology

CE

Cost
Equation
Type #

Cost
Year
($Year)

SFGDSCBBCL

Bituminous/Subbituminous Coal (Commercial/Institutional
Boilers)

FGD

90

3

1995

SFGDSIPFBC

In-process Fuel Use - Bituminous/Subbituminous Coal

FGD

90

3

1995

SFGDSIBLG

Lignite (Industrial Boilers)

FGD

90

3

1995

SFGDSCBRO

Residual Oil (Commercial/Institutional Boilers)

FGD

90

3

1995

SFGDSSGCO

Steam Generating Unit-Coal/Oil

FGD

90

3

1995

SDLABPLSS

Primary Lead Smelters - Sintering

Dual absorption

99

4

1990

SDLABPZSS

Primary Zinc Smelters - Sintering

Dual absorption

99

4

1990

SCOGDCOP

By-Product Coke Manufacturing (Coke Oven Plants)

Coke Oven Gas Desulfurization

90

6

1990

Table B-9. ptipm Sector PM Control Cost Equation Parameters (Equation Type 8)

cost cm
Abbreviation

Source Group

Control Technology

Control
Efficiency (%)

Typical Control

Cost
Equation-Based
Factors*

Typical Default Cost
per Ton Factors

Cost
Year









PM-10

PM-2.5

Capital

O&M

Capital

O&M

Annualized



PFFMSUBC

Utility Boilers ¦

- Coal

Fabric Filter (Mech. Shaker
Type)

99

99

29

11

412

62

126

1998

PFFPJUBC

Utility Boilers ¦

- Coal

Fabric Filter (Pulse Jet
Type)

99

99

13

11

380

28

117

1998

PFFRAUBC

Utility Boilers ¦

- Coal

Fabric Filter (Reverse-Air
Cleaned Type)

99

99

34

13

0

0

148

1998

PDESPWPUBC

Utility Boilers ¦

- Coal

Dry ESP-Wire Plate Type

98

95

27

16

710

41

110

1995

PDESPWPUBO

Utility Boilers ¦

-Oil

Dry ESP-Wire Plate Type

98

95

27

16

710

41

110

1995

* $/acfm

Table B-10. ptnonipm Sector PM Control Cost Equation Parameters (Equation Type 8)

cost cm
Abbreviation

Source Group

Control Technology

Control Efficiency (%)

Equipment
Life

Typical Control
Cost Equation-
Based Factors

Cost
Year







PM-10

PM-2.5



Capital O&M

l«p Tcai]

P CAT F WAT

Beef Cattle Feedlots

Watering

50

25

10



1990

PCHIPHB

Household burning

Substitute chipping for
burning



50

0



1999

PCHIPOB

Open burning

Substitute chipping for
burning



100

0



1999

B-7


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation

Source Group

Control Technology

Control Efficiency (%)

Equipment
Life

Typical Control
Cost Equation-
Based Factors

Cost
Year







PM-10

PM-2.5



Capital

O&M

l«p Tcai]

PCHRBCAOX

Conveyorized
Charbroilers

Catalytic Oxidizer

83

83

10





1990

PCHRBCAOX1

Conveyorized
Charbroilers

Catalytic Oxidizer

8.3

8.3

10





1990

PCHRBESP

Conveyorized
Charbroilers

ESP for Commercial
Cooking

99

99

10





1990

PCHRBESPSM

Commercial Cooking —
large underfired grilling
operations

ESP

99

99

10





1990

PCONWATCHM

Construction Activities

Dust Control Plan

62.5

37.5

0





1990

PDESPCIBCL

Commercial Institutional
Boilers - Coal

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995

PDESPCIBOL

Commercial Institutional
Boilers - Oil

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995

PDESPCIBWD

Commercial Institutional
Boilers - Wood

Dry ESP-Wire Plate
Type

90

90

20

27

16

1995

PDESPIBCL

Industrial Boilers - Coal

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995

PDESPIBLW

Industrial Boilers - Liquid
Waste

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995

PDESPIBOL

Industrial Boilers - Oil

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995

PDESPIBWD

Industrial Boilers - Wood

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995

PDESPMICM

Mineral Products -
Cement Manufacture

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995

PDESPMIOR

Mineral Products - Other

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995

PDESPMISQ

Mineral Products - Stone
Quarrying & Processing

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995

PDESPMPAM

Non-Ferrous Metals
Processing - Aluminum

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995

PDESPMPCR

Non-Ferrous Metals
Processing - Copper

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995

PDESPMPFP

Ferrous Metals
Processing - Ferroalloy
Production

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995

B-8


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation

Source Group

Control Technology

Control Efficiency (%)

Equipment
Life

Typical Control
Cost Equation-
Based Factors

Cost
Year







PM-10

PM-2.5



Capital

O&M

l«p Tcai]

PDESPMPIS

Ferrous Metals
Processing - Iron & Steel

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995



Production













PDESPMPLD

Non-Ferrous Metals
Processing - Lead

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995

PDESPMPOR

Non-Ferrous Metals
Processing - Other

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995

PDESPMPZC

Non-Ferrous Metals
Processing - Zinc

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995

PDESPMUWI

Municipal Waste
Incineration

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995

PDESPWDPP

Wood Pulp & Paper

Dry ESP-Wire Plate
Type

98

95

20

27

16

1995

PDIEOXCAT

IC Diesel Engine

Diesel Oxidation
Catalyst (DPF infeasible)

20



0





2003

PDIEPRTFIL

IC Diesel Engine

Diesel Particulate Filter

85



0





2003

PDPFICE

Internal Combustion
Engines

Diesel Particulate Filter



90

0





1999

PESPOFBOIL

Oil fired boiler

ESP



75

0





1999

PESPPETCRK

Petroleum Refinery
Catalytic and Thermal
Cracking Units

ESP

95



0





1999

PFFMSASMN

Asphalt Manufacture

Fabric Filter (Mech.
Shaker Type)

99

99

20

29

11

1998

PFFMSMICC

Mineral Products - Coal
Cleaning

Fabric Filter (Mech.
Shaker Type)

99

99

20

29

11

1998

PFFMSMICM

Mineral Products -
Cement Manufacture

Fabric Filter (Mech.
Shaker Type)

99

99

20

29

11

1998

PFFMSMIOR

Mineral Products - Other

Fabric Filter (Mech.
Shaker Type)

99

99

20

29

11

1998

PFFMSMISQ

Mineral Products - Stone
Quarrying & Processing

Fabric Filter (Mech.
Shaker Type)

99

99

20

29

11

1998

PFFMSMPAM

Non-Ferrous Metals
Processing - Aluminum

Fabric Filter (Mech.
Shaker Type)

99

99

20

29

11

1998

PFFMSMPCE

Ferrous Metals
Processing - Coke

Fabric Filter (Mech.
Shaker Type)

99

99

20

29

11

1998

PFFMSMPCR

Non-Ferrous Metals
Processing - Copper

Fabric Filter (Mech.
Shaker Type)

99

99

20

29

11

1998

B-9


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation

Source Group

Control Technology

Control Efficiency (%)

Equipment
Life

Typical Control
Cost Equation-
Based Factors

Cost
Year







PM-10

PM-2.5



Capital O&M

l«p Tcai]

PFFMSMPFP

Ferrous Metals
Processing - Ferroalloy
Production

Fabric Filter (Mech.
Shaker Type)

99

99

20

29 11

1998

PFFMSMPGI

Ferrous Metals
Processing - Gray Iron
Foundries

Fabric Filter (Mech.
Shaker Type)

99

99

20

29 11

1998

PFFMSMPIS

Ferrous Metals
Processing - Iron & Steel
Production

Fabric Filter (Mech.
Shaker Type)

99

99

20

29 11

1998

PFFMSMPLD

Non-Ferrous Metals
Processing - Lead

Fabric Filter (Mech.
Shaker Type)

99

99

20

29 11

1998

PFFMSMPOR

Non-Ferrous Metals
Processing - Other

Fabric Filter (Mech.
Shaker Type)

99

99

20

29 11

1998

PFFMSMPSF

Ferrous Metals
Processing - Steel
Foundries

Fabric Filter (Mech.
Shaker Type)

99

99

20

29 11

1998

PFFMSMPZC

Non-Ferrous Metals
Processing - Zinc

Fabric Filter (Mech.
Shaker Type)

99

99

20

29 11

1998

PFFPJASMN

Asphalt Manufacture

Fabric Filter (Pulse Jet
Type)

99

99

20

13 11

1998

PFFPJCIBCL

Commercial Institutional
Boilers - Coal

Fabric Filter (Pulse Jet
Type)

99

99

20

13 11

1998

PFFPJCIBWD

Commercial Institutional
Boilers - Wood

Fabric Filter (Pulse Jet
Type)

80

80

20

13 11

1998

PFFPJGRMG

Grain Milling

Fabric Filter (Pulse Jet
Type)

99

99

20

13 11

1998

PFFPJIBCL

Industrial Boilers - Coal

Fabric Filter (Pulse Jet
Type)

99

99

20

13 11

1998

PFFPJIBWD

Industrial Boilers - Wood

Fabric Filter (Pulse Jet
Type)

99

99

20

13 11

1998

PFFPJMICC

Mineral Products - Coal
Cleaning

Fabric Filter (Pulse Jet
Type)

99

99

20

13 11

1998

PFFPJMICM

Mineral Products -
Cement Manufacture

Fabric Filter (Pulse Jet
Type)

99

99

20

13 11

1998

PFFPJMIOR

Mineral Products - Other

Fabric Filter (Pulse Jet
Type)

99

99

20

13 11

1998

PFFPJMISQ

Mineral Products - Stone

Fabric Filter (Pulse Jet

99

99

20

13 11

1998

Quarrying & Processing

Type)

B-10


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation

Source Group

Control Technology

Control Efficiency (%)

Equipment
Life

Typical Control
Cost Equation-
Based Factors

Cost
Year







PM-10

PM-2.5



Capital

O&M

l«p Tcai]

PFFPJMPIS

Ferrous Metals
Processing - Iron & Steel
Production

Fabric Filter (Pulse Jet
Type)

99

99

20

13

11

1998

PFFPJMPSF

Ferrous Metals
Processing - Steel
Foundries

Fabric Filter (Pulse Jet
Type)

99

99

20

13

11

1998

PFFRAASMN

Asphalt Manufacture

Fabric Filter - Reverse-
Air Cleaned Type

99

99

20

34

13

1998

PFFRACIBCL

Commercial Institutional

Fabric Filter - Reverse-

99

99

20

34

13

1998

Boilers - Coal

Air Cleaned Type

PFFRACIBWD

Commercial Institutional
Boilers - Wood

Fabric Filter - Reverse-
Air Cleaned Type

80

80

20

34

13

1998

PFFRAGRMG

Grain Milling

Fabric Filter - Reverse-
Air Cleaned Type

99

99

20

34

13

1998

PFFRAIBCL

Industrial Boilers - Coal

Fabric Filter - Reverse-
Air Cleaned Type

99

99

20

34

13

1998

PFFRAIBWD

Industrial Boilers - Wood

Fabric Filter - Reverse-
Air Cleaned Type

99

99

20

34

13

1998

PFFRAMICC

Mineral Products - Coal

Fabric Filter - Reverse-

99

99

20

34

13

1998

Cleaning

Air Cleaned Type

PFFRAMICM

Mineral Products -
Cement Manufacture

Fabric Filter - Reverse-
Air Cleaned Type

99

99

20

34

13

1998

PFFRAMIOR

Mineral Products - Other

Fabric Filter - Reverse-
Air Cleaned Type

99

99

20

34

13

1998

PFFRAMISQ

Mineral Products - Stone

Fabric Filter - Reverse-

99

99

20

34

13

1998

Quarrying & Processing

Air Cleaned Type

PFFRAMPAM

Non-Ferrous Metals
Processing - Aluminum

Fabric Filter - Reverse-
Air Cleaned Type

99

99

20

34

13

1998

PFFRAMPCE

Ferrous Metals
Processing - Coke

Fabric Filter - Reverse-
Air Cleaned Type

99

99

20

34

13

1998

PFFRAMPCR

Non-Ferrous Metals
Processing - Copper

Fabric Filter - Reverse-
Air Cleaned Type

99

99

20

34

13

1998

PFFRAMPFP

Ferrous Metals
Processing - Ferroalloy
Production

Fabric Filter - Reverse-
Air Cleaned Type

99

99

20

34

13

1998

PFFRAMPGI

Ferrous Metals
Processing - Gray Iron
Foundries

Fabric Filter - Reverse-
Air Cleaned Type

99

99

20

34

13

1998

B-ll


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation

Source Group

Control Technology

Control Efficiency (%)

Equipment
Life

Typical Control
Cost Equation-
Based Factors

Cost
Year







PM-10

PM-2.5



Capital

O&M

l«p Tcai]

PFFRAMPIS

Ferrous Metals
Processing - Iron & Steel
Production

Fabric Filter - Reverse-
Air Cleaned Type

99

99

20

34

13

1998

PFFRAMPLD

Non-Ferrous Metals
Processing - Lead

Fabric Filter - Reverse-
Air Cleaned Type

99

99

20

34

13

1998

PFFRAMPOR

Non-Ferrous Metals
Processing - Other

Fabric Filter - Reverse-
Air Cleaned Type

99

99

20

34

13

1998

PFFRAMPSF

Ferrous Metals
Processing - Steel
Foundries

Fabric Filter - Reverse-
Air Cleaned Type

99

99

20

34

13

1998

PFFRAMPZC

Non-Ferrous Metals
Processing - Zinc

Fabric Filter - Reverse-
Air Cleaned Type

99

99

20

34

13

1998

PFIRINSHH

Home Heating

Fireplace Inserts



98

0





1999

PISCRMPGI

Ferrous Metals
Processing - Gray Iron
Foundries

Impingement-plate
scrubber

64

64

10

7

25

1995

PLNDFILBRN

Open Burning

Substitution of land filling
for open burning

75



0





1999

PPFCCASMN

Asphalt Manufacture

Paper/Nonwoven Filters
- Cartridge Collector
Type

99

99

20

9

14

1998

PPFCCFMAB

Fabricated Metal Products
- Abrasive Blasting

Paper/Nonwoven Filters
- Cartridge Collector
Type

99

99

20

9

14

1998

PPFCCFMMG

Fabricated Metal Products
- Machining

Paper/Nonwoven Filters
- Cartridge Collector
Type

99

99

20

9

14

1998

PPFCCFMWG

Fabricated Metal Products
-Welding

Paper/Nonwoven Filters
- Cartridge Collector
Type

99

99

20

9

14

1998

PPFCCGRMG

Grain Milling

Paper/Nonwoven Filters
- Cartridge Collector
Type

99

99

20

9

14

1998

PPFCCMICC

Mineral Products - Coal
Cleaning

Paper/Nonwoven Filters
- Cartridge Collector
Type

99

99

20

9

14

1998

PPFCCMICM

Mineral Products -
Cement Manufacture

Paper/Nonwoven Filters
- Cartridge Collector
Type

99

99

20

9

14

1998

B-12


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation

Source Group

Control Technology

Control Efficiency (%)

Equipment
Life

Typical Control
Cost Equation-
Based Factors

Cost
Year







PM-10

PM-2.5



Capital

O&M

l«p Tcai]

PPFCCMIOR

Mineral Products - Other

Paper/Nonwoven Filters
- Cartridge Collector
Type

99

99

20

9

14

1998

PPFCCMISQ

Mineral Products - Stone
Quarrying & Processing

Paper/Nonwoven Filters
- Cartridge Collector
Type

99

99

20

9

14

1998

PPRBRNFULM

Prescribed Burning

Increase Fuel Moisture

50

50

0





1990

PRESWDEDAD

Residential Wood
Combustion

Education and Advisory
Program

50

50

0





1990

PRESWDEDAP

Residential Wood
Combustion Generic

Education and Advisory
Program

35

35

0





1990

PRESWDSTV1

Residential Wood
Combustion

NSPS Compliant Wood
Stove

8.2

8.2

0





1990

PRESWDSTV2

Residential Wood
Combustion

NSPS Compliant Wood
Stove

9.8

9.8

0





1990

PVENTCCU

Catalytic cracking units

Venturi scrubber



90

0





1999

PVESCIBCL

Industrial Boilers - Coal

Venturi Scrubber

82

50

10

11

42

1995

PVESCIBOL

Industrial Boilers - Oil

Venturi Scrubber

92

89

10

11

42

1995

PVESCIBWD

Industrial Boilers - Wood

Venturi Scrubber

93

92

10

11

42

1995

PVSCRMICC

Mineral Products - Coal
Cleaning

Venturi Scrubber

99

98

10

11

42

1995

PVSCRMISQ

Mineral Products - Stone
Quarrying & Processing

Venturi Scrubber

95

90

10

11

42

1995

PVSCRMPCE

Ferrous Metals
Processing - Coke

Venturi Scrubber

93

89

10

11

42

1995

PVSCRMPGI

Ferrous Metals
Processing - Gray Iron
Foundries

Venturi Scrubber

94

94

10

11

42

1995

PVSCRMPIS

Ferrous Metals
Processing - Iron & Steel
Production

Venturi Scrubber

73

25

10

11

42

1995

PVSCRMPSF

Ferrous Metals
Processing - Steel
Foundries

Venturi Scrubber

73

25

10

11

42

1995

PWESPCHMN

Chemical Manufacture

Wet ESP - Wire Plate
Type

99

95

20

40

19

1995

PWESPMIOR

Mineral Products - Other

Wet ESP - Wire Plate
Type

99

95

20

40

19

1995

B-13


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation

Source Group

Control Technology

Control Efficiency (%)

Typical Control
Equipment Cost Equation-
Life Based Factors

Cost
Year







PM-10

PM-2.5



Capital O&M

l«p Tcai]

PWESPMISQ

Mineral Products - Stone
Quarrying & Processing

Wet ESP - Wire Plate
Type

99



95

20

40

19

1995

PWESPMPAM

Non-Ferrous Metals

Wet ESP - Wire Plate

99



95

20

40

19

1995

Processing - Aluminum

Type



PWESPMPCR

Non-Ferrous Metals
Processing - Copper

Wet ESP - Wire Plate
Type

99



95

20

40

19

1995

PWESPMPIS

Ferrous Metals
Processing - Iron & Steel
Production

Wet ESP - Wire Plate
Type

99



95

20

40

19

1995

PWESPMPLD

Non-Ferrous Metals
Processing - Lead

Wet ESP - Wire Plate
Type

99



95

20

40

19

1995

PWESPMPOR

Non-Ferrous Metals
Processing - Other

Wet ESP - Wire Plate
Type

99



95

20

40

19

1995

PWESPMPZC

Non-Ferrous Metals
Processing - Zinc

Wet ESP - Wire Plate
Type

99



95

20

40

19

1995

PWESPWDPP

Wood Pulp & Paper

Wet ESP - Wire Plate
Type

99



95

20

40

19

1995

Table B-ll. ptnonipm Sector PM Controls Default Cost per Ton Factors (Equation Type 8 or Controls Applied to Nonpoint Sources)

cost cm
Abbreviation

Source Group

Control Technology



Control Efficiency
(%)

Typical Default Cost
per Ton Factors

Cost
Year







PM-10

PM-2.5

Capital

O&M

Annualized

($ Year)

P CAT F WAT

Beef Cattle Feedlots

Watering



50

25





307

1990

PCHIPHB

Household burning

Substitute chipping for
burning





50







1999

PCHIPOB

Open burning

Substitute chipping for
burning





100







1999

PCHRBCAOX

Conveyorized Charbroilers

Catalytic Oxidizer



83

83





2150

1990

PCHRBCAOX1

Conveyorized Charbroilers

Catalytic Oxidizer



8.3

8.3





2150

1990

PCHRBESP

Conveyorized Charbroilers

ESP for Commercial
Cooking



99

99





7000

1990

PCHRBESPSM

Commercial Cooking — large
underfired grilling operations

ESP



99

99





7000

1990

PCONWATCHM

Construction Activities

Dust Control Plan



62.5

37.5





3600

1990

PDESPCIBCL

Commercial Institutional Boilers „ .... _
Coal Dry ESP-Wire Plate Type

98

95

710

41

110

1995

B-14


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation

Source Group

Control Technology

Control Efficiency
(%)

Typical Default Cost
per Ton Factors

Cost
Year





PM-10

PM-2.5

Capital

O&M

Annualized

($ Year)

PDESPCIBOL

Commercial Institutional Boilers
-Oil

Dry ESP-Wire Plate Type

98

95

710

41

110

1995

PDESPCIBWD

Commercial Institutional Boilers
-Wood

Dry ESP-Wire Plate Type

90

90

710

41

110

1995

PDESPIBCL

Industrial Boilers - Coal

Dry ESP-Wire Plate Type

98

95

710

41

110

1995

PDESPIBLW

Industrial Boilers - Liquid Waste

Dry ESP-Wire Plate Type

98

95

710

41

110

1995

PDESPIBOL

Industrial Boilers - Oil

Dry ESP-Wire Plate Type

98

95

710

41

110

1995

PDESPIBWD

Industrial Boilers - Wood

Dry ESP-Wire Plate Type

98

95

710

41

110

1995

PDESPMICM

Mineral Products - Cement
Manufacture

Dry ESP-Wire Plate Type

98

95

710

41

110

1995

PDESPMIOR

Mineral Products - Other

Dry ESP-Wire Plate Type

98

95

710

41

110

1995

PDESPMISQ

Mineral Products - Stone
Quarrying & Processing

Dry ESP-Wire Plate Type

98

95

710

41

110

1995

PDESPMPAM

Non-Ferrous Metals Processing
- Aluminum

Dry ESP-Wire Plate Type

98

95

710

41

110

1995

PDESPMPCR

Non-Ferrous Metals Processing
- Copper

Dry ESP-Wire Plate Type

98

95

710

41

110

1995

PDESPMPFP

Ferrous Metals Processing -
Ferroalloy Production

Dry ESP-Wire Plate Type

98

95

710

41

110

1995

PDESPMPIS

Ferrous Metals Processing -
Iron & Steel Production

Dry ESP-Wire Plate Type

98

95

710

41

110

1995

PDESPMPLD

Non-Ferrous Metals Processing
- Lead

Dry ESP-Wire Plate Type

98

95

710

41

110

1995

PDESPMPOR

Non-Ferrous Metals Processing
- Other

Dry ESP-Wire Plate Type

98

95

710

41

110

1995

PDESPMPZC

Non-Ferrous Metals Processing
- Zinc

Dry ESP-Wire Plate Type

98

95

710

41

110

1995

PDESPMUWI

Municipal Waste Incineration

Dry ESP-Wire Plate Type

98

95

710

41

110

1995

PDESPWDPP

Wood Pulp & Paper

Dry ESP-Wire Plate Type

98

95

710

41

110

1995

PDIEOXCAT

IC Diesel Engine

Diesel Oxidation Catalyst
(DPF infeasible)

20







1500

2003

PDIEPRTFIL

IC Diesel Engine

Diesel Particulate Filter

85







10500

2003

PDPFICE

Internal Combustion Engines

Diesel Particulate Filter



90







1999

PESPOFBOIL

Oil fired boiler

ESP



75







1999

PESPPETCRK

Petroleum Refinery Catalytic
and Thermal Cracking Units

ESP

95







5050

1999

PFFMSASMN

Asphalt Manufacture

Fabric Filter (Mech.
Shaker Type)

99

99

412

62

126

1998

PFFMSMICC

Mineral Products - Coal
Cleaning

Fabric Filter (Mech.
Shaker Type)

99

99

412

62

126

1998

B-15


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation

Source Group

Control Technology

Control Efficiency
(%)

Typical Default Cost
per Ton Factors

Cost
Year





PM-10

PM-2.5

Capital

O&M

Annualized

($ Year)

PFFMSMICM

Mineral Products - Cement
Manufacture

Fabric Filter (Mech.
Shaker Type)

99

99

412

62

126

1998

PFFMSMIOR

Mineral Products - Other

Fabric Filter (Mech.
Shaker Type)

99

99

412

62

126

1998

PFFMSMISQ

Mineral Products - Stone
Quarrying & Processing

Fabric Filter (Mech.
Shaker Type)

99

99

412

62

126

1998

PFFMSMPAM

Non-Ferrous Metals Processing
- Aluminum

Fabric Filter (Mech.
Shaker Type)

99

99

412

62

126

1998

PFFMSMPCE

Ferrous Metals Processing -
Coke

Fabric Filter (Mech.
Shaker Type)

99

99

412

62

126

1998

PFFMSMPCR

Non-Ferrous Metals Processing
- Copper

Fabric Filter (Mech.
Shaker Type)

99

99

412

62

126

1998

PFFMSMPFP

Ferrous Metals Processing -
Ferroalloy Production

Fabric Filter (Mech.
Shaker Type)

99

99

412

62

126

1998

PFFMSMPGI

Ferrous Metals Processing -
Gray Iron Foundries

Fabric Filter (Mech.
Shaker Type)

99

99

412

62

126

1998

PFFMSMPIS

Ferrous Metals Processing -
Iron & Steel Production

Fabric Filter (Mech.
Shaker Type)

99

99

412

62

126

1998

PFFMSMPLD

Non-Ferrous Metals Processing
- Lead

Fabric Filter (Mech.
Shaker Type)

99

99

412

62

126

1998

PFFMSMPOR

Non-Ferrous Metals Processing
- Other

Fabric Filter (Mech.
Shaker Type)

99

99

412

62

126

1998

PFFMSMPSF

Ferrous Metals Processing -
Steel Foundries

Fabric Filter (Mech.
Shaker Type)

99

99

412

62

126

1998

PFFMSMPZC

Non-Ferrous Metals Processing
- Zinc

Fabric Filter (Mech.
Shaker Type)

99

99

412

62

126

1998

PFFPJASMN

Asphalt Manufacture

Fabric Filter (Pulse Jet
Type)

99

99

380

28

117

1998

PFFPJCIBCL

Commercial Institutional Boilers
- Coal

Fabric Filter (Pulse Jet
Type)

99

99

380

28

117

1998

PFFPJCIBWD

Commercial Institutional Boilers
-Wood

Fabric Filter (Pulse Jet
Type)

80

80

380

28

117

1998

PFFPJGRMG

Grain Milling

Fabric Filter (Pulse Jet
Type)

99

99

380

28

117

1998

PFFPJIBCL

Industrial Boilers - Coal

Fabric Filter (Pulse Jet
Type)

99

99

380

28

117

1998

PFFPJIBWD

Industrial Boilers - Wood

Fabric Filter (Pulse Jet
Type)

99

99

380

28

117

1998

PFFPJMICC

Mineral Products - Coal
Cleaning

Fabric Filter (Pulse Jet
Type)

99

99

380

28

117

1998

B-16


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation

Source Group

Control Technology

Control Efficiency
(%)

Typical Default Cost
per Ton Factors

Cost
Year





PM-10

PM-2.5

Capital

O&M

Annualized

($ Year)

PFFPJMICM

Mineral Products - Cement
Manufacture

Fabric Filter (Pulse Jet
Type)

99

99

380

28

117

1998

PFFPJMIOR

Mineral Products - Other

Fabric Filter (Pulse Jet
Type)

99

99

380

28

117

1998

PFFPJMISQ

Mineral Products - Stone
Quarrying & Processing

Fabric Filter (Pulse Jet
Type)

99

99

380

28

117

1998

PFFPJMPIS

Ferrous Metals Processing -
Iron & Steel Production

Fabric Filter (Pulse Jet
Type)

99

99

380

28

117

1998

PFFPJMPSF

Ferrous Metals Processing -
Steel Foundries

Fabric Filter (Pulse Jet
Type)

99

99

380

28

117

1998

PFFRAASMN

Asphalt Manufacture

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFFRACIBCL

Commercial Institutional Boilers
- Coal

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFFRACIBWD

Commercial Institutional Boilers
-Wood

Fabric Filter - Reverse-Air
Cleaned Type

80

80

0

0

148

1998

PFFRAGRMG

Grain Milling

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFFRAIBCL

Industrial Boilers - Coal

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFFRAIBWD

Industrial Boilers - Wood

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFFRAMICC

Mineral Products - Coal
Cleaning

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFFRAMICM

Mineral Products - Cement
Manufacture

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFFRAMIOR

Mineral Products - Other

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFFRAMISQ

Mineral Products - Stone
Quarrying & Processing

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFFRAMPAM

Non-Ferrous Metals Processing
- Aluminum

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFFRAMPCE

Ferrous Metals Processing -
Coke

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFFRAMPCR

Non-Ferrous Metals Processing
- Copper

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFFRAMPFP

Ferrous Metals Processing -
Ferroalloy Production

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFFRAMPGI

Ferrous Metals Processing -
Gray Iron Foundries

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

B-17


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation

Source Group

Control Technology

Control Efficiency
(%)

Typical Default Cost
per Ton Factors

Cost
Year





PM-10

PM-2.5

Capital

O&M

Annualized

($ Year)

PFFRAMPIS

Ferrous Metals Processing -
Iron & Steel Production

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFFRAMPLD

Non-Ferrous Metals Processing
- Lead

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFFRAMPOR

Non-Ferrous Metals Processing
- Other

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFFRAMPSF

Ferrous Metals Processing -
Steel Foundries

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFFRAMPZC

Non-Ferrous Metals Processing
- Zinc

Fabric Filter - Reverse-Air
Cleaned Type

99

99

0

0

148

1998

PFIRINSHH

Home Heating

Fireplace Inserts



98







1999

PISCRMPGI

Ferrous Metals Processing -
Gray Iron Foundries

Impingement-plate
scrubber

64

64

87

417

431

1995

PLNDFILBRN

Open Burning

Substitution of land filling
for open burning

75







3500

1999

PPFCCASMN

Asphalt Manufacture

Paper/Nonwoven Filters -
Cartridge Collector Type

99

99

0

0

142

1998

PPFCCFMAB

Fabricated Metal Products -
Abrasive Blasting

Paper/Nonwoven Filters -
Cartridge Collector Type

99

99

0

0

142

1998

PPFCCFMMG

Fabricated Metal Products -
Machining

Paper/Nonwoven Filters -
Cartridge Collector Type

99

99

0

0

142

1998

PPFCCFMWG

Fabricated Metal Products -
Welding

Paper/Nonwoven Filters -
Cartridge Collector Type

99

99

0

0

142

1998

PPFCCGRMG

Grain Milling

Paper/Nonwoven Filters -
Cartridge Collector Type

99

99

0

0

142

1998

PPFCCMICC

Mineral Products - Coal
Cleaning

Paper/Nonwoven Filters -
Cartridge Collector Type

99

99

0

0

142

1998

PPFCCMICM

Mineral Products - Cement
Manufacture

Paper/Nonwoven Filters -
Cartridge Collector Type

99

99

0

0

142

1998

PPFCCMIOR

Mineral Products - Other

Paper/Nonwoven Filters -
Cartridge Collector Type

99

99

0

0

142

1998

PPFCCMISQ

Mineral Products - Stone
Quarrying & Processing

Paper/Nonwoven Filters -
Cartridge Collector Type

99

99

0

0

142

1998

PPRBRNFULM

Prescribed Burning

Increase Fuel Moisture

50

50





2617

1990

PRESWDEDAD

Residential Wood Combustion

Education and Advisory
Program

50

50





1320

1990

PRESWDEDAP

Residential Wood Combustion
Generic

Education and Advisory
Program

35

35





1320

1990

PRESWDSTV1

Residential Wood Combustion

NSPS Compliant Wood
Stove

8.2

8.2





1454

1990

B-18


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation

Source Group

Control Technology

Control Efficiency
(%)

Typical Default Cost
per Ton Factors

Cost
Year





PM-10

PM-2.5

Capital

O&M

Annualized

($ Year)

PRESWDSTV2

Residential Wood Combustion

NSPS Compliant Wood
Stove

9.8

9.8





1454

1990

PVENTCCU

Catalytic cracking units

Venturi scrubber



90







1999

PVESCIBCL

Industrial Boilers - Coal

Venturi Scrubber

82

50

189

713

751

1995

PVESCIBOL

Industrial Boilers - Oil

Venturi Scrubber

92

89

189

713

751

1995

PVESCIBWD

Industrial Boilers - Wood

Venturi Scrubber

93

92

189

713

751

1995

PVSCRMICC

Mineral Products - Coal
Cleaning

Venturi Scrubber

99

98

189

713

751

1995

PVSCRMISQ

Mineral Products - Stone
Quarrying & Processing

Venturi Scrubber

95

90

189

713

751

1995

PVSCRMPCE

Ferrous Metals Processing -
Coke

Venturi Scrubber

93

89

189

713

751

1995

PVSCRMPGI

Ferrous Metals Processing -
Gray Iron Foundries

Venturi Scrubber

94

94

189

713

751

1995

PVSCRMPIS

Ferrous Metals Processing -
Iron & Steel Production

Venturi Scrubber

73

25

189

713

751

1995

PVSCRMPSF

Ferrous Metals Processing -
Steel Foundries

Venturi Scrubber

73

25

189

713

751

1995

PWESPCHMN

Chemical Manufacture

Wet ESP - Wire Plate
Type

99

95

923

135

220

1995

PWESPMIOR

Mineral Products - Other

Wet ESP - Wire Plate
Type

99

95

923

135

220

1995

PWESPMISQ

Mineral Products - Stone
Quarrying & Processing

Wet ESP - Wire Plate
Type

99

95

923

135

220

1995

PWESPMPAM

Non-Ferrous Metals Processing
- Aluminum

Wet ESP - Wire Plate
Type

99

95

923

135

220

1995

PWESPMPCR

Non-Ferrous Metals Processing
- Copper

Wet ESP - Wire Plate
Type

99

95

923

135

220

1995

PWESPMPIS

Ferrous Metals Processing -
Iron & Steel Production

Wet ESP - Wire Plate
Type

99

95

923

135

220

1995

PWESPMPLD

Non-Ferrous Metals Processing
- Lead

Wet ESP - Wire Plate
Type

99

95

923

135

220

1995

PWESPMPOR

Non-Ferrous Metals Processing
- Other

Wet ESP - Wire Plate
Type

99

95

923

135

220

1995

PWESPMPZC

Non-Ferrous Metals Processing
- Zinc

Wet ESP - Wire Plate
Type

99

95

923

135

220

1995

PWESPWDPP

Wood Pulp & Paper

Wet ESP - Wire Plate
Type

99

95

923

135

220

1995

B-19


-------
Control Strategy Tool (CoST) Cost Equations

Table B-12. ptipm Sector PM Control Cost Equation Parameters (Equation Type 9)

cost cm
Abbreviation

Source
Group

Control
Technology

Control
Efficiency (%)

Capital Cost Variables



O&M Cost Variables





Cost
Year

PM-10

PM-2.5

tecs

teci

ec to cc

els

eli

dds

ddi

brs

bri

($ Yr)

PFFMSUBC2

Utility
Boilers -
Coal

Fabric Filter
- Mechanical
Shaker

99

99

5.702

77489

2.17

0.194

-15.96

0.7406

1.146

0.25

1221

1990

PFFMSUBG

Utility
Boilers -
Gas/Oil

Fabric Filter
- Mechanical
Shaker

95

95

5.702

77489

2.17

0.188

-19.58

0.0007

0.19

0.241

1224

1990

tecs = Total Equipment Cost Factor, teci = Total Equipment Cost Constant, ec to cc = Equipment to Capital Cost Multiplier, els = Electricity Factor, eli = Electricity
Constant, dds = Dust Dispersal Factor, ddi = Dust Disposal Constant, brs = Bag Replacement Factor, bri = Bag Replacement Constant

Table B-13. ptipm Sector PM Control Cost Equation Factors (Equation Type 10)

cost cm
Abbreviation

Source Group

Control Technology

Pollutant

Capital
Cost

Variable
O&M

Fixed
O&M

Cost
Year







Mult

Exp

Mult

Mult

Exp

($ Year)

PDESPMAGG

Utility Boilers -
Coal

Agglomerator

PM2.5

8.0

0.3

0.021

0.0

0.0

2005

PDESPM1FLD

Utility Boilers -
Coal

Adding Surface Area of
One ESP Field

PM2.5

13.75

0.3

0.0090

0.24

0.3

2005

PDESPM2FLD

Utility Boilers -
Coal

Adding Surface Area of
Two ESP Fields

PM2.5

17.5

0.3

0.013

0.31

0.3

2005

PDESPM2FAF

Utility Boilers -
Coal

Adding Surface Area of
Two ESP Fields, an
Agglomerator, and ID
Fans

PM2.5

37.2

0.3

0.042

0.53

0.3

2005

B-20


-------
Control Strategy Tool (CoST) Cost Equations

Table B-14. ptnonipm Sector SO2 Controls Default Cost per Ton Values (Equation Type 11)

CoST CM Abbreviation

Source Group

Control Technology

CE (%)

Boiler
Capacity
Bin
(mmBtu/hr)

Cost Per

Ton
Reduced
($/ton)

Capital

to
Annual
Ratio

Equipment
Life

Interest
Rate

Cost
Year

($
Year)

SSRBINJICB

ICI Boilers

In-duct Sorbent
Injection

40

All Sizes

1069



0



2003

SCHMADDHOM

Residential Nonpoint
Source

Chemical Additives to
Waste

75

All Sizes

2350



0



2002

SFGDICB

ICI Boilers

Flue Gas
Desulfurization

90

All Sizes

1109



0



2003

SLSFICB

ICI Boilers

Low Sulfur Fuel

80

All Sizes

2350



0



1999

SFGDICBOIL

ICI Boilers

Flue Gas
Desulfurization

90

All Sizes

2898



0



1999

SFUELSWECB

External Combustion
Boilers2

Fuel Switching

75

All Sizes

2350



0



1999

SSCRBPETCK

Petroleum Refinery
Catalytic and Thermal
Cracking Units

Wet Gas Scrubber

97

All Sizes

665



0



2004

SSCRBPETPH

Petroleum Refinery Process
Heaters

Scrubbing

96

All Sizes

26529



0



2004

SFUELSFC

Stationary Source Fuel
Combustion

Fuel Switching

75

All Sizes

2350



0



1999

SCATPETCRK

Petroleum Refinery
Catalytic and Thermal
Cracking Units

Catalyst Additive

43

All Sizes

1493



0



2004

SSCRBCEMKL

Cement Kilns

Wet Gas Scrubber

90

All Sizes

7000



0



2002

SSCRBDRKL

Cement Kilns

Wet Gas Scrubber

90

All Sizes

4000



0



2002

SSCRBPRKL

Cement Kilns

Wet Gas Scrubber

90

All Sizes

35000



0



2002

SSCRBPRPR

Cement Kilns

Wet Gas Scrubber

90

All Sizes

25000



0



2002

SSPRADRKL

Cement Kilns

Spray Dry Absorber

90

All Sizes

4000



0



2002

SSPRAPRPR

Cement Kilns

Spray Dry Absorber

90

All Sizes

25000



0



2002

SSPRAPRKL

Cement Kilns

Spray Dry Absorber

90

All Sizes

35000



0



2002

SSRTGSRP95

Sulfur Recovery Plants -
Elemental Sulfur (Claus: 2
Stage w/o control (92-95%
removal))

Sulfur Recovery
and/or Tail Gas
Treatment

99.84

All Sizes

643



15

7

1990

SSRTGSRP96

Sulfur Recovery Plants -
Elemental Sulfur (Claus: 3
Stage w/o control (95-96%
removal))

Sulfur Recovery
and/or Tail Gas
Treatment

99.78

All Sizes

643



15

7

1990

B-21


-------
Control Strategy Tool (CoST) Cost Equations

CoST CM Abbreviation

Source Group

Control Technology

CE (%)

Boiler
Capacity
Bin
(mmBtu/hr)

Cost Per

Ton
Reduced
($/ton)

Capital

to
Annual
Ratio

Equipment
Life

Interest
Rate

Cost
Year

($
Year)

SSRTGSRP97

Sulfur Recovery Plants -
Elemental Sulfur (Claus: 3
Stage w/o control (96-97%
removal))

Sulfur Recovery
and/or Tail Gas
Treatment

99.71

All Sizes

643



15

7

1990

SIDISIBBCL

Bituminous/Subbituminous
Coal (Industrial Boilers)

IDIS

40

<100

2107



30

7

1999

SIDISIBBCL

Bituminous/Subbituminous
Coal (Industrial Boilers)

IDIS

40

100-250

1526



30

7

1999

SIDISIBBCL

Bituminous/Subbituminous
Coal (Industrial Boilers)

IDIS

40

>250

1110



30

7

1999

SSDAJBBCL

Bituminous/Subbituminous
Coal (Industrial Boilers)

SDA

90

<100

1973



30

7

1999

SSDAJBBCL

Bituminous/Subbituminous
Coal (Industrial Boilers)

SDA

90

100-250

1341



30

7

1999

SSDAJBBCL

Bituminous/Subbituminous
Coal (Industrial Boilers)

SDA

90

>250

804



30

7

1999

SWFGSIBBCL

Bituminous/Subbituminous
Coal (Industrial Boilers)

Wet FGD

90

<100

1980



30

7

1999

SWFGSIBBCL

Bituminous/Subbituminous
Coal (Industrial Boilers)

Wet FGD

90

100-250

1535



30

7

1999

SWFGSIBBCL

Bituminous/Subbituminous
Coal (Industrial Boilers)

Wet FGD

90

>250

1027



30

7

1999

SIDISIBLG

Lignite (Industrial Boilers)

IDIS

40

<100

2107



30

7

1999

SIDISIBLG

Lignite (Industrial Boilers)

IDIS

40

100-250

1526



30

7

1999

SIDISIBLG

Lignite (Industrial Boilers)

IDIS

40

>250

1110



30

7

1999

SSDA IBLG

Lignite (Industrial Boilers)

SDA

90

<100

1973



30

7

1999

SSDA IBLG

Lignite (Industrial Boilers)

SDA

90

100-250

1341



30

7

1999

SSDA IBLG

Lignite (Industrial Boilers)

SDA

90

>250

804



30

7

1999

SWFGDIBLG

Lignite (Industrial Boilers)

Wet FGD

90

<100

1980



30

7

1999

SWFGDIBLG

Lignite (Industrial Boilers)

Wet FGD

90

100-250

1535



30

7

1999

SWFGDIBLG

Lignite (Industrial Boilers)

Wet FGD

90

>250

1027



30

7

1999

SWFGDIBRO

Residual Oil (Industrial
Boilers)

Wet FGD

90

<100

4524



30

7

1999

SWFGDIBRO

Residual Oil (Industrial
Boilers)

Wet FGD

90

100-250

3489



30

7

1999

SWFGDIBRO

Residual Oil (Industrial
Boilers)

Wet FGD

90

>250

2295



30

7

1999

SLSFRESHET

Residential Heating

Low Sulfur Fuel

75

All Sizes

2350



0



2002

B-22


-------
Control Strategy Tool (CoST) Cost Equations

Table B-15. ptnonipm Sector NOx Control Cost Parameters (Equation Type 12)

cost cm
Abbreviation

Source Group

Outlet
Cone,
(ppmv)

Fixed

Capital

Cost

Multiplier

Variable
Capital
Cost
Multiplier

Fixed O&M

Cost

Multiplier

Variable
O&M Cost
Multiplier

CRF

PRGFPRE02C

Petroleum Refinery
Gas-Fired Process
Heaters; Excess 02
Control

80

$20,000

-

$4,000

-

0.243890694

PRGFPRULNB

Petroleum Refinery
Gas-Fired Process
Heaters; Ultra Low
NOX Burners

40

-

$1,154,000

$56,000

$74,702

0.094392926

PRGFPRSCR

Petroleum Refinery
Gas-Fired Process
Heaters; SCR

20

-

$6,837,075

$121,000

$972,483

0.094392926

PRGFPRSC95

Petroleum Refinery
Gas-Fired Process
Heaters; SCR-95%

10

-

$8,888,198

$121,000

$1,171,507

0.094392926

Assumption

Value

Cost year

2008

Length of ductwork required

500 ft

Number of elbows per length of ductwork

0.02 per ft

Exhaust fan coefficient

22.1

Exhaust fan exponent

1.55

Exhaust fan diameter

35.5 in

Exhaust fan efficiency

70%

Gas transport velocity

3000 ft/min

Operating labor rate

$51.26 per hr

Electricity cost

$0.069981 per kWh

Dust disposal cost

$42.1411 per ton

Compressed air cost

$0.31 per scf

Lime cost

$95 per ton

B-23


-------
Control Strategy Tool (CoST) Cost Equations

Table B-17. Assumptions used in construction Equations Type 16

Assumption

Value

Density of exhaust qas

0.0709 lb/ft3

Density of scrubbinq liquid

62.4 lb/ft3

Packinq constant

28 ft2/ft3

Packinq cost factor

$20 per ft3

Factor to convert from FRP to other material

1

Minimum wettinq rate

1.3 ft2/hr

Cost factor for pump

$23.64 per qpm

Moles of caustic required per mole of SO2

1.0

Molecular weiqht of caustic

62 Ib/lb-mol

Cost factor for caustic

$440 per ton

Molecular weiqht of qaseous exhaust stream

29 Ib/lb-mol

Moles of salt produced per mole of SO2

1

Molecular weiqht of salt

58.5 Ib/lb-mol

Fraction of waste stream that is treated

0.1

Wastewater disposal cost

$0.0054 per qal

Water cost

$0.00060 per qal

Adjustment for 76% Na20 solution

0.76

Pump pressure

60 ft H2O

Pump efficiency

70%

Packinq constant 1

0.24

Packinq constant 2

0.17

Friction loss factor for elbows in ductwork

0.35

Assumption

Value

Water cost

$0.20 per 1,000 qal

Makeup lime stoichiometric ratio

2.5 to 1

Assumption

Value

Sodium bicarbonate cost

$440 per ton

Makeup lime stoichiometric ratio

2.5 to 1

B-24


-------
Control Strategy Tool (CoST) Cost Equations

Table B-20. NOx ptnonipm Default Control Technologies (Equation Type 2)

CoST CM Abbreviation

Source Group

Control Technology

CE

NAFRICGS

Internal Combustion Engines - Gas

AF RATIO

20

NAFRIICGS

Internal Combustion Engines - Gas

AF + IR

30

NBINTCEMK

Cement Kilns

Biosolid Injection Technology

23

NCLPTGMCN

Glass Manufacturing - Container

Cullet Preheat

25

NCLRBIBCC

ICI Boilers - Coal/Cyclone

Coal Reburn

50

NCUPHGMPD

Glass Manufacturing - Pressed

Cullet Preheat

25

NDOXYFGMG

Glass Manufacturing - General

OXY-Firing

85

NDSCRBCCK

In-Process; Bituminous Coal; Cement Kiln

SCR

90

NDSCRBCGN

In-Process Fuel Use;Bituminous Coal; Gen

SCR

90

NDSCRBCLK

In-Process; Bituminous Coal; Lime Kiln

SCR

90

NDSCRCMDY

Cement Manufacturing - Dry

SCR

90

NDSCRCMWT

Cement Manufacturing - Wet

SCR

90

NDSCRFEP

Taconite Iron Ore Processing - Induration - Coal or Gas

SCR

90

NDSCRFFCCU

Fluid Cat Cracking Units; Cracking Unit

SCR

90

NDSCRFPGCO

In-Process; Process Gas; Coke Oven Gas

SCR

90

NDSCRIBCF

ICI Boilers - Coal/FBC

SCR

90

NDSCRIBCK

ICI Boilers - Coke

SCR

90

NDSCRIBCS

ICI Boilers - Coal/Stoker

SCR

90

NDSCRIBLP

ICI Boilers - LPG

SCR

90

NDSCRIBLW

ICI Boilers - Liguid Waste

SCR

90

NDSCRIBPG

ICI Boilers - Process Gas

SCR

90

NDSCRIBW

ICI Boilers - Wood/Bark/Waste

SCR

90

NDSCRIDIN

Indust. Incinerators

SCR

90

NDSCRISAN

Iron & Steel Mills - Annealing

SCR

90

NDSCRNAMF

Nitric Acid Manufacturing

SCR

90

NDSCRPPNG

Pulp and Paper - Natural Gas - Incinerators

SCR

90

NDSCRSPRF

Sulfate Pulping - Recovery Furnaces

SCR

90

NDSCRSPRF

Sulfate Pulping - Recovery Furnaces

SCR

80

NDSCRSWIN

Solid Waste Disp;Gov;Other lncin;Sludge

SCR

90

NDSCRUNGGN

In-Process Fuel Use; Natural Gas; Gen

SCR

90

NDSCRUPGCO

In-Process; Process Gas; Coke Oven Gas2

SCR

90

NDSCRUROGN

In-Process Fuel Use; Residual Oil; Gen

SCR

90

NELBOGMCN

Glass Manufacturing - Container

Electric Boost

10

NELBOGMFT

Glass Manufacturing - Flat

Electric Boost

10

NELBOGMPD

Glass Manufacturing - Pressed

Electric Boost

10

NEPABURN96

Agricultural Burning

Seasonal Ban (Ozone Season Daily Only)

100

NEPOBRUN96

Open Burning

Episodic Ban (Daily Only)

100

NEXABADMF

Adipic Acid Manufacturing

Extended Absorption

86

B-25


-------
Control Strategy Tool (CoST) Cost Equations

CoST CM Abbreviation

Source Group

Control Technology

CE

NEXABNAMF

Nitric Acid Manufacturing

Extended Absorption

95

NIRICGD

IC Engines - Gas/ Diesel/ LPG

IR

25

NIRICGS

Internal Combustion Engines - Gas

IR

20

NIRICOL

Internal Combustion Engines - Oil

IR

25

NIRRICOIL

Reciprocating IC Engines - Oil

IR

25

NLEAISRH

Iron & Steel Mills - Reheating

LEA

13

NLECICEGAS

Lean Burn IC Engine - Gas

Low Emission Combustion

87

NLECINGIC2

Industrial NG ICE, 2cycle (lean)

Low Emission Combustion

87

NLELSICGS

Internal Combustion Engines - Gas

L-E (Low Speed)

87

NLEMSICGS

Internal Combustion Engines - Gas

L-E (Medium Speed)

87

NLNBFAPFD

Ammonia Prod; Feedstock Desulfurization

LNB + FGR

60

NLNBFCOBF

ln-Proc;Process Gas;Coke Oven/Blast Furn

LNB + FGR

55

NLNBFCSRS

Pri Cop Smel; Reverb Smelt Furn

LNB + FGR

60

NLNBFFCCU

Fluid Cat Cracking Units; Cracking Unit

LNB + FGR

55

NLNBFFPHP

Fuel Fired Eguip; Process Htrs; Pro Gas

LNB + FGR

55

NLNBFFRNG

Ammonia - NG-Fired Reformers

LNB + FGR

60

NLNBFFROL

Ammonia - Oil-Fired Reformers

LNB + FGR

60

NLNBFGROFA

ICI Boilers - Gas

LNB + FGR + Over Fire Air

80

NLNBFGRPH

Fuel Fired Eguip/ Process Heaters

LNB + FGR

50

NLNBFIBDO

ICI Boilers - Distillate Oil

LNB + FGR

60

NLNBFIBLP

ICI Boilers-LPG

LNB + FGR

60

NLNBFIBLW

ICI Boilers - Liguid Waste

LNB + FGR

60

NLNBFIBNG

ICI Boilers - Natural Gas

LNB + FGR

60

NLNBFIBPG

ICI Boilers - Process Gas

LNB + FGR

60

NLNBFIBRO

ICI Boilers - Residual Oil

LNB + FGR

60

NLNBFIPBH

Iron Prod; Blast Furn; Blast Htg Stoves

LNB + FGR

77

NLNBFISAN

Iron & Steel Mills - Annealing

LNB + FGR

60

NLNBFISGV

Iron & Steel Mills - Galvanizing

LNB + FGR

60

NLNBFISRH

Iron & Steel Mills - Reheating

LNB + FGR

77

NLNBFPHDO

Process Heaters - Distillate Oil

LNB + FGR

48

NLNBFPHLG

Process Heaters - LPG

LNB + FGR

55

NLNBFPHLG

Process Heaters - LPG

LNB + FGR

484

NLNBFPHLP

Process Heaters - LPG

LNB + FGR

48

NLNBFPHNG

Process Heaters - Natural Gas

LNB + FGR

55

NLNBFPHOF

Process Heaters - Other Fuel

LNB + FGR

34

NLNBFPHPG

Process Heaters - Process Gas

LNB + FGR

55

NLNBFPHRO

Process Heaters - Residual Oil

LNB + FGR

34

4 Emissions cutoff < 365 tons/yr

B-26


-------
Control Strategy Tool (CoST) Cost Equations

CoST CM Abbreviation

Source Group

Control Technology

CE

NLNBFPPAR

Plastics Prod-Specific; (ABS) Resin

LNB + FGR

55

NLNBFSGDR

Sand/Gravel; Dryer

LNB + FGR

55

NLNBFSHDO

Space Heaters - Distillate Oil

LNB + FGR

60

NLNBFSHNG

Space Heaters - Natural Gas

LNB + FGR

60

NLNBFSMCO

Starch Mfg; Combined Operations

LNB + FGR

55

NLNBFSPRF

Sulfate Pulping - Recovery Furnaces

LNB + FGR

60

NLNBFSPSP

Steel Prod; Soaking Pits

LNB + FGR

60

NLNBICB

ICI Boilers - Coal/ subbituminous

LNB

51

NLNBICISWH

ICI Space and Water Heaters

LNB

7

NLNBNISAN

Iron & Steel Mills - Annealing

LNB + SNCR

80

NLNBNPHDO

Process Heaters - Distillate Oil

LNB + SNCR

78

NLNBNPHLP

Process Heaters - LPG

LNB + SNCR

78

NLNBNPHNG

Process Heaters - Natural Gas

LNB + SNCR

80

NLNBNPHOF

Process Heaters - Other Fuel

LNB + SNCR

75

NLNBNPHPG

Process Heaters - Process Gas

LNB + SNCR

80

NLNBNPHRO

Process Heaters - Distillate & Residual Oil

LNB + SNCR

75

NLNBOAICBG

ICI Boilers - Gas

LNB + Over Fire Air

60

NLNBOAICBO

ICI Boilers - Oil

LNB + Over Fire Air

50

NLNBOAICBO

ICI Boilers - Oil

LNB + Over Fire Air

305

NLNBOFAICB

ICI Boilers - Coal/ bituminous

LNB + Over Fire Air

51

NLNBOFAICS

ICI Boilers - Coal/ subbituminous

LNB + Over Fire Air

65

NLNBPHLP

Process Heaters - LPG

LNB

45

NLNBSASF

Sec Alum Prod; Smelting Furn/Reverb

LNB

50

NLNBSISAN

Iron & Steel Mills - Annealing

LNB + SCR

90

NLNBSPHDO

Process Heaters - Distillate Oil

LNB + SCR

90

NLNBSPHLP

Process Heaters - LPG

LNB + SCR

92

NLNBSPHNG

Process Heaters - Natural Gas

LNB + SCR

80

NLNBSPHNG

Process Heaters - Natural Gas

LNB + SCR

904

NLNBSPHOF

Process Heaters - Other Fuel

LNB + SCR

91

NLNBSPHPG

Process Heaters - Process Gas

LNB + SCR

90

NLNBSPHRO

Process Heaters - Residual Oil

LNB + SCR

90

NLNBSPWHNG

Water Heater, Space Heater - Natural Gas

LNB

7

NLNBUACCP

Asphaltic Cone; Rotary Dryer; Conv Plant

LNB

50

NLNBUCCAB

Conv Coating of Prod; Acid Cleaning Bath

LNB

50

NLNBUCCFB

Coal Cleaning-Thrml Dryer; Fluidized Bed

LNB

50

NLNBUCCMD

Ceramic Clay Mfg; Drying

LNB

50

NLNBUCHNG

Surf Coat Oper;Coating Oven Htr;Nat Gas

LNB

50

5 Emissions cutoff < 365 tons/yr

B-27


-------
Control Strategy Tool (CoST) Cost Equations

CoST CM Abbreviation

Source Group

Control Technology

CE

NLNBUCMDY

Cement Manufacturing - Dry

LNB

25

NLNBUCMWT

Cement Manufacturing - Wet

LNB

25

NLNBUFFNG

Fuel Fired Equip; Furnaces; Natural Gas

LNB

50

NLNBUFMTF

Fbrqlass Mfq; Txtle-Type Fbr; Recup Furn

LNB

40

NLNBUFRNG

Ammonia - NG-Fired Reformers

LNB

50

NLNBUFROL

Ammonia - Oil-Fired Reformers

LNB

50

NLNBUGMCN

Glass Manufacturinq - Container

LNB

40

NLNBUGMFT

Glass Manufacturinq - Flat

LNB

40

NLNBUGMPD

Glass Manufacturinq - Pressed

LNB

40

NLNBUIBCK

ICI Boilers - Coke

LNB

50

NLNBUIBDO

ICI Boilers - Distillate Oil

LNB

50

NLNBUIBLP

ICI Boilers - LPG

LNB

50

NLNBUIBLW

ICI Boilers - Liquid Waste

LNB

50

NLNBUIBNG

ICI Boilers - Natural Gas

LNB

50

NLNBUIBPG

ICI Boilers - Process Gas

LNB

50

NLNBUIBRO

ICI Boilers - Residual Oil

LNB

50

NLNBUISAN

Iron & Steel Mills - Annealinq

LNB

50

NLNBUISGV

Iron & Steel Mills - Galvanizinq

LNB

50

NLNBUISRH

Iron & Steel Mills - Reheatinq

LNB

66

NLNBULMKN

Lime Kilns

LNB

30

NLNBUNGGN

In-Process Fuel Use; Natural Gas; Gen

LNB

50

NLNBUPGCO

In-Process; Process Gas; Coke Oven Gas

LNB

50

NLNBUPHDO

Process Heaters - Distillate Oil

LNB

45

NLNBUPHLG

Process Heaters - LPG

LNB

50

NLNBUPHNG

Process Heaters - Natural Gas

LNB

50

NLNBUPHOF

Process Heaters - Other Fuel

LNB

37

NLNBUPHPG

Process Heaters - Process Gas

LNB

50

NLNBUPHRO

Process Heaters - Residual Oil

LNB

37

NLNBUROGN

In-Process Fuel Use; Residual Oil; Gen

LNB

37

NLNBUSFHT

Steel Foundries; HeatTreatinq Furn

LNB

50

NLNBUSHDO

Space Heaters - Distillate Oil

LNB

50

NLNBUSHNG

Space Heaters - Natural Gas

LNB

50

NLNBUSPRF

Sulfate Pulpinq - Recovery Furnaces

LNB

50

NLNCMNGC03

Commercial/Institutional - NG

LNB (1997 AQMD)

75

NLNRSNGC03

Residential NG

LNB (1997 AQMD)

75

NMKFRCMDY

Cement Manufacturinq - Dry

Mid-Kiln Firinq

30

NMKFRCMWT

Cement Manufacturinq - Wet

Mid-Kiln Firinq

30

NNGRIBCC

ICI Boilers - Coal/Cyclone

NGR

55

NNSCRNAMF

Nitric Acid Manufacturinq

NSCR

98

B-28


-------
Control Strategy Tool (CoST) Cost Equations

CoST CM Abbreviation

Source Group

Control Technology

CE

NNSCRRBGD

Rich Burn IC Engines - Gas/ Diesel/ LPG

NSCR

90

NNSCRRBIC

Rich Burn Internal Combustion Engines - Diesel

NSCR

90

NNSCRRBIC2

Rich Burn Internal Combustion Engines - Nat. Gas

NSCR

90

NOTWIFRNG

Ammonia - NG-Fired Reformers

OT + Wl

65

NOTWIIBNG

ICI Boilers - Natural Gas

OT + Wl

65

NOTWIIBPG

ICI Boilers - Process Gas

OT + Wl

65

NOTWISHNG

Space Heaters - Natural Gas

OT + Wl

65

NOTWISPRF

Sulfate Pulping - Recovery Furnaces

OT +Wl

65

NOXYFGMCN

Glass Manufacturing - Container

OXY-Firing

85

NOXYFGMFT

Glass Manufacturing - Flat

OXY-Firing

85

NOXYFGMPD

Glass Manufacturing - Pressed

OXY-Firing

85

NR25COL96

Industrial Coal Combustion

RACT to 25 tpy (LNB)

21

NR25NGC96

Industrial NG Combustion

RACT to 25 tpy (LNB)

31

NR250IL96

Industrial Oil Combustion

RACT to 25 tpy (LNB)

36

NR50COL96

Industrial Coal Combustion

RACT to 50 tpy (LNB)

21

NR50NGC96

Industrial NG Combustion

RACT to 50 tpy (LNB)

31

NR50OIL96

Industrial Oil Combustion

RACT to 50 tpy (LNB)

36

NSCRCMDY

Cement Manufacturing - Dry2

SCR

80

NSCRFRNG

Ammonia - NG-Fired Reformers2

SCR

90

NSCRFROL

Ammonia - Oil-Fired Reformers

SCR

80

NSCRGMCN

Glass Manufacturing - Container

SCR

75

NSCRGMFT

Glass Manufacturing - Flat

SCR

75

NSCRGMPD

Glass Manufacturing - Pressed

SCR

75

NSCRIBCC

ICI Boilers - Coal/Cyclone

SCR

90

NSCRIBCK

ICI Boilers - Coke2

SCR

90

NSCRIBCOAL

ICI Boilers - Coal

SCR

80

NSCRIBLP

ICI Boilers - LPG2

SCR

90

NSCRIBLW

ICI Boilers - Liguid Waste2

SCR

90

NSCRIBPG

ICI Boilers - Process Gas2

SCR

90

NSCRICBG

ICI Boilers - Gas

SCR

80

NSCRICBO

ICI Boilers - Oil

SCR

80

NSCRICGD

IC Engines - Gas/ Diesel/ LPG

SCR

80

NSCRICGS

Internal Combustion Engines - Gas

SCR

90

NSCRICOL

Internal Combustion Engines - Oil

SCR

80

NSCRISAN

Iron & Steel Mills - Annealing2

SCR

90

NSCRISAN

Iron & Steel Mills - Annealing2

SCR

99s

NSCRNAMF

Nitric Acid Manufacturing2

SCR

90

6 Emissions cutoff < 365 tons/yr

B-29


-------
Control Strategy Tool (CoST) Cost Equations

CoST CM Abbreviation

Source Group

Control Technology

CE

NSCRNGCP

Natural Gas Prod; Compressors

SCR

20

NSCRPHDO

Process Heaters - Distillate Oil

SCR

75

NSCRPHLP

Process Heaters - LPG

SCR

75

NSCRPHNG

Process Heaters - Natural Gas

SCR

75

NSCRPHOF

Process Heaters - Other Fuel

SCR

75

NSCRPHPG

Process Heaters - Process Gas

SCR

75

NSCRPHRO

Process Heaters - Residual Oil

SCR

75

NSCRRICOIL

Reciprocatinq IC Enqines - Oil

SCR

80

NSCRSHDO

Space Heaters - Distillate Oil

SCR

80

NSCRSHNG

Space Heaters - Natural Gas

SCR

80

NSCRSPRF

Sulfate Pulpinq - Recovery Furnaces2

SCR

90

NSCRWGTJF

Gas Turbines - Jet Fuel

SCR + Water Injecti

90

NSNCNCMDY

Cement Manufacturinq - Dry

SNCR - NH3 Based

50

NSNCRBCCK

In-Process; Bituminous Coal; Cement Kiln

SNCR - urea based

50

NSNCRBCGN

In-Process Fuel Use; Bituminous Coal; Gen

SNCR

40

NSNCRBCLK

In-Process; Bituminous Coal; Lime Kiln

SNCR - urea based

50

NSNCRCIIN

Comm./Inst. Incinerators

SNCR

45

NSNCRCMDY

Cement Manufacturinq - Dry

SNCR - Urea Based

50

NSNCRCMOU

By-Product Coke Mfq; Oven Underfirinq

SNCR

60

NSNCRFRNG

Ammonia - NG-Fired Reformers

SNCR

50

NSNCRFROL

Ammonia - Oil-Fired Reformers

SNCR

50

NSNCRGMCN

Glass Manufacturinq - Container

SNCR

40

NSNCRGMFT

Glass Manufacturinq - Flat

SNCR

40

NSNCRGMPD

Glass Manufacturinq - Pressed

SNCR

40

NSNCRIBC

ICI Boilers - Coal

SNCR

40

NSNCRIBCC

ICI Boilers - Coal/Cyclone

SNCR

35

NSNCRIBCK

ICI Boilers - Coke

SNCR

40

NSNCRIBGA

ICI Boilers - Baqasse

SNCR - Urea

55

NSNCRIBLP

ICI Boilers-LPG

SNCR

50

NSNCRIBLW

ICI Boilers - Liquid Waste

SNCR

50

NSNCRIBMS

ICI Boilers - MSW/Stoker

SNCR - Urea

55

NSNCRICBG

ICI Boilers - Gas

SNCR

40

NSNCRICBO

ICI Boilers - Oil

SNCR

40

NSNCRICGS

Internal Combustion Enqines - Gas

SNCR

90

NSNCRIDIN

Indust. Incinerators

SNCR

45

NSNCRINGI4

Industrial NG ICE, 4cycle (rich)

SNCR

90

NSNCRISAN

Iron & Steel Mills - Annealinq

SNCR

60

NSNCRMWCB

Municipal Waste Combustors

SNCR

45

NSNCRMWIN

Medical Waste Incinerators

SNCR

45

B-30


-------
Control Strategy Tool (CoST) Cost Equations

CoST CM Abbreviation	Source Group	Control Technology	CE

NSNCRPHDO	Process Heaters - Distillate Oil	SNCR	60

NSNCRPHLP	Process Heaters - LPG	SNCR	60

NSNCRPHNG	Process Heaters - Natural Gas	SNCR	60

NSNCRPHOF	Process Heaters - Other Fuel	SNCR	60

NSNCRPHPG	Process Heaters - Process Gas	SNCR	60

NSNCRPHRO	Process Heaters - Residual Oil	SNCR	60

NSNCRSHDO	Space Heaters - Distillate Oil	SNCR	50

NSNCRSHNG	Space Heaters - Natural Gas	SNCR	50

NSNCRSPRF	Sulfate Pulping - Recovery Furnaces	SNCR	50

NSNCRSWIN	Solid Waste Disp; Gov; Other Incin; Sludge	SNCR	45

NTHRDADMF	Adipic Acid Manufacturing	Thermal Reduction	81

NULNBPHDO	Process Heaters - Distillate Oil	ULNB	74

NULNBPHLP	Process Heaters - LPG	ULNB	74

NULNBPHNG	Process Heaters - Natural Gas	ULNB	75

NULNBPHOF	Process Heaters - Other Fuel	ULNB	73

NULNBPHPG	Process Heaters - Process Gas	ULNB	75

NULNBPHRO	Process Heaters - Residual Oil	ULNB	73

NWHCMNGC99	Commercial/Institutional - NG	Water heater replacement	7-45

NWHRSNGC99	Residential NG	Water heater replacement	7-45

NWIGTAGT	Gas Turbines	Water Injection	40

NWLCMNGC99	Commercial/Institutional - NG	Water heater + LNB Space heaters	7-44

NWLRSNGC99	Residential NG	Water heater + LNB Space heaters	7-44

NWTINGTJF	Gas Turbines - Jet Fuel	Water Injection	68

Table B-21. NOx ptnonipm Default Cost per Ton Values (Equation Type 2)

NAFRICGS	1570	1570	2.8	0.1098	1990	<365

NCLRBIBCC	1570	1570	2	0.0944	1990	<365

B-31


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation



Cost per Ton
($/ton reduced)

Capital
/Annual
Cost

CRF

Cost Year
($Year)

Emissions
Cutoff

Default Incremental

Ratio



(tons/yr)

NCUPHGMPD

810

810

4.5

0.1424

1990

< 365

NDOXYFGMG

4277







1999



NDSCRBCCK

2119







1999



NDSCRBCGN

3027







1999



NDSCRBCLK

2119







1999



NDSCRCMDY

4636







1999



NDSCRCMWT

3962







1999



NDSCRFEP

5269







1999



NDSCRFFCCU

3457







1999



NDSCRFPGCO

6371







1999



NDSCRIBCF

1159







1999



NDSCRIBCK

1610







1999



NDSCRIBCS

2531







1999



NDSCRIBLP

2958







1990



NDSCRIBLW

1568







1999



NDSCRIBPG

2366







1999



NDSCRIBW

3274







1999



NDSCRIDIN

3109







1999



NDSCRISAN

5269







1999



NDSCRNAMF

812







1999



NDSCRPPNG

3109







1999



NDSCRSPRF

2366







1999



NDSCRSPRF

1720







1990



NDSCRSWIN

3109







1999



NDSCRUNGGN

4953







1999



NDSCRUPGCO

4953







1999



NDSCRUROGN

4458







1999



NELBOGMCN

7150

7150

0

0.1424

1990

> 365

NELBOGMCN

7150

7150

0

0.1424

1990

< 365

NELBOGMFT

2320

2320

0

0.1424

1990

> 365

NELBOGMFT

2320

2320

0

0.1424

1990

< 365

NELBOGMPD

8760

8760

0

0.1424

1990

> 365

NELBOGMPD

2320

8760

0

0.1424

1990

< 365

NEPABURN96

0







1990



NEPOBRUN96

0







1990



NEXABADMF

90

90

6.7

0.1424

1990

> 365

NEXABADMF

90

90

6.7

0.1424

1990

< 365

NEXABNAMF

480

480

8.1

0.1424

1990

> 365

B-32


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation



Cost per Ton
($/ton reduced)

Capital
/Annual
Cost

CRF

Cost Year
($Year)

Emissions
Cutoff

Default Incremental

Ratio



(tons/yr)

NEXABNAMF

480

480

8.1

0.1424

1990

< 365

NIRICGD

490

490

0.6

0.1098

1990

> 365

NIRICGD

770

770

1.1

0.1098

1990

< 365

NIRICGS

550

550

0.7

0.1098

1990

> 365

NIRICGS

1020

1020

1.2

0.1098

1990

< 365

NIRICOL

490

490

0.6

0.1098

1990

> 365

NIRICOL

770

770

1.1

0.1098

1990

< 365

NIRRICOIL

770



1.1



1999



NLEAISRH

1320

1320

3.8

0.1424

1990

> 365

NLEAISRH

1320

1320

3.8

0.1424

1990

< 365

NLECICEGAS

422



2.3



1993



NLECINGIC2

521







1999



NLELSICGS

630





0.1098

1990

> 365

NLELSICGS

1680





0.1098

1990

< 365

NLEMSICGS

380





0.1098

1990

> 365

NLEMSICGS

380





0.1098

1990

< 365

NLNBFAPFD

590

280

7.5

0.1424

1990

> 365

NLNBFAPFD

2560

2470

5.9

0.1424

1990

< 365

NLNBFCOBF

2470

830

6.8

0.1098

1990

> 365

NLNBFCOBF

3190

1430

6.9

0.1098

1990

< 365

NLNBFCSRS

750

250

7

0.1424

1990

> 365

NLNBFCSRS

750

250

7

0.1424

1990

< 365

NLNBFFCCU

2470

830

6.8

0.1098

1990

> 365

NLNBFFCCU

3190

1430

6.9

0.1098

1990

< 365

NLNBFFPHP

2470

830

6.8

0.1098

1990

> 365

NLNBFFPHP

3190

1430

6.9

0.1098

1990

< 365

NLNBFFRNG

590

280

7.5

0.1424

1990

> 365

NLNBFFRNG

2560

2470

5.9

0.1424

1990

< 365

NLNBFFROL

390

190

7.5

0.1424

1990

> 365

NLNBFFROL

1120

1080

5.9

0.1424

1990

< 365

NLNBFGROFA

368



7.8



2003

> 365

NLNBFGROFA

1278



7.8



2003

< 365

NLNBFGRPH

570



7.3

0.1098

1990



NLNBFIBDO

760

370

7.5

0.1424

1990

> 365

NLNBFIBDO

2490

1090

5.9

0.1424

1990

< 365

NLNBFIBLP

760

370

7.5

0.1424

1990

> 365

NLNBFIBLP

2490

1090

5.9

0.1424

1990

< 365

NLNBFIBLW

390

190

7.5

0.1424

1990

> 365

B-33


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation



Cost per Ton
($/ton reduced)

Capital
/Annual
Cost

CRF

Cost Year
($Year)

Emissions
Cutoff

Default Incremental

Ratio



(tons/yr)

NLNBFIBLW

1120

1080

5.9

0.1424

1990

< 365

NLNBFIBNG

590

280

7.5

0.1424

1990

> 365

NLNBFIBNG

2560

2470

5.9

0.1424

1990

< 365

NLNBFIBPG

590

280

7.5

0.1424

1990

> 365

NLNBFIBPG

2560

2470

5.9

0.1424

1990

< 365

NLNBFIBRO

390

190

7.5

0.1424

1990

> 365

NLNBFIBRO

1120

1080

5.9

0.1424

1990

< 365

NLNBFIPBH

380

150

4.1

0.2439

1990

> 365

NLNBFIPBH

380

150

4.1

0.2439

1990

< 365

NLNBFISAN

750

250

7

0.1424

1990

> 365

NLNBFISAN

750

250

7

0.1424

1990

< 365

NLNBFISGV

580

190

6.5

0.15350001

1990

> 365

NLNBFISGV

580

190

6.5

0.15350001

1990

< 365

NLNBFISRH

380

150

4.1

0.2439

1990

> 365

NLNBFISRH

380

150

4.1

0.2439

1990

< 365

NLNBFPHDO

1680

16680

6.8

0.1098

1990

> 365

NLNBFPHDO

4250

19540

7.1

0.1098

1990

< 365

NLNBFPHLG

3200



7.1

0.1098

1990

> 365

NLNBFPHLG

4200



7.1

0.1098

1990

< 365

NLNBFPHLP

1680

16680

6.8

0.1098

1990

> 365

NLNBFPHLP

4250

19540

7.1

0.1098

1990

< 365

NLNBFPHNG

3200

9160

6.8

0.1098

1990

> 365

NLNBFPHNG

4200

15580

6.9

0.1098

1990

< 365

NLNBFPHOF

1380

1380

6.8

0.1098

1990

> 365

NLNBFPHOF

3490

3490

7.1

0.1098

1990

< 365

NLNBFPHPG

3200

9160

6.8

0.1098

1990

> 365

NLNBFPHPG

4200

15580

6.9

0.1098

1990

< 365

NLNBFPHRO

1380

1380

6.8

0.1098

1990

> 365

NLNBFPHRO

3490

3490

7.1

0.1098

1990

< 365

NLNBFPPAR

2470

830

6.8

0.1098

1990

> 365

NLNBFPPAR

3190

1430

6.9

0.1098

1990

< 365

NLNBFSGDR

2470

830

6.8

0.1098

1990

> 365

NLNBFSGDR

3190

1430

6.9

0.1098

1990

< 365

NLNBFSHDO

760

370

7.5

0.1424

1990

> 365

NLNBFSHDO

2500

1090

5.9

0.1424

1990

< 365

NLNBFSHNG

590

280

7.5

0.1424

1990

> 365

NLNBFSHNG

2650

2470

5.9

0.1424

1990

< 365

NLNBFSMCO

2470

830

6.8

0.1098

1990

> 365

B-34


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation



Cost per Ton
($/ton reduced)

Capital
/Annual
Cost

CRF

Cost Year
($Year)

Emissions
Cutoff

Default Incremental

Ratio



(tons/yr)

NLNBFSMCO

3190

1430

6.9

0.1098

1990

< 365

NLNBFSPRF

590

280

7.5

0.1424

1990

> 365

NLNBFSPRF

2560

2470

5.9

0.1424

1990

< 365

NLNBFSPSP

750

250

7

0.1424

1990

> 365

NLNBFSPSP

750

250

7

0.1424

1990

< 365

NLNBICB

256



4.5



2003

> 365

NLNBICB

850



4.5



2003

< 365

NLNBICISWH

1230



5.5



1990



NLNBNISAN

1720

1320

3.7

0.1424

1990

> 365

NLNBNISAN

1720

1320

3.7

0.1424

1990

< 365

NLNBNPHDO

1880

3150

5.9

0.1098

1990

> 365

NLNBNPHDO

3620

3830

6.5

0.1098

1990

< 365

NLNBNPHLP

1880

3150

5.9

0.1098

1990

> 365

NLNBNPHLP

3620

3830

6.5

0.1098

1990

< 365

NLNBNPHNG

2590

3900

6.4

0.1098

1990

> 365

NLNBNPHNG

3520

6600

6.7

0.1098

1990

< 365

NLNBNPHOF

1240

1760

5.5

0.1098

1990

> 365

NLNBNPHOF

2300

2080

6.4

0.1098

1990

< 365

NLNBNPHPG

2590

3900

6.4

0.1098

1990

> 365

NLNBNPHPG

3520

6600

6.7

0.1098

1990

< 365

NLNBNPHRO

1240

1760

5.5

0.1098

1990

> 365

NLNBNPHRO

2300

2080

6.4

0.1098

1990

< 365

NLNBOAICBG

280



2.7



2003

> 365

NLNBOAICBG

1052



2.7



2003

< 365

NLNBOAICBO

306



2.9



2003

> 365

NLNBOAICBO

1052



2.9



2003

< 365

NLNBOFAICB

392



3.3



2003

> 365

NLNBOFAICB

1239



3.3



2003

< 365

NLNBOFAICS

306



3.1



2003

> 365

NLNBOFAICS

972



3.1



2003

< 365

NLNBPHLP

970

970

7.3

0.1098

1990

> 365

NLNBPHLP

3470

3470

7.3

0.1098

1990

< 365

NLNBSASF

570

570

7

0.1424

1990

> 365

NLNBSASF

570

570

7

0.1424

1990

< 365

NLNBSISAN

4080

3720

5.1

0.1424

1990

> 365

NLNBSISAN

4080

3720

5.1

0.1424

1990

< 365

NLNBSPHDO

8687

8687

7

0.1098

1999



NLNBSPHLP

9120

9430

7

0.1098

1990

> 365

B-35


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation



Cost per Ton
($/ton reduced)

Capital
/Annual
Cost

CRF

Cost Year
($Year)

Emissions
Cutoff

Default Incremental

Ratio



(tons/yr)

NLNBSPHLP

11500

15350

6.5

0.1098

1990

< 365

NLNBSPHNG

12378

12378

6.8

0.11

1999

> 365

NLNBSPHNG

12378

12378

6.8

0.1098

1999

< 365

NLNBSPHOF

3160

4840

7

0.1098

1990

> 365

NLNBSPHOF

5420

7680

6.6

0.1098

1990

< 365

NLNBSPHPG

12378

12378

6.4

0.1098

1999

> 365

NLNBSPHPG

12378

12378

6.8

0.1098

1999

< 365

NLNBSPHRO

5240

5240

6.6

0.1098

1999

< 365

NLNBSPWHNG

770







1999



NLNBUACCP

1800

1800

7.3

0.1098

1990

> 365

NLNBUACCP

2200

2200

7.3

0.1098

1990

< 365

NLNBUCCAB

1800

1800

7.3

0.1098

1990

> 365

NLNBUCCAB

2200

2200

7.3

0.1098

1990

< 365

NLNBUCCFB

200

1090

4.5

0.1424

2003

> 365

NLNBUCCFB

1000

1460

4.5

0.1424

2003

< 365

NLNBUCCMD

1800

1800

7.3

0.1098

1990

> 365

NLNBUCCMD

2200

2200

7.3

0.1098

1990

< 365

NLNBUCHNG

1800

1800

7.3

0.1098

1990

> 365

NLNBUCHNG

2200

2200

7.3

0.1098

1990

< 365

NLNBUCMDY

440

440

5

0.1098

1997

> 365

NLNBUCMDY

440

440

5

0.1098

1997

< 365

NLNBUCMWT

440

440

5

0.1098

1997

> 365

NLNBUCMWT

440

440

5

0.1098

1997

< 365

NLNBUFFNG

570

570

7

0.1424

1990

> 365

NLNBUFFNG

570

570

7

0.1424

1990

< 365

NLNBUFMTF

1690

1690

2.2

0.3811

1990

> 365

NLNBUFMTF

1690

1690

2.2

0.3811

1990

< 365

NLNBUFRNG

650

650

5.5

0.1424

1990

> 365

NLNBUFRNG

820

820

5.5

0.1424

1990

< 365

NLNBUFROL

430

430

5.5

0.1424

1990

> 365

NLNBUFROL

400

400

5.5

0.1424

1990

< 365

NLNBUGMCN

700

1690

2.2

0.1424

1990

> 365

NLNBUGMCN

700

1690

2.2

0.1424

1990

< 365

NLNBUGMFT

700

700

2.2

0.3811

1990

> 365

NLNBUGMFT

700

700

2.2

0.3811

1990

< 365

NLNBUGMPD

1500

1500

2.2

0.1424

1990

> 365

NLNBUGMPD

1500

1500

2.2

0.1424

1990

< 365

NLNBUIBCK

1090

1090

4.5

0.1424

1990

> 365

B-36


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation



Cost per Ton
($/ton reduced)

Capital
/Annual
Cost

CRF

Cost Year
($Year)

Emissions
Cutoff

Default Incremental

Ratio



(tons/yr)

NLNBUIBCK

1460

1460

4.5

0.1424

1990

< 365

NLNBUIBDO

2070

2070

5.5

0.1424

1990

> 365

NLNBUIBDO

1180

1180

5.5

0.1424

1990

< 365

NLNBUIBLP

2070

2070

5.5

0.1424

1990

> 365

NLNBUIBLP

1180

1180

5.5

0.1424

1990

< 365

NLNBUIBLW

430

430

5.5

0.1424

1990

> 365

NLNBUIBLW

400

400

5.5

0.1424

1990

< 365

NLNBUIBNG

650

650

5.5

0.1424

1990

> 365

NLNBUIBNG

820

820

5.5

0.1424

1990

< 365

NLNBUIBPG

650

650

5.5

0.1424

1990

> 365

NLNBUIBPG

820

820

5.5

0.1424

1990

< 365

NLNBUIBRO

430

430

5.5

0.1424

1990

> 365

NLNBUIBRO

400

400

5.5

0.1424

1990

< 365

NLNBUISAN

570

570

7

0.1424

1990

> 365

NLNBUISAN

570

570

7

0.1424

1990

< 365

NLNBUISGV

490

490

6.5

0.1535

1990

> 365

NLNBUISGV

490

490

6.5

0.1535

1990

< 365

NLNBUISRH

300

300

4.1

0.2439

1990

> 365

NLNBUISRH

300

300

4.1

0.2439

1990

< 365

NLNBULMKN

560

560

5

0.1098

1990

> 365

NLNBULMKN

560

560

5

0.1098

1990

< 365

NLNBUNGGN

1800

1800

7.3

0.1098

1990

> 365

NLNBUNGGN

2200

2200

7.3

0.1098

1990

< 365

NLNBUPGCO

1800

1800

7.3

0.1098

1990

> 365

NLNBUPGCO

2200

2200

7.3

0.1098

1990

< 365

NLNBUPHDO

970

970

7.3

0.1098

1990

> 365

NLNBUPHDO

3470

3470

7.3

0.1098

1990

< 365

NLNBUPHLG

3740



2

0.1098

1990



NLNBUPHNG

1800

1800

7.3

0.1098

1990

> 365

NLNBUPHNG

2200

2200

7.3

0.1098

1990

< 365

NLNBUPHOF

710

710

7.3

0.1098

1990

> 365

NLNBUPHOF

2520

2520

7.3

0.1098

1990

< 365

NLNBUPHPG

1800

1800

7.3

0.1098

1990

> 365

NLNBUPHPG

2200

2200

7.3

0.1098

1990

< 365

NLNBUPHRO

710

710

7.3

0.1098

1990

> 365

NLNBUPHRO

2520

2520

7.3

0.1098

1990

< 365

NLNBUROGN

710

710

7.3

0.1098

1990

> 365

NLNBUROGN

2520

2520

7.3

0.1098

1990

< 365

B-37


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation



Cost per Ton
($/ton reduced)

Capital
/Annual
Cost

CRF

Cost Year
($Year)

Emissions
Cutoff

Default Incremental

Ratio



(tons/yr)

NLNBUSFHT

570

570

7

0.1424

1990

> 365

NLNBUSFHT

570

570

7

0.1424

1990

< 365

NLNBUSHDO

2070

2070

5.5

0.1424

1990

> 365

NLNBUSHDO

1180

1180

5.5

0.1424

1990

< 365

NLNBUSHNG

650

650

5.5

0.1424

1990

> 365

NLNBUSHNG

820

820

5.5

0.1424

1990

< 365

NLNBUSPRF

650

650

5.5

0.1424

1990

> 365

NLNBUSPRF

820

820

5.5

0.1424

1990

< 365

NLNCMNGC03

595







1990



NLNCMNGC03

595







1990



NLNCMNGC03

595







1990



NLNCMNGC03

595







1990



NLNCMNGC03

595







1990



NLNCMNGC03

595







1990



NLNRSNGC03

595







1990



NLNRSNGC03

595







1990



NLNRSNGC03

595







1990



NLNRSNGC03

595







1990



NLNRSNGC03

595







1990



NLNRSNGC03

595







1990



NMKFRCMDY

55

55

3.4

0.1098

1997

> 365

NMKFRCMDY

55

55

3.4

0.1098

1997

< 365

NMKFRCMWT

55

55

3.6

0.1098

1997

> 365

NMKFRCMWT

55

55

3.6

0.1098

1997

< 365

NNGRIBCC

300

300

2

0.0944

1990

> 365

NNGRIBCC

1570

1570

2

0.0944

1990

< 365

NNSCRNAMF

550

550

2.4

0.1424

1990

> 365

NNSCRNAMF

550

550

2.4

0.1424

1990

< 365

NNSCRRBGD

342

342

2

0.1098

1999

> 365

NNSCRRBGD

342

342

2

0.1098

1999

< 365

NNSCRRBIC

342





0.1098

1990

> 365

NNSCRRBIC

342

342

2

0.1098

1990

< 365

NNSCRRBIC2

521



3.4

0.1098

1999



NOTWIFRNG

320

320

2.9

0.1424

1990

> 365

NOTWIFRNG

680

680

2.9

0.1424

1990

< 365

NOTWIIBNG

320

320

2.9

0.1424

1990

> 365

NOTWIIBNG

680

680

2.9

0.1424

1990

< 365

NOTWIIBPG

320

320

2.9

0.1424

1990

> 365

B-38


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation



Cost per Ton
($/ton reduced)

Capital
/Annual
Cost

CRF

Cost Year
($Year)

Emissions
Cutoff

Default Incremental

Ratio



(tons/yr)

NOTWIIBPG

680

680

2.9

0.1424

1990

< 365

NOTWISHNG

320

320

2.9

0.1424

1990

> 365

NOTWISHNG

680

680

2.9

0.1424

1990

< 365

NOTWISPRF

320

320

2.9

0.1424

1990

> 365

NOTWISPRF

680

680

2.9

0.1424

1990

< 365

NOXYFGMCN

4590

4590

2.7

0.1424

1990

> 365

NOXYFGMCN

4590

4590

2.7

0.1424

1990

< 365

NOXYFGMFT

1900

1900

2.7

0.1424

1990

> 365

NOXYFGMFT

1900

1900

2.7

0.1424

1990

< 365

NOXYFGMPD

3900

3900

2.7

0.1424

1990

> 365

NOXYFGMPD

3900

3900

2.7

0.1424

1990

< 365

NR25COL96

1350







1990

> 25

NR25NGC96

770







1990

> 25

NR250IL96

1180







1990

> 25

NR50COL96

1350







1990

> 50

NR50NGC96

770







1990

> 50

NR50OIL96

1180







1990

> 50

NSCRCMDY

3370

3370

4.4

0.1098

1999

> 365

NSCRCMDY

3370

3370

4.4

0.1098

1999

< 365

NSCRFRNG

2366

2366

9.6

0.0944

1999

> 365

NSCRFRNG

2366

2366

10

0.0944

1999

< 365

NSCRFROL

810

940

9.6

0.0944

1990

> 365

NSCRFROL

1480

1910

10

0.0944

1990

< 365

NSCRGMCN

2200

2200

1.8

0.1424

1990

> 365

NSCRGMCN

2200

2200

1.8

0.1424

1990

< 365

NSCRGMFT

710

710

2.2

0.1424

1990

> 365

NSCRGMFT

3370

710

2.2

0.1424

1990

< 365

NSCRGMPD

2530

2530

1.3

0.1424

1990

> 365

NSCRGMPD

2530

2530

1.3

0.1424

1990

< 365

NSCRIBCC

700

700

6.3

0.0944

1990

> 365

NSCRIBCC

820

820

7

0.0944

1990

< 365

NSCRIBCK

1610

1610

6.5

0.0944

1999

> 365

NSCRIBCK

1610

1610

7.1

0.0944

1999

< 365

NSCRIBCOAL

876



7



2003

> 365

NSCRIBCOAL

2141



7



2003

< 365

NSCRIBLP

2958

2958

9.6

0.0944

1999

> 365

NSCRIBLP

2958

2958

10

0.0944

1999

< 365

NSCRIBLW

1568

1568

9.6

0.0944

1999

> 365

B-39


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation



Cost per Ton
($/ton reduced)

Capital
/Annual
Cost

CRF

Cost Year
($Year)

Emissions
Cutoff

Default Incremental

Ratio



(tons/yr)

NSCRIBLW

1568

1568

10

0.0944

1999

< 365

NSCRIBPG

2366

2366

9.6

0.0944

1999

> 365

NSCRIBPG

2366

2366

10

0.0944

1999

< 365

NSCRICBG

986



7



2003

> 365

NSCRICBG

2933



7



2003

< 365

NSCRICBO

760



7



2003

> 365

NSCRICBO

2014



7



2003

< 365

NSCRICGD

920

920

2.2

0.1098

1990

> 365

NSCRICGD

2340

2340

1.8

0.1098

1990

< 365

NSCRICGS

2769



7



1990



NSCRICOL

920

920

2.2

0.1098

1990

> 365

NSCRICOL

2340

2340

1.8

0.1098

1990

< 365

NSCRISAN

5296

5296

5

0.1424

1999

> 365

NSCRISAN

5296

5296

5

0.1424

1999

< 365

NSCRNAMF

812

812

2.5

0.1424

1999

> 365

NSCRNAMF

812

812

2.5

0.1424

1999

< 365

NSCRNGCP

533





0.1098

1990

> 365

NSCRNGCP

2769





0.1098

1990

< 365

NSCRPHDO

6030

6030

7

0.1098

1990

> 365

NSCRPHDO

9230

9230

6.4

0.1098

1990

< 365

NSCRPHLP

5350

6030

7

0.1098

1990

> 365

NSCRPHLP

12040

9230

6.4

0.1098

1990

< 365

NSCRPHNG

8160

8160

6.3

0.1098

1990

> 365

NSCRPHNG

12040

12040

6.7

0.1098

1990

< 365

NSCRPHOF

3590

3590

6.9

0.1098

1990

> 365

NSCRPHOF

5350

5350

6.5

0.1098

1990

< 365

NSCRPHPG

8160

8160

6.3

0.1098

1990

> 365

NSCRPHPG

12040

12040

6.7

0.1098

1990

< 365

NSCRPHRO

3590

3590

6.9

0.1098

1990

> 365

NSCRPHRO

5350

5350

6.5

0.1098

1990

< 365

NSCRRICOIL

1066



7



1993



NSCRSHDO

1510

1750

9.6

0.0944

1990

> 365

NSCRSHDO

2780

3570

10

0.0944

1990

< 365

NSCRSHNG

1210

1410

9.6

0.0944

1990

> 365

NSCRSHNG

2860

2860

10

0.0944

1990

< 365

NSCRSPRF

2366

2366

9.6

0.0944

1999

> 365

NSCRSPRF

2366

2366

10

0.0944

1999

< 365

NSCRWGTJF

1010

2280

2.3

0.1098

1990

> 365

B-40


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation



Cost per Ton
($/ton reduced)

Capital
/Annual
Cost

CRF

Cost Year
($Year)

Emissions
Cutoff

Default Incremental

Ratio



(tons/yr)

NSCRWGTJF

2300

7850

2.8

0.1098

1990

< 365

NSNCNCMDY

850

850

3.3

0.1098

1990

> 365

NSNCNCMDY

850

850

3.3

0.1098

1990

< 365

NSNCRBCCK

770

770

1.6

0.1098

1999

> 365

NSNCRBCCK

770

770

1.6

0.1098

1999

< 365

NSNCRBCGN

940

940

1.2

0.0944

1990

> 365

NSNCRBCGN

1260

1260

1.2

0.0944

1990

< 365

NSNCRBCLK

770

770

1.6

0.1098

1990

> 365

NSNCRBCLK

770

770

1.6

0.1098

1990

< 365

NSNCRCIIN

1130

1130

4.1

0.0944

1990

> 365

NSNCRCIIN

1130

1130

4.1

0.0944

1990

< 365

NSNCRCMDY

770

770

2.1

0.1098

1990

> 365

NSNCRCMDY

770

770

2.1

0.1098

1990

< 365

NSNCRCMOU

1640

1640

2.7

0.1424

1990

> 365

NSNCRCMOU

1640

1640

2.7

0.1424

1990

< 365

NSNCRFRNG

1570

840

8.2

0.0944

1990

> 365

NSNCRFRNG

3870

2900

9.4

0.0944

1990

< 365

NSNCRFROL

1050

560

8.2

0.0944

1990

> 365

NSNCRFROL

2580

1940

9.4

0.0944

1990

< 365

NSNCRGMCN

1770

1770

2.4

0.1424

1990

> 365

NSNCRGMCN

1770

1770

2.4

0.1424

1990

< 365

NSNCRGMFT

740

740

2.4

0.1424

1990

> 365

NSNCRGMFT

740

740

2.4

0.1424

1990

< 365

NSNCRGMPD

1640

1640

2.4

0.1424

1990

> 365

NSNCRGMPD

1640

1640

2.4

0.1424

1990

< 365

NSNCRIBC

1285



5.8



2003

> 365

NSNCRIBC

2073



5.8



2003

< 365

NSNCRIBCC

700

700

6.4

0.0944

1990

> 365

NSNCRIBCC

840

840

7.5

0.0944

1990

< 365

NSNCRIBCK

840

260

6.6

0.0944

1990

> 365

NSNCRIBCK

1040

400

7.7

0.0944

1990

< 365

NSNCRIBGA

930

930

6.8

0.0944

1990

> 365

NSNCRIBGA

1440

1440

6.3

0.0944

1990

< 365

NSNCRIBLP

1890

1010

8.2

0.0944

1990

> 365

NSNCRIBLP

4640

3470

9.4

0.0944

1990

< 365

NSNCRIBLW

1050

560

8.2

0.0944

1990

> 365

NSNCRIBLW

2580

1940

9.4

0.0944

1990

< 365

NSNCRIBMS

1250

1250

6.2

0.0944

1990

> 365

B-41


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation



Cost per Ton
($/ton reduced)

Capital
/Annual
Cost

CRF

Cost Year
($Year)

Emissions
Cutoff

Default Incremental

Ratio



(tons/yr)

NSNCRIBMS

1690

1690

6.8

0.0944

1990

< 365

NSNCRICBG

280



5.2



2003

> 365

NSNCRICBG

1052



5.2



2003

< 365

NSNCRICBO

1485



5.5



2003

> 365

NSNCRICBO

2367



5.5



2003

< 365

NSNCRICGS

521



4.4

0.1098

1990



NSNCRIDIN

1130

1130

4.1

0.0944

1990

> 365

NSNCRIDIN

1130

1130

4.1

0.0944

1990

< 365

NSNCRINGI4

422







1999



NSNCRISAN

1640

1640

2.7

0.1424

1990

> 365

NSNCRISAN

1640

1640

2.7

0.1424

1990

< 365

NSNCRMWCB

1130

1130

4.1

0.0944

1990

> 365

NSNCRMWCB

1130

1130

4.1

0.0944

1990

< 365

NSNCRMWIN

4510

4510

4.1

0.0944

1990

> 365

NSNCRMWIN

4510

4510

4.1

0.0944

1990

< 365

NSNCRPHDO

1720

1720

5.2

0.1098

1990

> 365

NSNCRPHDO

3180

3180

6.2

0.1098

1990

< 365

NSNCRPHLP

1720

1720

5.2

0.1098

1990

> 365

NSNCRPHLP

3180

3180

6.2

0.1098

1990

< 365

NSNCRPHNG

1950

1950

5.7

0.1098

1990

> 365

NSNCRPHNG

2850

2850

6.4

0.1098

1990

< 365

NSNCRPHOF

1100

1100

4.8

0.1098

1990

> 365

NSNCRPHOF

1930

1930

6

0.1098

1990

< 365

NSNCRPHPG

1950

1950

5.7

0.1098

1990

> 365

NSNCRPHPG

2850

2850

6.4

0.1098

1990

< 365

NSNCRPHRO

1100

1100

4.8

0.1098

1990

> 365

NSNCRPHRO

1930

1930

6

0.1098

1990

< 365

NSNCRSHDO

1890

1010

8.2

0.0944

1990

> 365

NSNCRSHDO

4640

3470

9.4

0.0944

1990

< 365

NSNCRSHNG

1570

840

8.2

0.0944

1990

> 365

NSNCRSHNG

3870

2900

9.4

0.0944

1990

< 365

NSNCRSPRF

1570

840

8.2

0.0944

1990

> 365

NSNCRSPRF

3870

2900

9.4

0.0944

1990

< 365

NSNCRSWIN

1130

1130

4.1

0.0944

1990

> 365

NSNCRSWIN

1130

1130

4.1

0.0944

1990

< 365

NTHRDADMF

420

420

2.3

0.1424

1990

> 365

NTHRDADMF

420

420

2.3

0.1424

1990

< 365

NULNBPHDO

610

610

7.3

0.1098

1990

> 365

B-42


-------
Control Strategy Tool (CoST) Cost Equations

cost cm
Abbreviation



Cost per Ton
($/ton reduced)

Capital
/Annual
Cost

CRF

Cost Year
($Year)

Emissions
Cutoff

Default Incremental

Ratio



(tons/yr)

NULNBPHDO

2140

2140

7.3

0.1098

1990

< 365

NULNBPHLP

610

610

7.3

0.1098

1990

> 365

NULNBPHLP

2140

2140

7.3

0.1098

1990

< 365

NULNBPHNG

1200

1200

7.3

0.1098

1990

> 365

NULNBPHNG

1500

1500

7.3

0.1098

1990

< 365

NULNBPHOF

360

360

7.3

0.1098

1990

> 365

NULNBPHOF

1290

1290

7.3

0.1098

1990

< 365

NULNBPHPG

1200

1200

7.3

0.1098

1990

> 365

NULNBPHPG

1500

1500

7.3

0.1098

1990

< 365

NULNBPHRO

360

360

7.3

0.1098

1990

> 365

NULNBPHRO

1290

1290

7.3

0.1098

1990

< 365

NWHCMNGC99

0







1990



NWHRSNGC99

0







1990



NWIGTAGT

44000



2.8



2005



NWLCMNGC99

1230







1990



NWTINGTJF

650

650

1.6

0.1098

1990

> 365

NWTINGTJF

1290

1290

2.9

0.1098

1990

< 365

B-43


-------