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
V
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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
-------
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
-------
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
-------
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
-------
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
-------
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
-------
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 $/MW
Variable O&M = Variable O&M Cost Multiplier x Capacity x Capacity Factor x 8,760
Capital Recovery Factor =
Interest Rate x (1 + Interest Rate^EctulPment Llfe
(1 + Interest Rate)EiuivmentLife - 1
28
-------
Control Strategy Tool (CoST) Cost Equations
Where:
Variable O&M Cost Multiplier ($/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
-------
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
-------
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
-------
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
-------
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
-------
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
-------
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
-------
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
-------
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
-------
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
-------
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
-------
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
-------
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
-------
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
-------
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
-------
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
-------
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
-------
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
-------
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
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