1

GUIDE TO IPM Output FILES

EPA Base Case 

v.5.13

The following information is meant to provide users with a general explanation of the 

different IPM output files that are made web ready and posted to EPA’s website. It refers to 

the EPA Base Case v.5.13 that was designed and developed for use in analyzing policy 

scenarios starting in 2016. It is meant to help users identify and interpret the data available in 

the model input and output files. The EPA Base Case v.5.13 documentation (available at

http://www.epa.gov/airmarkets/progsregs/epa-ipm/BaseCasev513.html provides more 

comprehensive details regarding the assumptions and methodology used in the model.

Below is a brief overview of the non-unit level IPM inputs and outputs that are made

publically available through EPA’s website. Because the System Summary Report is one of 

the more frequently referenced documents that summarizes many IPM key outputs, it is 

described in further detail in the remainder of this guide.

Once EPA Base Case v.5.13 files are downloaded and decompressed from EPA’s website, the 

unzipped files will contain two folders: “Input and Output Files” & “Parsed Files”. 

Additionally, it will have an Excel spreadsheet that includes “System Summary Report” in the 

title. The “Input and Output Files” folder will have six files within it: A DAT Replacement file,

RPE Replacement file, RPT Replacement files, EIA Style Gas Report, State Emission File, and 

an Overview file.

Input and Output Files

DAT file (Model Inputs): This file will have “dat file” in the file name, e.g., “Base Case dat

file.xlsx.” This file replaces “.dat” file that was output by earlier versions of IPM and is 

easier to navigate. It contains the key input set-up data used to define the model run, 

including the definitions and specifications for run years, model regions, model plants, 

financial parameters, available fuels, and power system transmission and operating 

parameters. The “Index” worksheet provides a list of all other worksheets and data 

available in the file, and the “RunUniverse” worksheets includes a table of region names 

and IDs. 

RPE file (Model Plant Outputs): This file will have “rpe file” in the file name, e.g., “Base Case 

rpe file.xlsx.” This file replaces “.rpe” file that was output by earlier versions of IPM and is 

easier to navigate. For each model plant, this file shows the projections of fuel consumption, 

emissions, capacity, costs (capital, fixed operations and maintenance, and variable 

operations and maintenance), and generation. 

RPT files (Detailed Model Operational Outputs): This is a zip file with “rpt files” in the file 

name, e.g., “Base Case rpt files.zip.” It contains multiple excel workbooks that replace the 

“.rpt” file that was output by earlier versions of IPM and is easier to navigate. These files 

contain a variety of model outputs, including: regional summaries; costs, fuel supply, 
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transportation, and use; electricity transmission and constraints; new and retrofit capacity; 

environmental constraints; and energy price. 

EIA Style Gas Report file: This file will have “EIA Style Gas Report” in the file name, e.g., 

“Base Case EIA Style Gas Report.xlsx.” This file shows outputs related to natural gas 

production and use in format matching natural gas tables developed by the Energy 

Information Administration (EIA). 

State Emissions file: This file will have “State Emissions” in the file name, e.g., “Base Case 

State Emissions.xlsx.” This file shows EGU emissions at the state level for each run year, 

derived from the IPM regional level results. . There are two tabs, one showing emissions 

from all EGUs, the other showing emissions only from fossil units greater than 25 MW. 

Overview file (Regional Summary of Model Operational Outputs): This file will have 

“Overview” in the file name, e.g., “Base Case Overview File.xlsx.” It contains model 

operational outputs by run year at the regional level, including capacity, generation, costs, 

retrofits, and retirements. It is typically easier for users to refer to either the System 

Summary Report or the Regional Summary File/ 

System Summary Report

System Summary Report: The System Summary Report is available as a spreadsheet, e.g.,

“Base Case SSR. xlsx.” It contains system-wide power sector results for the lower continental 

U.S. for each run year. It reports forecasted generation, capacity, capacity additions, capacity 

factors, production costs, emissions, fuel consumption & cost, and allowance prices by model 

run year. Disaggregation of system-wide data to plant type data is provided for generation 

and capacity fields. The plant types are categorized based on fuel used (e.g., coal, oil/gas, 

nuclear, hydro), combustion technology (e.g., turbine, combined cycle gas), control 

technology (e.g., scrubber, post-combustion NOx control), and retrofit structure (e.g., coal 

plant with existing SNCR retrofit with ACI). In addition to providing the above outputs 

forecasted for each model run year, it also gives information on the various regulatory and 

legal requirements that were inputted into the model as constraints. Below is a more 

detailed explanation of each worksheet in the System Summary Report.

The regional level equivalent of the System Summary Report Tables 1-16 is available in the 

“Regional Summary.xlsx” file that is included in the RPT replacement files. 
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Description of Worksheets and Data within the System Summary Report File

System Summary Report: When the Excel File is opened, it will contain six worksheets

1. “Summary” worksheet

2. “All Constraints” worksheet

3. “Fuel Report” worksheet

4. “Tables 1-16_US” worksheet

5. “Coal Pivot Tables” worksheet

6. “Final Wholesale Price” worksheet

Summary Worksheet: The summary worksheet in the system summary file highlights some of the key data points from the 

IPM output, and is intended to be an ideal starting point for assessing fundamental environmental and operational 

projections for the power sector in any given IPM run. For first time users, it is one of the more user friendly documents 

from which to view output data. See Appendix 1-1 for description of fields included in the “Summary” worksheet.

All Constraints: The “All Constraints” worksheet in the System Summary Report provides information on various legal and 

policy requirements and how they are captured in the model. Each constraint typically involves a “standard” that is 

imposed in the form of an emission limit, emission rate limit, or generation limit. The constraint can be applied at the 

unit, plant, system, state, regional or national level. The constraints also include a time dimension and may vary between 

model run years. Each constraint in the worksheet provides information on the impact of the “standard” on the effected 

unit(s). These impacts are modeling outputs given in the form of emissions, emission rates, and/or generation that occur 

under the given “standard” in a particular model run year. For constraints that represent cap-and-trade programs with 

banking, the run output indicates additions and withdraws from the allowance bank and allowance price by year. There 

are nearly 1000 constraints in the EPA Base Case v.5.13 Base Case, and the total number may extend beyond a thousand 

for the modeling of certain policy scenarios. An example of a constraint would be “Constraint Name: #1 –SO2 CAIR 

Annual Constraint” which captures the emission limits imposed on coal units by the Clean Air Interstate Rule. The 

constraint provides a total “standard” that reflects the CAIR allowances available to units in a given model run year. 

Below is a table that illustrates the typical format of a constraint in the “All Constraints” worksheet, along with an 

explanation of each row. Appendix table 2-1 provides a comprehensive list of legal and policy requirements that are 

reflected in the model through the various constraints.
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Description of Constraint Level Data Fields

Row Title Description 

Constraint Name: #1 - SO2 CAIR Annual 

Constraint Provides information on legal or policy constraint being modeled.

Constraint Type: Rate Constraint in Mtons

Provides information on constraint type that is being modeled (e.g., generation, 

emission, rate, etc.). "Mtons"= thousand tons (emission limit); "GWh" = gigawatt 

hours (generation limit); "lbs/Mmbtu" = pounds per million btus (rate limit).

Seasons Included

Shows model run year for the output and indicates if the constraint was applied to 

summer generation, winter generation, or both. Winter months include October 

through April. Summer months include May through September.

Standard This row provides the value of the constraint being inputted into the model. It is 

modeling input and one of key interest in the “All Constraints” worksheet.

Emissions at Affected Plants

Model output of collective emission at plants affected by "standard" as well as 

summary of allowance trading activity supporting the emission level.

Allowances Purchased SO2

Allowances Sold SO2

Allowances Banked

Allowances Withdrawn (1:1)

Allowances Withdrawn (n:1)

Net Emissions Allowance Position

Fuel Consumed Tbtu=trillion btu. Model output of fuel consumption for affected units.

Rate Model output of emission rate for effected units. "lbs/Mmbtu" = pounds per 

affected unit.

Generation Electricity generated by units subject to the "standard" limit. TWh = Terawatt 

hours generated.

Qualifying Generation

Rate Rate for affected units. lb/MWh = pound per Megawatt hour.

Constraint Shadow Price

If the "standard" is an emission limit (i.e., cap) in a trading program, the constraint 

shadow price will reflect the $ per ton value of allowances in that trading program. 

Commonly called the “allowance price”.
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Fuel Report: The “Fuel Report” worksheet provides consumption and cost data for major power sector fuel sources for 

each model run year. These fuels include coal, nuclear, natural gas, biomass, pet.coke (petroleum coke), natural gas, 

biomass, waste coal, and oil. For each fuel type the total consumption is given in TBtus (trillion Btus). Cost is provided in 

both MMUS$ (million US dollar units) and US$/MMBtu (U.S. dollar per million Btus).

Tables 1-16: The “Tables 1-16” worksheet in the System Summary Report provides information on controls, generation,

capacity, and cost. The information in these tables is often the disaggregated value of the totals reported in the “Summary” 

worksheet. A user interested in better understanding the details behind the totals given in the “Summary” worksheet may 

wish to consult “Tables 1-16”. For example, the “Summary” worksheet provides the total amount of generation from coal in 

a given model run year. However, the “Tables 1-16” worksheet goes one step further and provides data on the portion of 

that generation total coming from coal plants with no pollution control and the portion coming from plants with specific 

pollution control configurations. In particular, tables 10 through14 provide generation and capacity data at the model plant 

type level. Tables 1–9 provide generation supply and demand data at the U.S. region wide level. The table below describes 

the data output reported in each table, and Appendix 3-1 and 3-2 provides more information on the acronyms and 

nomenclature used in the data fields.

Description Tables in “Tables 1-16” Worksheet

Table # Title Description

1 Reserve Margin Capacity Winter

(MW)

Shows total electric generating capacity available to the U.S. region during

winter period. Available supply of electricity in megawatts (MW).

2 Peak Load Winter (MW) Shows total electricity demand during winter period by the U.S. region. Capacity

reported in megawatts (MW).

3 Reserve Margin Winter (%) Shows excess winter capacity supply as percentage of demand using total values

reported from Tables 1 & 2. (supply - demand)/demand.

1 Reserve Margin Capacity summer

(MW)

Shows total electric generating capacity available to U.S. region during

summer period. Available supply of electricity in megawatts(MW).

2 Peak Load summer (MW) Shows total electricity demand during summer period by the U.S. region. Capacity

reported in megawatts (MW).

3

Reserve Margin summer (%) Shows excess summer capacity as percentage of demand using total values reported

from Tables 1 & 2.
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1 Reserve Margin Capacity annual (MW) Shows total electric generating capacity available to U.S. region annually. 

Available supply of electricity in megawatts (MW).

2 Peak Load annual (MW) Shows total electricity demand annually by the U.S. region. Capacity reported in 

megawatts (MW).

3 Reserve Margin annual (%) Shows excess annual capacity as percentage of demand using total values reported

from Tables 1 & 2.

4 Generation (GWh) Gigawatt hours(GWh) of annual electricity that is produced domestically,

imported, exported, and lost during pumping and storage.

5 Total Supply for Demand (GWh) Gigawatt hours(GWh) of annual electricity generation supplied to the U.S. region.

Summation of values in Table 4

6 Projected Demand (GWh) Gigawatt hours(GWh) of annual projected demand and projected net demand.

7 Dumped Energy Typically not referenced.

8 Total Generation Gigawatt hours(GWh) of annual electricity that is produced domestically,

imported, exported, and lost during pumping and storage.

9 Total Sales (GWh) Gigawatt hours(GWh) of annual electricity supply determined by subtracting

projected transmission & demand losses from total supply.

10 Capacity by Capacity Reporting Type

Cumulative capacity (MW) of model plant types for each model run year. The

model run plants are categorized by the unit’s fuel, configuration, and online status

(e.g., new, existing, retiring). Each control configuration combination is modeled as

a separate plant type. The total capacity, retrofit capacity, new unit capacity, and

retiring unit capacity values given in the summary table are disaggregated into

model plant types in this table. Key difference between table 10 & 11 is that 10 is

cumulative and 11 is incremental. Therefore, table 10 will show model plant

capacity by a given year, and table 11 will show model plant capacity added during

that run year.

11 Capacity Additions and Changes

Incremental capacity (MW) of model plant types for each model run year. The

model run plants are categorized by the unit’s fuel, configuration, and online status

(e.g., new, existing, retiring). Each control configuration combination is modeled as

a separate plant type. The total capacity, retrofit capacity, new unit capacity, and

retiring unit capacity values given in the summary table are disaggregated into

model plant types in this table.
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12 Generation by Capacity Reporting 

Type (GWh)

Cumulative generation (GWh) of model plant types for each model run year. The 

model run plants are categorized by the unit’s fuel, configuration, and online status

(e.g., new, existing, retiring). Each control configuration combination is modeled as

a separate plant type. The total generation by each plant type given in the

summary table is disaggregated into model plant type generation in this table.

12a

Generation by Capacity Reporting 

Type (GWh)

Total gigawatt hours (GWh) of generation in each model run year by fuel type.

Aggregation of the model plants pertaining to each fuel in table 12.

13 Generation by Capacity Reporting 

Type (Tbtu)

Cumulative generation measured in Trillion btus (Tbtu) of model plant types for

each model run year. The data correspondsto generation values given in Table 12,

but is expressed in TBtus to provide the heat content of the power generated.

Conversion factor of approximately 3,412 Btu/KWh is used.

14 Capacity factor by Capacity Reporting 

Type (%)

Capacity factor for each model plant type. Capacity factor is the actual generation

expressed as a percentage of maximum generation possible if the plant was

operated every hour of the year. Therefore, it is the generation / (capacity*8760).

Generally, the model does not allow for 100% capacity factors because of

maintenance, planned outage, and forced outage times. Intermittent generation

sources (i.e., wind) also have their capacity factor limited by the availability of their 

fuel source.

15 Total Annual Production Cost

Provides total production cost in million U.S. dollar units (MMUS$) for each model

run year. The production costs are disaggregated into variable operating and

maintenance (variable O&M), fixed O&M, fuel, capital, and CO2 transportation

and storage cost.

16 Emissions

Providestotal annual U.S. emissions for each model run year for several hazardous,

criteria, and green house gas pollutants. Emission totals are expressed in 1000 tons

(Mtons); 1,000,000 tons (MMtons), or regular tons. All tons are short tons (2000

lbs/ton) unless otherwise noted.

Coal Pivot Tables: The “Coal Pivot Tables” worksheet in the System Summary Report provides information on coal prices 

and total coal consumption for each run year by coal region. Data is reported in both MMBtu and tons. 

Final Wholesale Price: The “Final Wholesale Electricity Price” worksheet in the System Summary Report provides the 

wholesale electricity price for each region and model run year. 
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APPENDICES

Appendix 1-1: Description of Data Fields in “Summary” Worksheet

Row 

Number Row Title

Description of Field

1

2 EPA IPM Run Results

3 All costs and prices are in 2011-year dollars Provides year to which all cost and prices within the summary report are indexed.

4 NATIONWIDE EMISSIONS

Provides nationwide total emissions from EGUs for given run years in short tons 

(2000 lbs/ton) unless otherwise noted.

5 SO2 (million tons)

6 NOx (million tons)

7 CO2 (million metric tons)

8 Hg (tons)

9 HCL (Mtons)

10

11 TOTAL COSTS Provides the total cost of electricity generation to meet demand in given year under 

the modeled operational, regulatory, and policy constraints. Values are given in 

billion dollar units and indexed to 2007 prices. 12 Total Costs (billion $)

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14 PRICES Gives the prices for various fuel and emission commodities relevant to the power 

sector.
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15 National Wholesale Electricity Price 

(mills/kWh)

For wholesale electricity prices in “mills/kWh”. 1 mill = 1/10 of a cent. Therefore, 10 

mills/kWh is equivalent to $.01/kWh.

16 Natural Gas Prices (2011 $/MMBtu) "MMbtu" = million btus.

17 Henry Hub

Price at Henry Hub. Henry Hub is a gas pipeline in Louisiana that serves as a 

generally accepted reference point for U.S. natural gas trading data due to its central 

location giving shippers access to pipelines in the southeast, midwest, and northeast 

regions.

18 Delivered Delivered price of gas. Reflects seasonal and transportation cost adders.

19 Minemouth Coal Prices (2011 $/MMBtu)

Provides endogenously determined minemouth coal prices. "MMbtu" = million btus. 

Figure 9-1 of the Documentation for EPA Base Case v.5.13 for a map of coal regions. 

National price is weighted average of regional coal prices.

20 Appalachia

21 Imports

22 Interior

23 Waste Coal

24 West

25 National

26

27 EMISSION ALLOWANCE PRICES ($/Ton)

28 SO2 Annual (CAIR) SO2 Annual (CAIR) Provides emission allowance price for pollutants under that 

program. 

29 NOx Annual (CAIR) NOx Annual (CAIR) Provides emission allowance price for pollutants under that 

program.

30 NOx Ozone Season (CAIR) NOx Ozone Season (CAIR Provides emission allowance price for pollutants under that 

program.
10

31 CO2 ($/metric ton) CO2 ($/metric ton)

32

33 EMISSION CONSTRAINTS (Mtons) Mtons = Thousand Tons

34 SO2 Annual (CAIR) SO2 Region 1 (CAIR) Provides total emissions for electric generating units (EGUs) 

affected by the referenced policy. 

35 NOx Annual (CAIR) NOx Annual (CAIR) Provides total emissions for electric generating units (EGUs) 

affected by the referenced policy.

36 NOx Ozone Season (CAIR) NOx Ozone Season (CAIR) Provides total emissions for electric generating units 

(EGUs) affected by the referenced policy.

37 CO2 (metric ton) CO2 (metric ton) Provides total emissions for electric generating units (EGUs) 

affected by the referenced policy.

38

39 TOTAL CAPACITY (Cumulative GW)

Provides the cumulative gigawatts of generating capacity by plant type forecasted to 

be online for a given run year. It reflects ((existing units + new units) – retiring units) 

for that generation type. The existing value is obtained from the previous model run 

year. Total is the aggregate electricity generating capacity available. Abbreviations: 

PC = pulverized coal; IGCC = integrated gasification combined cycle; IGCC-CCS = 

integrated gasification combined cycle with carbon capture and storage; CC = 

combined cycle; CT = combustion turbine.

40 Hydro

41 Non-Hydro Renewables

42 Biomass

43 Other

44 Wind

45 Coal

46 PC

47 IGCC

48 IGCC - CCS
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49 New Future Technology

50 Nuclear

51 Natural Gas

52 CC

53 CC - CCS

54 CT

55 Oil/Gas Steam

56 Other

57 Grand Total

58

59 NEW CAPACITY (Cumulative GW)

Provides the cumulative gigawatts of new capacity by plant type expected to come 

online by a given run year (. New capacity is determined endogenously and 

constitutes units that are not currently listed in the National Electric Energy Data 

Source (NEEDs). Abbreviations:

 PC = pulverized coal; 

 IGCC = integrated gasification combined cycle;

 IGCC-CCS = integrated gasification combined cycle with carbon capture and 

storage; 

 CC = combined cycle;

 CT = combustion turbine.

60 Non-Hydro Renewables

61 Biomass

62 Other

63 Wind

64 Coal

65 PC

66 IGCC
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67 IGCC - CCS

68 New Future Technology

69 Nuclear

70 Natural Gas

71 CC

72 CC - CCS

73 CT

74 Other

75 Grand Total

76

77 RETIREMENTS (GW)

Provides the cumulative gigawatts of retirements by plant type that occur by the 

given run year. Abbreviations: 

 PC = pulverized coal;

 IGCC = integrated gasification combined cycle; 

 IGCC-CCS = integrated gasification combined cycle with carbon capture and 

storage; 

 CC = combined cycle; 

 CT = combustion turbine; 

 O/G = oil/gas steam. In some cases, retirements may also reflect retirements that 

are required by enforcement actions (e.g., consent decree).

78 CC Retirements

79 Coal Retirements

80 CT Retirements

81 Nuclear Retirements

82 O/G Retirements

83 IGCC Retirements

84 Non-Fossil Retirements
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85 Grand Total

86

87 GENERATION MIX (thousand GWh)

Provides the annual generation projected for a given model run year by a particular 

plant type. Generation data is given in units of 1000 gigawatt hours. The total value 

reflects total electricity demand from the power grid. Abbreviations: 

 PC = pulverized coal; 

 IGCC = integrated gasification combined cycle; 

 IGCC-CCS = integrated gasification combined cycle with carbon capture and 

storage; 

 CC = combined cycle; 

 CT = combustion turbine; 

 O/G = oil/gas steam.

88 Hydro

89 Non-Hydro Renewables

90 Biomass

91 Other

92 Wind

93 Biomass Co-firing

94 Coal

95 PC

96 IGCC

97 IGCC - CCS

98 New Future Technology

99 Nuclear

100 Natural Gas

101 CC

102 CC - CCS
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103 CT

104 Oil/Gas Steam

105 Other

106 Grand Total

107

108 TOTAL CONTROLS (Cumulative GW) Provides total gigawatts of a particular type of control technology at coal-fired units.

109 FGD

Provides total gigawatt of units with Flue Gas Desulfurization technology (FGD) for a 

given run year. FGD is used for removing SO2 from coal fired power plants. Also 

referred to as a "scrubber". The total given is a summation of existing scrubbers, 

retrofit scrubbers, and all new pulverized coal capacity which is assumed to have 

scrubber technology installed.

110 Existing Scrubber Provides total gigawatt of coal steam capacity in NEEDS with a FGD. These FGDs are

exogenous to the model and in place prior to retrofits and new units that are added 

in the model. Wet FGD refers to limestone forced oxidation (LSFO) and Dry FGD 

refers to Lime Spray Dryer (LSD) technology.

111 Existing Wet Scrubber

112 Existing Dry Scrubber

113 Non-Disapatchable Scrubber

Provides gigawatts of FGD retrofits for a given model run year. These are model 

projections and therefore endogenous to the model.

114 Retrofit Wet Scrubber

115 Retrofit Dry Scrubber

116 New Scrubber

Refers to cumulative GW of new FGDs online by a given model run year. 

Corresponds to the capacity of cumulative new pulverized coal capacity expected for 

a given model run year. The model assumes all new pulverized coal has FGD 

controls.

117 New Wet Scrubber

118 New Dry Scrubber
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119 SCR

Provides total gigawatts of Selective Catalytic Reduction (SCR) online by a given 

model run year (Existing + retrofits + new units). SCRs are primarily used as a postcombustion technology for reducing NOX from emissions at power plants.

120 Existing SCR

Provides total gigawatt of coal steam capacity in NEEDS with a SCR. These SCRs are 

exogenous to the model and in place prior to retrofits and new units that are added 

in the model

121 Retrofit SCR Refers to cumulative gigawatts of capacity retrofitted with SCR by a given model run 

year. These are model projections and therefore endogenous to the model.

122 New SCR

Refers to the cumulative gigawatts of new SCRs (non-retrofits) that have come 

online by a given model run year. Corresponds to capacity of new coal units that is 

forecasted, as all new coal is assumed to have SCR.

123 SNCR

Provides total cumulative gigawatts of Selective Non-Catalytic Reduction (SNCR) 

technology that is online by a given model run year. Summation of existing, retrofit, 

and new SNCR. SNCR is post-combustion technology for reducing NOX from power 

plant emissions.

124 Existing SNCR

Provides total gigawatt of coal steam capacity in NEEDS with a SNCR. These SNCRs 

are exogenous to the model and in place prior to retrofits and new units that are 

added in the model

125 Retrofit SNCR Refers to cumulative gigawatts of capacity that is retrofitted with SNCR by a given 

run year. These are model projections and therefore endogenous to the model.

126 ACI

Provides cumulative GW of generating capacity that has Activated Carbon Injection 

(ACI). Is a summation of existing, retrofits, and new ACI. ACI is technology for 

reducing Mercury (Hg) emissions at power plants.

127 Existing ACI

Provides total gigawatt of coal steam capacity in NEEDS with a ACI. These ACIs are 

exogenous to the model and in place prior to retrofits and new units that are added 

in the model

128 Retrofit ACI

Provides cumulative gigawatts of generating capacity that is retrofitted with ACI by 

the given model run year. These are model projections, and therefore endogenous 

to the model.
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129 New ACI Provides cumulative gigawatts of new units that are coming online with ACI 

technology.

130 CCS

Provides cumulative gigawatts of generating capacity that has Carbon Capture and 

Storage Technology installed by a given model run year. Is a summation of existing, 

retrofit, and new CCS.

131 Hardwired CCS Provides total gigawatts of existing CCS that is online prior to 2012 and included in 

the modeling input in the NEEDs inventory. This is exogenous to the model.

132 Retrofit CCS

Provides total cumulative gigawatts of capacity that is retrofitted with CCS by the 

given model run year. These are model projections and therefore endogenous to the 

model..

133 New CCS Provides cumulative gigawatts of new units that are coming online with CCS by the 

given model run year.

134 FF

Provides cumulative gigawatts of generating capacity that has Fabric Filter

technology installed by a given model run year. Is a summation of existing and 

retrofit Fabric Filters.

135 Existing FF

Provides total gigawatt of capacity in NEEDS with a Fabric Filter. These fabric Filters

are exogenous to the model and in place prior to retrofits and new units that are 

added in the model

136 Retrofit FF

Provides total cumulative gigawatts of capacity that is retrofitted with Fabric Filters 

by the given model run year. These are model projections and therefore 

endogenous to the model.

137 DSI

Provides cumulative gigawatts of generating capacity that has Dry Sorbent Injection 

technology installed by a given model run year. Is a summation of existing, retrofit, 

and new DSI.

138 Existing DSI

Provides total gigawatt of coal steam capacity in NEEDS with a DSI. These DSIs are 

exogenous to the model and in place prior to retrofits and new units that are added 

in the model

139 Retrofit DSI

Provides total cumulative gigawatts of capacity that is retrofitted with DSI by the 

given model run year. These are model projections and therefore endogenous to the 

model.

140 C2G Provides the cumulative gigawatts of capacity that is converted from burning coal to 

natural gas by the given model run year.
17

141 HRI Provides the cumulative gigawatts of capacity that has heat rate improvements by 

the given model run year.

142

143 RETROFITS (Cumulative GW)

Provides total cumulative gigawatts of capacity that is retrofitted with a given 

technology post 2015 and by given model run year. The capital costs of the retrofits 

are included in the model and they are installed at the power plant post 2015.

144 FGD Cumulative gigawatts of Flue Gas Desulfurization.

145 SCR Cumulative gigawatts of Selective Catalytic Reduction retrofits.

146 SNCR Cumulative gigawatts of Selective Non-Catalytic Reduction retrofits

147 ACI Cumulative gigawatts of Activated Carbon Injection retrofits.

148 CCS Cumulative gigawatts of Carbon Capture & Storage retrofits.

149 FF Cumulative gigawatts of Fabric Filter retrofits.

150 DSI Cumulative gigawatts of Dry Sorbent Injection retrofits

151 C2G Cumulative gigawatts of coal-to-gas retrofits

152 HRI Cumulative gigawatts of heat rate improvement retrofits

153

154 TOTAL CONTROLS IN NEEDS

155 FGD

Reflects cumulative gigatwatts of capacity that has control installed in NEEDS. Value 

is reflective of controls at all coal steam units

156 SCR

157 SNCR

158 ACI
18

159

160 FUEL SUPPLY AND CONSUMPTION Provides Coal and Gas supply and consumption for given model run years.

161 Coal Use by Region (million tons) Provides total coal use in million tons by power and non-power sector for given 

model run year.

162 Power Sector Provides total coal use in million tons by power sector for given model run year.

163 Appalachia Provides total coal use for power sector that comes from Appalachia coal region.

164 Imports Provides total coal use for power sector that comes from Imports.

165 Interior Provides total coal use for power sector that comes from Interior Region.

166 Waste Coal Provides total coal use for power sector that comes from Waste Coal.

167 West Provides total coal use for power sector that comes from the West Region.

168 Non-Power Sector Provides total coal use in million tons for the non-power sector.

169 Appalachia Provides total coal use for non-power sector that comes for Appalachia region.

170 Interior Provides total coal use for non-power sector that comes from Interior Region.

171 West Provides total coal use for non-power sector that comes from West Region.

172 Power Sector Coal Use by Rank (TBtu) Provides total coal supply to power sector in trillion Btus (Tbtu).

173 Bituminous Provides total bituminous coal use for power sector in trillion Btus (Tbtu).

174 Subbituminous Provides total subbituminous coal use for power sector in trillion Btus (Tbtu).

175 Lignite Provides total lignite coal use for power sector in trillion Btus (Tbtu).

176

177 Natural Gas Use (Trillion cubic feet) Total natural gas use by power and non-power sectors in trillion cubic feet (Tcf).
19

Appendix 2-1: Summary of legal and regulatory requirements considered in the IPM v.5.13 Base Case.

See Appendices 3-2, 3-3, 3-4, and 3-5 of the Documentation for EPA Base Case v.5.13 Using the Integrated Planning Model for more details 

on settlements and state rules. 

NSR Settlements State Settlements Citizen Suits State Rules

Regional/National 

Programs International

Alabama Power AES SWEPCO Alabama Title IV Acid Rain Program Canada

Minnkota Power

Niagara Mohawk 

Power Allegheny Energy Arizona

Regional Green House Gas 

Initiative (RGGI) Alberta

SIGECO

Public Service Co of 

New Mexico

Wisconsin Public 

Service Corp. California Pacific Northwest Manitoba

PSEG Fossil

Public Service Co of 

Colorado

University of 

Wisconsin Colorado NOX SIP Call Ontario

TECO TVA

Tucson Electric 

Power Connecticut

Western Regional Air 

Partnership (WRAP) Quebec

WEPCO

Rochester Gas & 

Electric

Kansas City Board 

of Public Utilities Delaware

Clean Air Interstate Rule 

(CAIR) New Brunswick

VEPCO Mirant-New York Dominion Energy Georgia

Mercury and Air Toxics 

Standard (MATS) Nova Scotia

Santee Cooper

RC Cape May Holdings, 

LLC Duke Energy Illinois

Best Available Retrofit 

Technology (BART) PEI

Ohio Edison Kansas

Labrador & 

Newfoundland

Mirant Louisiana Saskatchewan

Illinois Power Maine

Kentucky Utilities Company Maryland

Salt River Project Massachusetts

American Electric Power (AEP) Michigan

Eastern Kentucky Power 

Cooperative Minnesota

Nevada Power Missouri

Dayton Power and Light Montana

Westar Energy

New

Hampshire

Duke Energy New Jersey

American Municipal Power New York
20

Hoosier Energy Rural Electric Coop North Carolina

Northern Indiana Public Service Co. Oregon

Tennessee Valley Authority Pennsylvania

Wisconsin Public Service Texas

Dairyland Power Cooperative Utah

Louisiana Generating LLC Washington

Dominion Energy, Inc. West Virginia

Wisconsin Power and Light Wisconsin
21

Appendix 3-1: Explanation of Model Plant Nomenclature

The field headers given in each row of Tables 10-14 represent model plant types. The model plant types are differentiated 

by fuel used (e.g., coal, oil/gas, nuclear, hydro), combustion technology (e.g., turbine, combined cycle gas), control 

technology (e.g., scrubber, post-combustion NOX control), online status (e.g., new, existing, or retiring) and retrofit structure 

(e.g., coal plant with existing SNCR retrofit with ACI). It is helpful in understanding the nomenclature of model plants to 

recognize the significance of the “ret.”, “exist” and “&” usage in the title. “Ret.” suggests that the model plant is receiving a 

retrofit in or by the given run year. If there is no “exist” label that immediately follows the “ret.” designation, then every 

control listed is a retrofit on a unit without any previously existing emission controls. The indicated are endogenous to the 

model.

If there is an “exist” that follows “ret.” then each control listed after the “exist” and before the first ampersand (&) is an

existing control and everything after the “&” is a retrofit that is added to that model plant by the model run year given. To 

illustrate the difference, let’s look at plant types with the same controls shown but with the word “Exist” absent and when 

the word “Exist” is present, there will be variants in the placement of the first ampersand (&):

Sample Plant Types and Descriptions

Plant Type Description

ExistSCR_WFGD_ACI Existing Coal Steam with SCR, ACI and Wet FGD

Ret.ACI & SCR & WetFGD Retrofit ACI, SCR, and Wet FGD on Existing Coal Steam

Ret.ExistACI & SCR & WetFGD Retrofit SCR, and Wet FGD on Existing Coal Steam with ACI

Ret.ExistSCR_ACI & WetFGD Retrofit Wet FGD on Existing Coal Steam with SCR and ACI

Ret.ExistWetFGD & ACI & SCR Retrofit ACI, and SCR on Existing Coal Steam with Wet FGD

Ret.ExistWetFGD_ACI & SCR Retrofit SCR on Existing Coal Steam with ACI and Wet FGD

Ret.ExistWetFGD_SCR & ACI Retrofit ACI on Existing Coal Steam with SCR and Wet FGD
22

Appendix 3-2: Abbreviations Appearing in Model Plant Naming

Abbreviation Definition

IGCC Integrated Gasification Combined Cycle

PV Photovoltaic

ACI Activated Carbon Injection

FGD Flue gas desulfurization

SCR Selective Catalytic Reduction

SNCR Selective Non Catalytic Reduction

CC Combined Cycle

CT Combustion Turbine

CCS Carbon Capture & Storage

Ret Retrofit

Exist Existing