2011-2017 GHGRP Industrial Profile
Power Plants Sector
Greenhouse Gas Reporting Program
Industrial Profile: Power Plants Sector
September 2019
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2011-2017 GHGRP Industrial Profile
Power Plants Sector
CONTENTS
POWER PLANTS SECTOR 1
Highlights 1
About this Sector 1
Who Reports? 2
Reported Emissions 3
Power Plants Sector: Emissions Trends, 2011 to 2017 6
Emission Calculation Methods Available for Use 12
Data Verification and Analysis 13
Glossary 13
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2011-2017 GHGRP Industrial Profile
Power Plants Sector
POWER PLANTS SECTOR
Highlights
• Greenhouse gas (GHG) emissions from the Power
Plants Sector have steadily decreased since 2011.
GHG emissions in 2017 were over 19% lower than
2011 emissions.
• The replacement of coal-fired units with natural
gas combined-cycle units contributes to the
observed decline in emissions from the Power
Plants Sector over the period covered by the
Greenhouse Gas Reporting Program (GHGRP). A
plant's cost for electricity generation is a function
of fuel price and conversion efficiency. When
natural gas prices are low compared to coal,
natural gas power production is favored.1 The
natural gas combined-cycle units generate approximately 40% of the GHG emissions per
megawatt-hours (MWh) of power output compared to conventional coal-fired units.2
• According to data from the U.S. Department of Energy's (DOE's) Energy Information
Administration (EIA), increased utilization of renewables such as wind and solar assets
from 2011 to 2017 continues to contribute to decreased emissions from this sector across
the time series.3
About this Sector
The Power Plants Sector consists predominantly of facilities that produce electricity by combusting
fossil fuels or biomass. The sector also includes facilities that produce steam, heated air, or cooled
air by combusting fuels.
Two groups of power plants are required to report. The first group includes facilities that are
required to report CO2 mass emissions on a year-round basis to the U.S. Environmental Protection
Agency (EPA) under 40 CFR Part 75: facilities subject to the Acid Rain Program (ARP) and facilities
in the Regional Greenhouse Gas Initiative (RGGI) (see https: //www.rggi.0rg/I Facilities subject to
the ARP have combustion units that serve electricity generators that exceed a 25-MW nameplate
capacity and facilities subject to the RGGI have combustion units that serve electricity generators
that are equal to or greater than a 25-MW nameplate capacity. These facilities are subject to
Subpart D of the GHGRP. For more details on the reporting requirements of power plants subject to
Subparts 75 and 98, see the following link.
All emissions presented here are
as of 8/19/2018 and exclude
biogenic carbon dioxide (CO2). All
GHG emission data displayed in
units of carbon dioxide equivalent
(CC>2e) reflect the global warming
potential (GWP) values from
Table A-l of 40 CFR 98, which is
generally based on the
Intergovernmental Panel on
Climate Change's Fourth
Assessment Report flPCC AR41.
1. Annual Energy Outlook 2012 with Projections to 2035. DOE/EIA (2012), June 2012.
https://www.eia.gov/outlooks/aeo/pdf/0383 (2 012).pdf
2. EPA's Emissions and Generation Resource Integrated Database (eGRID), released in 2018 with 2016 data,
shows that at the national level, natural gas units have an average emission rate of 898 pounds CO2 per
megawatt-hour (MWh), while coal units have an emissions rate of 2,180 pounds CO2 per MWh. U.S.
Environmental Protection Agency. 2018. Emissions and Generation Resource Integrated Database (eGRID).
Available: https: //www.epa.gov/energy/emissions-generation-resource-integrated-database-egrid.
3. U.S. Energy Information Administration, Electricity Data Browser: Net Generation for All Sectors Annual.
Available: http: / /www.eia.gov/electricity /data /browser /# /topic /0?agg=2.
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2011-2017 GHGRP Industrial Profile
Power Plants Sector
The second group includes combustion units that are located at facilities with primary North
American Industry Classification System (NAICS) codes of 221330 (Steam and Air-Conditioning
Supply4) and 221 lxx (Electric Power Generation, Transmission and Distribution), and emit
> 25,000 metric tons (MT) C02e per year from stationary fuel combustion. These facilities are
subject to Subpart C of the GHGRP. Table 1 includes details of the applicability of each reporter
category as well as their corresponding reporting schedules.
Table 1: Power Plants Sector - Reporting Schedule by Subpart
Subpart
Source Category
Applicability
First Reporting
Year
D
Electricity generation
All electric generating units subject to the ARP or
otherwise required to report CO2 mass emissions to
EPA year-round under 40 CFR Part 75
2010
C
General stationary
fuel combustion
Facilities that reported a primary NAICS code of
221330 or 2211xx, and emit > 25,000 MT C02e per
year from stationary fuel combustion
2010
Who Reports?
In 2017,1,369 facilities in the Power Plants Sector submitted GHG reports. The Power Plants Sector
represents 18% of the facilities reporting direct emissions to the GHGRP. Total reported emissions
from the sector were 1,792.8 million metric tons (MMT) C02e, which represented 62% of total
direct emissions reported to the GHGRP. In 2017, power plants represented approximately 28% of
total U.S. GHG emissions.5 Table 2 shows the number of reporters and emissions by subsector by
year.
Table 2: Power Plants Sector - Number of Reporters (2011-2017)
Power Plants Sector
Number of Reporters
2011
2012
2013
2014
2015
2016
2017
Total Power Plants
Sector
1,592
1,609
l,577a
1,547
l,485b
1,411
1,369
Electricity generation
(Subpart D)
1,286
1,296
1,272
1,247
1,193
1,150
1,125
Other power and steam
plants (Subpart C)
306
313
305
300
292
261
244
a Beginning in 2013, facilities became eligible to discontinue reporting if their emissions were less than 15,000 MT CChe
per year for each of the previous three reporting years. More information on when a facility is eligible to stop reporting is
available. Facilities that have stopped reporting can be identified in Facility Level Information on Greenhouse Gases Tool
(FLIGHT) by using the drop-down menu titled "Filter by Status."
b Beginning in 2015, facilities became eligible to discontinue reporting if their emissions were less than 25,000 MT CChe
per year for each of the previous five reporting years. More information on when a facility is eligible to stop reporting is
available. Facilities that have stopped reporting can be identified in FLIGHT by using the drop-down menu titled "Filter by
Status."
4. Establishments primarily engaged in providing steam, heated air, or cooled air. The steam distribution may
be through main lines.
5. Total U.S. GHG emissions for 2017 were 6,456.7 MMT C02e, as reported in the Inventory of U.S. Greenhouse
Gas Emissions and Sinks: 1990-2017. U.S. Environmental Protection Agency. EPA 430-R-19-001. Available:
https://www.epa.gov/ghgemissions/overview-greenhouse-gases.
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2011-2017 GHGRP Industrial Profile
Power Plants Sector
Reported Emissions
Table 3 shows the reported emissions by subsector by year. Figure 1 shows the breakdown of
emissions by subsector in Reporting Year 2017.
Table 3: Power Plants Sector - Emissions by Subsector (2011-2017)
Power Plants Sector
Emissions (MMT CChe)3
2011
2012
2013
2014
2015
2016
2017
Total Power Plants Sector
2,221.7
2,089.5
2,105.8
2,101.7
1,972.5
1,876.7
1,792.8
Electricity generators
(Subpart D)
2,135.4
2,006.8
2,027.8
2,026.4
1,899.4
1,808.1
1,738.1
Other power and steam plants
(Subpart C]
86.2
82.7
78.0
75.2
73.1
68.5
54.7
a Totals may not sum due to independent rounding.
©FIGURE 1: 2017 TOTAL REPORTED EMISSIONS FROM THE POWER
PLANTS SECTOR, BY SUBSECTOR
Figure 2 shows the locations of power plant facilities. Sizes of circles correspond to the quantity of
emissions reported by that facility. There are also power plants located in Alaska, Hawaii, Puerto
Rico, the U.S. Virgin Islands, and Guam (https://www.epa.gov/ghgreporting/ghgrp-power-plants).
Readers can identify the largest emitting facilities by visiting the FLIGHT website
fhttp://ghgdata.epa.gov/ghgp/main.do].
Figure 3 shows the reported direct emissions by state from the Power Plants Sector for 2017. The
states with the highest reported emissions from this sector for 2017 were Texas, followed by
Florida and Indiana.
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2011-2017 GHGRP Industrial Profile
Power Plants Sector
©FIGURE 2: POWER PLANTS SECTOR-EMISSIONS BY RANGE AND
LOCATION (2017)
J TT ..
\ M ® \ ©° (pT\ © /gv@©o •
v „ ® •
f "* - °-c-h - 9 • '-J
/a - "wo ® ™ a ® • © © en #
a • • 1 4a a • ®
( . I • , I . °0 ; • :v. >£**> 4*
n1 " ° C~} ° a 0 8° (5 tfiQ^ e (cP .JOrto
«J, °° f£>>° 1 a ° 0 °°e© I* '® A. c?^ 2°
n-*: n.o.. A. *f'
®o v>° 0 o ^ ®
ffV ° 8
Power Plants Sector Emissions, 2017 0,crv§®.dP®® 10,000,000
[ Data Source: 2017 Greenhouse Gas Reporting Program |
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2011-2017 GHGRP Industrial Profile
Power Plants Sector
©
L_ -A
FIGURE 3: DIRECT EMISSIONS BY STATE FROM THE POWER
PLANTS SECTOR3
2017 Emissions (million metric tons C02e)
Texas
Florida
Indiana
Ohio
Pennsylvania
Missouri
West Virginia
Illinois
Kentucky
Michigan
Alabama
Georgia
North Carolina
Arizona
Wisconsin
Wyoming
Louisiana
Colorado
Tennessee
Arkansas
Oklahoma
California
Virginia
North Dakota
Utah
Minnesota
Iowa
Mississippi
South Carolina
New York
New Mexico
Kansas
Nebraska
New Jersey
Montana
Nevada
Maryland
Massachusetts
Washington -H
Oregon
Hawaii
Connecticut
Puerto Rico
Alaska
Delaware -I
Rhode Island -I
South Dakota \
New Hampshire \
Guam -|
Idaho -j
Maine-|
Virgin Islands
District Of Columbia -j
a Represents total emissions reported to the GHGRP from this industry. Additional emissions occur at facilities that have
not reported, such as those below the reporting threshold.
Click here to view the most current information using FLIGHT.
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2011-2017 GHGRP Industrial Profile
Power Plants Sector
Power Plants Sector: Emissions Trends, 2011 to 2017
Emissions in the Power Plants Sector decreased 19.3% from 2011 to 2017, from 2,221 MMT C02e in
2011 to 1,793 MMT C02e in 2017. Several factors contributed to this reduction, including the
increased use of renewable energy sources, historically low natural gas prices, and increased use of
more efficient natural gas combined-cycle generators.6 Overall, GHG emissions per unit of
electricity production have decreased from 541.8 to 444.6 MT C02e per thousand MWh (17.9%)
since 2011. In 2011, 42.3% of U.S. electricity was produced from coal and 24.7% from natural gas.
By 2017, only 29.9% of electricity production was produced from coal and 32.1% from natural gas.7
Nationally, fuel consumption for electricity generation decreased by 13% from 2011 to 2017.8 The
number of facilities has decreased from a high of 1,609 reporters in 2012 to 1,369 reporters in
2017. Figure 4 shows the progression of total net power generation from 2011 to 2017 by
technology type.
6. Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990-2017. EPA 430-R-19-001. U.S. Environmental
Protection Agency. Available: https://www.epa.gov/ghgemissions/overview-greenhouse-gases.
7. U.S. Energy Information Administration, Electricity Data Browser: Net Generation for All Sectors Annual.
Available: http://www.eia.gov/electricity/data /browser/#/topic/0?agg=2.
8. U.S. Energy Information Administration. Electricity Data Browser: Total Consumption [Btu] for All Sectors,
Annual. Available:
http://www.eia.gov/electri city/data/browser/#/topic/8?agg=2.0.1&fuel=f&geo=g&sec=g&freq=A&start=20
01&end=2017&ctype=linechart<ype=pin&rtype=s&maptype=0&rse=0&pin=.
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2011-2017 GHGRP Industrial Profile
Power Plants Sector
©
FIGURE 4: NET GENERATING OUTPUT BY GENERATING
TECHNOLOGY FOR THE POWER PLANTS SECTOR (2011-2017)ab
Figure 4a. Net Generating Output by Generating Technology
3500
3000
2500
2000
1500
1000
500
¦Combined Cycle
Fuel Cell
¦Simple Cycle
¦Steam Turbines
¦ Renewable Sources
¦Other
2011
2012
2013
2014
2015
2016
2017
350
300
250
200
150
100
50
0
2011 2012 2013 2014 2015 2016 2017
a Net generating output data obtained from the EIA Form 923 Reports.
b "Steam Turbines" include generators powered by nuclear plants or the combustion of coal, oil, natural gas,
or biomass; but do not include combined-cycle steam turbines.
Figure 4b. Net Generating Output of Renewable Sources
Geothermal Hydro
^^—Photovoltaic Wind
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2011-2017 GHGRP Industrial Profile
Power Plants Sector
Coal and natural gas account for about 62% of U.S. electricity generation by utility-scale
generators.9 Coal combustion accounted for 68.3% of total reported power plant sector emissions
in 2017, natural gas combustion accounted for 29.7% of total emissions, and other fossil fuels
accounted for 2.1%. In 2017, coal combustion generated 47.5% of the total MWh produced from
fuel combustion, and natural gas combustion generated 51.1%.10 Due to the higher rate of
emissions per MWh of coal, emissions from coal combustion are more than double the emissions
from natural gas combustion despite the generation from natural gas being slightly higher than that
from coal in 2017. Figure 5 compares the emissions and net generation from coal and natural gas
plants by year.
©
2000
1800
§ 1600
£
.2 1400
il 1200
§ iooo
E 800
01
E
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2011-2017 GHGRP Industrial Profile
Power Plants Sector
In general, there is a downward trend in emissions from both of the subsectors (see Figure 6).
Table 4 breaks down the emissions by the GHG emitted.
Table 5 and Table 6 break down emissions by fuel type for each subsector.
©
FIGURE 6: ANNUAL REPORTED DIRECT EMISSIONS FROM THE
POWER PLANTS SECTOR, BY SUBSECTOR
2500-
^ 2000 -
a>
C\J
O
O
CO
c
o
o 1500^
CD
E
c
o
J. 1000 —
c
o
CO
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2011-2017 GHGRP Industrial Profile
Power Plants Sector
Table 5: Power Plants Sector - Combustion Emissions by Fuel Type - Electricity
Generators3'11
Fuel Type
Total Reported Emissions (MMT CChe)
2011
2012
2013
2014
2015
2016
2017
Coal
1,695.2
1,489.8
1,550.8
1,557.7
1,351.5
1,241.8
1,207.4
Natural gas
402.0
488.7
446.2
445.7
526.8
538.8
505.7
Petroleum products
21.4
16.2
19.5
17.9
15.7
18.1
17.2
Other fuelsb
4.9
5.3
5.9
4.7
5.4
8.6
7.9
a In cases where CO2 emissions were reported at the unit level (i.e., CEMS-monitored sources], fuel-level CO2 emissions
were estimated by EPA based on other data directly reported by the facilities, as well as default emission factors. Fuel-
level emission values presented may differ slightly from other publicly available GHGRP data due to minor differences in
the calculation methodology.
b Individual fuel emissions may not sum to total emissions due to independent rounding.
c Excludes biogenic CO2.
Table 6: Power Plants Sector - Combustion Emissions by Fuel Type - Other Power and Steam
Plantsab
Fuel Type
Total Reported Emissions (MMT CChel
2011
2012
2013
2014
2015
2016
2017
Coal
30.5
28.6
22.6
25.3
22.0
19.8
16.2
Natural gas
29.0
30.4
28.8
28.0
29.4
28.8
26.2
Petroleum products
23.0
19.7
22.2
16.3
17.0
15.6
7.7
Other fuelsb
3.6
3.9
4.3
5.3
4.6
4.2
4.4
a In cases where CO2 emissions were reported at the unit level (i.e. CEMS-monitored sources], fuel-level CO2 emissions
were estimated by EPA based on other data directly reported by the facilities, as well as default emission factors. Fuel-
level emissions values presented may differ slightly from other publicly available GHGRP data due to minor differences in
the calculation methodology.
b Individual fuel emissions may not sum to total emissions due to independent rounding.
c Excludes biogenic CO2.
Generally, the Power Plants Sector emits more GHG per reporter, as it has more large reporters
compared to all GHGRP reporters. Figure 7 compares emissions per reporter between power plant
subsectors and all GHGRP reporters on average (including power plant facilities). Figure 8 and
Table 7 show the percentage and number of reporters within each emission range, respectively.
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2011-2017 GHGRP Industrial Profile
Power Plants Sector
©
FIGURE 7: AVERAGE EMISSIONS PER REPORTER FROM THE
POWER PLANTS SECTOR, BY SUBSECTOR (2017)
2017 Emissions (million metric tons C02e)
0 0.2 0.4 0.6 0.8 1 1.2 1.4 1.6 1.8 2
I
Other Power and Steam Plants -
0.23
Electricity Generation
1.55
GHGRP Average(Direct Emitters Only) -
0.39
Table 7: Power Plants Sector - Number of Reporters by Emissions Range (2017)
Power Plants Sector
Number of Facilities within Emissions Range (MMT CChe)
0-0.025
0.025-0.05
0.05-0.1
0.1-0.25
0.25-1
>1
Total Power Plants Sector
223
131
157
173
264
421
Electricity generation
161
81
108
131
231
413
Other power and steam plants
62
50
49
42
33
8
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2011-2017 GHGRP Industrial Profile
Power Plants Sector
FIGURE 8: PERCENTAGE OF FACILITIES IN THE POWER PLANTS
SECTOR AT VARIOUS EMISSION RANGES
35%
30% -
125% 1
L I
imil
0-0.025 0.025-0.05 0.05-0.1 0.1-0.25 0.25-1 >1
2017 Emissions Range (million metric tons C02e)
Emission Calculation Methods Available for Use
Facilities in the Power Plants Sector can use several different methodologies to calculate their
emissions. Electricity-generating combustion units that are subject to Subpart D must report CO2
emissions according to the applicable requirements of 40 CFR Part 75. Part 75 provides several
monitoring options. The options that are available for a unit (shown in Table 8) depend on how the
unit is classified. In general, if a unit is coal-fired or combusts any type of solid fuel, the use of a
CEMS is required. If a unit is classified as an oil- or gas-fired unit, it may qualify for an alternative
calculation methodology instead of using a CEMS. The four Subpart D options are:
• CEMS - Operate a CEMS for CO2.
• Equation G-l of Appendix G (40 CFR Part 75) - Calculate daily CO2 emissions from
company records of fuel usage and periodic fuel sampling and analysis (to determine the
percent of carbon in the fuel).
• Equation G-4 of Appendix G (40 CFR Part 75) - Gas- and oil-fired units can calculate
hourly CO2 emissions using heat input rate measurements made with certified fuel flow-
meters together with fuel-specific, carbon-based "F-factors."
• Low Mass Emissions (LME) Units - Estimate C02 emissions using fuel-specific default
emission factors and either estimated or reported hourly heat input To qualify for using the
k- -j
| Power Plants Sector
GHGRP (All Direct Emitters)
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2011-2017 GHGRP Industrial Profile
Power Plants Sector
LME unit provisions, a unit must be gas-fired or oil-fired, and its sulfur dioxide and/or
nitrogen oxide emissions must not exceed certain annual and/or ozone season limits.
Other power and steam plants not subject to Subpart D must report under Subpart C, and the
reporter generally must use one of four calculation methodologies (i.e., tiers) to calculate CO2
emissions (Table 8), depending on fuel type and unit size. The calculation methodologies for
Subpart C are explained in more detail here. Units that are not subject to Subpart D but are
required by states to monitor emissions according to Part 75 can report their CO2 emissions
under Subpart C using Part 75 calculation methods and monitoring data that they already
collect under Part 75 (e.g., heat input and fuel use).
Table 8: Power Plants Sector: Combustion Source Calculation Methodologies
Type of
Emissions
Methodology
Portion of Emissions Monitored by Method (by type)
2011
2012
2013
2014
2015
2016
2017
Electricity
generation:
Combustion
emissions
CEMS (Subpart D)
80.8%
76.2%
78.6%
79.6%
74.7%
72.2%
69.6%
Part 75 Appendix G, Equation G-4
14.5%
18.7%
16.9%
16.2%
20.8%
23.0%
26.9%
Part 75 Appendix G, Equation G-l
0.7%
0.9%
0.7%
0.8%
0.9%
1.1%
0.3%
LME per §75.19(c)(4)(iii)
0.1%
0.1%
0.1%
0.1%
0.1%
0.1%
0.1%
CEMS (Tier 4, Subpart C)
0.8%
0.8%
0.7%
0.6%
0.5%
0.6%
0.6%
Measured carbon content and, if
applicable, molecular weight
(Tier 3)
1.2%
1.1%
1.0%
0.9%
0.9%
0.8%
0.5%
Measured high heating values
(HHVs) and default emission
factors (Tier 2)
1.1%
1.1%
0.9%
0.8%
1.0%
1.0%
0.9%
Default HHVs and emission
factors (Tier 1)
0.2%
0.3%
0.4%
0.5%
0.5%
0.4%
0.4%
Alternative Part 75
methodologies
0.6%
0.8%
0.8%
0.7%
0.7%
0.8%
0.7%
For both Subpart C and Subpart D reporters, methane and nitrous oxide mass emissions are also
required to be reported for fuels that are included in Table C-2 of Part 98, and are calculated using
either an estimated or measured fuel quantity, default or measured HHV, and default emission
factors.
Data Verification and Analysis
As a part of the reporting and verification process, EPA evaluates annual GHG reports with
electronic checks. EPA contacts facilities regarding potential reporting issues and facilities resubmit
reports if errors are identified. Additional information on EPA's verification process is available
here.
Glossary
ARP means the Acid Rain Program authorized by Title IV of the Clean Air Act
CEMS means continuous emissions monitoring system.
CFR means the Code of Federal Regulations.
C02e means carbon dioxide equivalent, which is a metric used to compare emissions from various
GHGs based upon their GWP. The C02e for a gas is calculated by multiplying the tons of the gas by
the associated GWP.
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2011-2017 GHGRP Industrial Profile
Power Plants Sector
Direct emitters are facilities that combust fuels or otherwise put GHGs into the atmosphere
directly from their facility. Alternatively suppliers are entities that supply certain fossil fuels or
fluorinated gases into the economy that - when combusted, released, or oxidized - emit GHGs into
the atmosphere.
FLIGHT refers to EPA's GHG data publication tool, named the Facility Level Information on
GreenHouse Gases Tool fhttp://ghgdata.epa.gov/ghgp/main.do].
GHGRP means EPA's Greenhouse Gas Reporting Program (40 CFR Part 98).
GHGRP vs. GHG Inventory: EPA's Greenhouse Gas Reporting Program (GHGRP) collects and
disseminates annual GHG data from individual facilities and suppliers across the U.S. economy. EPA
also develops the annual Inventory of U.S. Greenhouse Gas Emissions and Sinks (GHG Inventory) to
track total national emissions of GHGs to meet U.S. government commitments to the United Nations
Framework Convention on Climate Change. The GHGRP and Inventory datasets are complementary
and may inform each other over time. However, there are also important differences in the data and
approach. For more information, please see
http://www.epa.gov/climatechange/ghgemissions/usinventoryreport.html.
GWP means global warming potential, which is a measure of the total energy that a gas absorbs
over a particular period of time (usually 100 years), compared to CO2. The GWP for CO2 is one.
IPCC AR4 refers to the Fourth Assessment Report by the Intergovernmental Panel on Climate
Change. Climate Change 2007: The Physical Science Basis. Contribution of Working Group I to the
Fourth Assessment Report of the Intergovernmental Panel on Climate Change [Core Writing Team,
Pachauri, R.K. and A. Reisinger (eds.)]. IPCC, Geneva, Switzerland2007. The AR4 values also can be
found in the current version of Table A-l in Subpart A of 40 CFR Part 98.
MMT means million metric tons.
NAICS means the North American Industry Classification System, the standard used by federal
statistical agencies to classify business establishments into industrial categories for collecting and
publishing statistical data related to the U.S. economy.
RGGI refers to the Regional Greenhouse Gas Initiative, which is a cooperative regional effort among
nine northeastern states to reduce CO2 emissions from the power sector through a cap and trade
program.
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