2013 GHGRP Industrial Profiles
Power Plants
Power Plants Sector
Highlights
• Greenhouse gas (GHG) emissions from the Power Plants
Sector for 2013 were less than one percent higher than
2012 and five percent lower than 2011. The lack of a
clear trend from 2012 to 2013 indicates that the
displacement of coal by gas to power base load
generation has dramatically slowed as natural gas prices
have increased.
• Fifty one natural gas combined-cycle generating units were put into service in the United
States during 2010, 2011, and 2012. These units generate approximately one-fourth of the
GHG emissions per megawatt compared to conventional coal-fired units, which is
contributing to the observed decline in emissions from the sector over the period covered
by the GHGRP.
• According to data from the U.S. Department of Energy's (DOE) Energy Information
Administration (EIA), increased utilization of hydro-electric and wind assets from 2010 to
2013 are also contributing to lower emissions from this sector across the time series.
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 EPA under 40 CFR part 75:
facilities subject to the Acid Rain Program (ARP) and facilities in the Regional Greenhouse Gas
Initiative (RGGI) (see http: //rggi.org). Facilities subject to the ARP and RGGI have combustion units
that serve electricity generators that exceed 25 megawatts. These facilities are subject to Subpart D
of the Greenhouse Gas Reporting Program (GHGRP).
The second group includes combustion units that are located at facilities with primary NAICS codes
of 221330 (Steam and Air-Conditioning Supply1) and 2211xx (Electric Power Generation,
Transmission and Distribution). These facilities are subject to Subpart C of the GHGRP.
Who Reports?
In 2013,1,570 facilities in the Power Plants Sector submitted GHG reports. The Power Plants Sector
reflects 20% of the facilities reporting direct emissions to the GHGRP. Total reported emissions
from the sector were 2,100.9 million metric tons C02e (MMT C02e). In 2012, power plants
represented approximately 32% of total U.S. GHG emissions.2
Emissions in the Power Plants Sector from the combustion of coal accounted for 74.5% of the total
reported emissions in 2013. Emissions from natural gas combustion contributed 22.6% of the total
emissions and other fossil fuels accounted for 2.8%.
All emissions presented here
are as of 8/18/2014 and
exclude biogenic CO2. All
GHG emissions data
displayed in units of carbon
dioxide equivalent (C02e)
reflect the global warming
potential (GWP) values from
TPCC AR4.
1 Establishments primarily engaged in providing steam, heated air, or cooled air. The steam distribution may
be through main lines.
2 The total U.S. GHG emissions are 6,525.6 MMT C02e as reported in the Inventory of U.S. Greenhouse
Gas Emissions and Sinks: 1990-2012. U.S. Environmental Protection Agency. April 15, 2014. EPA 430-R-14-
003. 3 Annual Electric Utility data: http: //www.eia.gov/electricity/data/eia92 3 /
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2013 GHGRP Industrial Profiles
Power Plants
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 Acid Rain
Program or otherwise required to report CO 2 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 metric tons
C02e/year from stationary fuel combustion.
2010
Table 2: Power Plants Sector - Number of Reporters (2011-2013)
Power Plants Sector
Number of Reporters
2011
2012
2013
Total Power Plants Sector
1,589
1,601
l,570a
Electricity Generation (Subpart D]
1,282
1,292
1,268
Other Power and Steam Plants (Subpart C]
307
309
302
a Beginning in 2013, facilities became eligible to discontinue reporting if emissions were less than 15,000 metric tons
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 FLIGHT by using the drop-down menu
titled "Filter by Status."
Table 3: Power Plants Sector - GHGRP Coverage (as of Reporting Year 2012)a
Source Category
GHGRP Coverage of Industry
Estimated Percent of
Industry Facilities
Covered by GHGRP
Estimated Percent of
Industry Emissions
Covered by GHGRP
Electricity
Generation
All electric generating units
subject to the Acid Rain Program
or that are otherwise required to
report CO 2 mass emissions to
EPA year round under 40 CFR
part 75.
100%
100%
Other Power and
Steam Plants
Facilities that emit > 25,000
metric tons C02e/year from
stationary fuel combustion and
that reported a primary NAICS
code of 221330 or 2211xx.
20%b
95%c
a The reporting universe has evolved since 2012 (see Table 2] however these changes have not significantly impacted
the percent of emissions covered by the GHGRP in this sector.
b Estimate of size of industry based on U.S. EPA eGRID2012 Version 1.0 for 2009 data.
c Estimate of size ofindustiy emissions based on U.S. EPAeGRID2012 Version 1.0 for 2009 data.
EPA has determined that the GHGRP covered more than 99.8% of the 2012 emissions in the Power
Plants Sector. This included 100% of emissions from electricity generating units larger than 25
megawatts and over 95% of emissions from other facilities included in the sector.
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2013 GHGRP Industrial Profiles
Power Plants
Reported Emissions
Table 4: Power Plants Sector - Emissions by Subsector (2011-2013)
Power Plants Sector
Emissions (MMT C02e)-'
2011
2012
2013
Total Power Plants Sector
2,221.3
2,088.1
2,100.9
Electricity Generators (Subpart D]
2,145.8
2,016.1
2,034.2
Other Power and Steam Plants (Subpart C]
75.5
72.0
66.7
a Totals may not sum due to independent rounding.
Figure 1: Power Plants Sector - Emissions by Subsector (2013)
©2013 TOTAL REPORTED EMISSIONS FROM THE POWER PLANTS
SECTOR, BY SUBSECTOR
Other Power and
Steam Plants
Electricity Generation
97%
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2013 GHGRP Industrial Profiles
Power Plants
Figure 2: Location and Emissions Range for Each Reporting Facility in the Power Plants
Sector (as of 8/18/14)
%"
m
.*
-f
¦ i. • ''v.;t
?!
• •
~». - ». •
1. • »s •
••
• 0 j\
GHGRP, 2013
Power Plants Sector Emissions
(metric tons C02e)
• <500,000
• 500,000—2,000,000
• 2,000,000—5,000,000
• 5,000,000—10,000,000
0 >10,000,000
Data Source: 2013 Greenhouse Gas Reporting Program
As of: 08/18/2014
. • ••• •# 1
• .* • i
-j-j-—• . ».•
.• * 1. * 1 • 1
Ue)
*L prO"^
This map shows the locations of direct-emitting facilities. The size of a circle corresponds to the
quantity of emissions reported by that facility. There are also power plant facilities located in
Alaska, Hawaii, Puerto Rico, the U.S. Virgin Islands, and Guam
(http://www.epa.gov/ghgreporting/ghgdata/reported/powerpIants.htmll.
Readers can identify the largest emitting facilities by visiting the Facility Level Information on
Greenhouse Gases (FLIGHT) website fhttp://ghgdata.epa.govI
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2013 GHGRP Industrial Profiles
Power Plants
Figure 3: Power Plants Sector - Emissions by State (2013)a
©
DIRECT EMISSIONS BY STATE FROM THE POWER PLANTS
SECTOR
2013 Emissions (million metric tons C02e)
50 100 150
200
250
Alabama
Alaska
Arizona
Arkansas
California
Colorado
Connecticut
Delaware
District of Columbia
Florida
Georgia
Guam
Hawaii
Idaho
Illinois
Indiana
Iowa
Kansas
Kentucky
Louisiana
Maine
Maryland
Massachusetts
Michigan
Minnesota
Mississippi
Missouri
Montana
Nebraska
Nevada
New Hampshire
New Jersey
New Mexico
New York-
North Carolina
North Dakota
Ohio
Oklahoma
Oregon
Pennsylvania
Puerto Rico
Rhode Island
South Carolina
South Dakota
Tennessee
Texas
Utah
Vermont
Virgin Islands
Virginia
Washington
West Virginia
Wisconsin
Wyoming
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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2013 GHGRP Industrial Profiles
Power Plants
Power Plants Sector: Emissions Trends 2012 to 2013
From 2012 to 2013, emissions in the Power Plants Sector increased by less than one percent The
lack of a clear trend from 2012 to 2013 indicates that the displacement of coal by gas to power base
load generation has dramatically slowed.
Power Plants Sector: Longer-Term Emissions Trends
From 2010 to 2013, annual emissions in the Power Plants Sector decreased by about ten percent.
Several factors contributed to this reduction, including the increased use of renewable energy
sources, historically-low natural gas prices, and increased use of combined-cycle generators. To
meet state requirements for control of ozone and fine particles, utilities are retiring older coal-fired
units that cannot be cost-effectively retrofitted with air pollution control equipment and replacing
these conventional coal generators with natural gas combined-cycle generators. Combined-cycle
power plants are approximately twice as efficient as conventional power plants; according to EIA
data for 2013, 97.7% of the heat input to combined cycle plants was from combustion of natural
gas.3 Combustion of natural gas releases approximately half the mass of GHGs per unit of heat
released compared to coal combustion. Therefore, when a conventional coal plant is replaced with a
natural gas combined-cycle plant, emissions of GHGs are reduced by about 75% per unit of
electrical output. According to the DOE's EIA Form 860 data, 51 new natural gas combined-cycle
power blocks came online during 2010, 2011, and 2012.4
Figure 4: Power Plants Sector - Change in Net Generating Output by Generating Technology
(2010-2013)ab
©
NET GENERATING OUTPUT BY GENERATING TECHNOLOGY FOR
THE POWER PLANTS SECTOR (2010-2013)
3,000,000,000
2,500,000,000
g 2,000,000,000
s
1,500,000,000
1,000,000,000
500,000,000
o
u
g
0
^// ~V
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2013 GHGRP Industrial Profiles
Power Plants
Figure 5: Power Plants Sector - Change in Net Generating Output and GHG Emissions by Fuel
Type (2010-2013)ab
©COMPARISON OF POWER PLANT GENERATION TO EMISSIONS
FOR THE POWER PLANTS SECTOR (2010-2013)
c
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2013 GHGRP Industrial Profiles
Power Plants
Figure 6: Power Plants Sector - Emissions Trend by Subsector (2011-2013)
©
ANNUAL REPORTED DIRECT EMISSIONS FROM THE POWER
PLANTS SECTOR, BY SUBSECTOR
o
o
in
e
o
0)
E
c
o
(A
c
o
'35
i/i
2,500
2,000
1,500
1,000
500
Electricity Generation
Other Power and Stream
Plants
2011
2012
2013
Click here to view the most current information using FLIGHT.
Table 5: Power Plants Sector - Emissions by GHG (MMT C02e)
Power Plants Sector
Reporting Year
2011
2012
2013
Number of facilities
1,589
1,601
1,570
Total emissions (C02e)
2,221.3
2,088.1
2,100,9
Emissions by GHG
Carbon dioxide (C02)
2,208.0
2,076.0
2,089.0
Methane (CH+)
4.2
3.7
3.7
Nitrous oxide (N20)
9.2
8.2
8.4
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2013 GHGRP Industrial Profiles
Power Plants
Table 6: Power Plants Sector - Combustion Emissions by Fuel Type - Subpart Da
Fuel Type
Total Reported Emissions (MMT C02e)
2011
2012
2013
Coal
1,683.5
1,488.8
1,548.4
Natural Gas
412.8
486.5
443.7
Petroleum Products
34.3
28.0
30.6
Other Fuelsb
0.1
0.2
0.2
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 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,
i Excludes biogenic carbon dioxide.
Table 7: Power Plants Sector - Combustion Emissions by Fuel Type - Subpart Ca
Fuel Type
Total Reported Emissions (MMT C02e)
2011
2012
2013
Coal
30.0
28.1
21.8
Natural Gas
29.7
33.0
28.5
Petroleum Products
22.0
19.0
20.7
Other Fuels'3
3.6
3.9
4.9
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 facilities, as well as default emission factors.
b Excludes biogenic CO2.
Figure 7: Power Plants Sector - Average Emissions per Reporter (2013)
©AVERAGE EMISSIONS PER REPORTER FROM THE POWER
PLANTS SECTOR
2013 Emissions (million metric tons C02e)
0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8
Electricity Generation
Other Power and
Steam Plants
GHGRP Average
(Direct Emitters Only)
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2013 GHGRP Industrial Profiles
Power Plants
Figure 8: Power Plants Sector - Percentage of Reporters by Range of Emissions (2013)
©
PERCENTAGE OF FACILITIES IN THE POWER PLANTS SECTOR
AT VARIOUS EMISSION RANGES
d)
U)
c
<0
cc
"O
0
O
<0
c
CD
o
Q_
35%
30%
25%
20%
15%
10%
5%
0%
Power Plants
Sector
n
GHGRP (All
Direct Emitters)
0-25 25-50 50- 100 100-250 250-1,000 >1,000
2013 Emissions Range (thousand metric tons C02e)
Table 8: Power Plants Sector - Number of Reporters by Emissions Range (2013)
Power Plants Sector
Number of Facilities Within Emissions Range (MMT C02e)
0-0.025
0.025-0.05
0.05 - 0.1
0.1 - 0.25
0.25 -1
> 1
Total Power Plants Sector
342
154
150
177
294
453
Electricity Generation
247
102
104
127
254
437
Other Power and Steam Plants
95
52
46
50
40
16
Calculation Methods Used
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 (Table 9) 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 continuous
emissions monitoring system (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 CO- emissions from
company records of fuel usage and periodic fuel sampling and analysis (to determine the
percent carbon in the fuel).
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2013 GHGRP Industrial Profiles
Power Plants
• Equation G-4 of Appendix G (40 CFR part 75) - Gas and oil-fired units can calculate
hourly C02 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 to use the
LME unit provisions, a unit must be gas-fired or oil-fired, and its S02 and/or N0X 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 (tiers) to calculate CO2 emissions
(Table 9), depending on fuel type and unit size. Units that are not subject to Subpart D but are
required by states to monitor emissions according to Part 75 can report 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).
For both Subpart C and Subpart D reporters, methane (CH4) and nitrous oxide (N2O) 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.
For reporting year 2010, some facilities were eligible to use any of the four calculation tiers, but had
to start using the required tier in 2011.
Table 9: Power Plants Sector: Combustion Source Calculation Methodologies
Type of
Emissions
Methodology
Portion of Emissions
Monitored by Method (by Type)
2011
2012
2013
CEMS (Subpart D)
81.0%
76.4%
78.9%
Part 75 Appendix G, Equation G-4
14.4%
18.6%
16.8%
Part 75 Appendix G, Equation G-l
0.7%
0.9%
0.7%
LME per §75.19(c)(4)(iii)
0.1%
0.1%
0.1%
Electricity
CEMS (Tier 4, Subpart C)
0.9%
0.8%
0.8%
Generation:
Combustion
Emissions
Measured carbon content, and, if
applicable, molecular weight (Tier 3)
1.1%
1.1%
0.9%
Measured high heating values (HHVs)
and default emission factors (Tier 2)
1.0%
1.1%
0.8%
Default HHVs and emission factors
(Tier 1)
0.2%
0.3%
0.4%
Alternative Part 75 Methodologies
0.6%
0.7%
0.7%
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2013 GHGRP Industrial Profiles
Power Plants
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.
Electricity generating sources subject to Subpart D report CO2 mass emissions data to the EPA's
Clean Air Markets Division (CAMD). Consistency between the unit-level data submitted through the
GHGRP and CAMD are assessed by comparing the two data sets. However, due to differences in the
GHG pollutants reported and the universe of reporters subject to each program, the CAMD data is
not well-suited for comparison with the GHGRP data for total C02e emissions for this sector. As an
alternative, EIA data can be used to estimate the C02 emissions from the combustion of fossil fuels
in the power plants sector, as is performed in the EPA Inventory of U.S. Greenhouse Gas Emissions
and Sinks: 1990-2012. Table 10 shows a comparison of these two datasets for GHG emissions from
the power plants sector for 2011 through 2013. The GHGRP emissions from the power plants sector
are about 0.4-0.7% less than the estimate provided in the Inventory. Given the inventory emissions
values are calculated based on the amount of fuel combusted and applying emission factors, this
minor difference shows excellent agreement with the GHGRP data that is obtained primarily
through the use of CEMS for units in this sector.
Table 10: Power Plants Sector - Comparison of Emissions by Data Source (2011-2013)
Power Plants Sector
Emissions (MMT C02e)
2011
2012
2013
GHGRP3
2,145.8
2,016.1
2,034.2
Inventory of U.S. GHG Emissions & Sinksb
2,158.1
2,022.2
N/A
a Totals as shown in Table 4 of this section.
b Sum of coal, natural gas, and fuel oil emissions from stationaiy fossil fuel combustion for the electricity generation
sector contained in Table 3-9 of Inventoiy of U.S. Greenhouse Gas Emissions and Sinks: 1990-2012
rhttp://www.epa.gov/climatechange/ghgemissions/usinventoi-yreport.htmn.
GLOSSARY
ARP means the Acid Rain Program authorized by Title IV of the Clean Air Act.
BAMM means Best Available Monitoring Methods. Facilities approved for BAMM may use best
available monitoring methods for any parameter (e.g., fuel use, feedstock rates) that cannot
reasonably be measured according to the monitoring and QA/QC requirements of a relevant
subpart
CAMD refers to the Clean Air Markets Division within the EPA Office of Atmospheric Programs.
CAMD administers the Acid Rain Program and other market-based air pollution control programs.
CFR means the Code of Federal Regulations.
CChe means carbon dioxide equivalent, which is a metric used to compare the emissions from
various greenhouse gases based upon their global warming potential (GWP). The carbon dioxide
equivalent for a gas is calculated by multiplying the tons of the gas by the associated GWP.
Direct emitters are facilities that combust fuels or otherwise put greenhouse gases into the
atmosphere directly from their facility. Alternatively, Suppliers are entities that supply certain
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2013 GHGRP Industrial Profiles
Power Plants
fossil fuels or fluorinated gases into the economy that—when combusted, released or oxidized—
emit greenhouse gases into the atmosphere.
FLIGHT refers to EPA's GHG data publication tool, named Facility Level Information on GreenHouse
Gases Tool (http://ghgdata.epa.gov).
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 greenhouse gas 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 greenhouse gases 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/ghgreporting/ghgdata/reported/inventory.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 carbon dioxide. The GWP for
carbon dioxide 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 Reisinger, A. (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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