Greenhouse Gas Emissions in the U.S. Electricity Sector: Background, Policies, and Projections

May 18, 2023 R47561

Greenhouse Gas Emissions in the U.S.
May 18, 2023
Electricity Sector: Background, Policies,
Jonathan L. Ramseur
and Projections
Specialist in Environmental
Policy
International negotiations and domestic policy developments continue to generate congressional

interest in current and projected U.S. greenhouse gas (GHG) emissions. The United States has
pledged to reduce its net GHG emissions by 50%-52% below 2005 levels by 2030. Considering

recent federal statutes, emissions analyses indicate U.S. net GHG emissions will decrease by
30% to 43% by 2030 compared with 2005 levels, thus not meeting the 2030 reduction target.
Overall U.S. GHG emissions levels will likely be driven by GHG emissions—particularly CO2 emissions—from electric
power plants. Multiple factors generally affect GHG emissions levels from the electric power sector, including electricity
market developments, weather, and general U.S. economic conditions. In addition, a primary factor affecting CO2 emissions
levels in the U.S. electricity sector is the electricity generation portfolio, which experienced considerable changes between
2005 and 2022, including the following:
• coal’s contribution to total electricity generation decreased from 50% to 19%;
• natural gas’s contribution to total electricity generation increased from 19% to 39%; and
• non-hydro renewable energy (mostly wind and solar) generation increased from 2% to 17%.
Climate-related provisions in recent legislation, particularly
CO2 Emissions in the Electricity Sector: Actual Levels
the tax incentives and funding provisions in P.L. 117-169,
and EIA Projections Through 2035
commonly known as the Inflation Reduction Act (IRA), are
projected to influence the U.S. electricity portfolio, and
ultimately CO2 emissions levels. Among other provisions,
IRA creates new and revises existing tax credits that
encourage electricity generation from less carbon-intensive
sources than fossil fuels, such as renewable sources or
nuclear power. Several groups have prepared projections of
emissions for the U.S. electricity sector. The figure in this
summary illustrates emissions estimates from the U.S.
Energy Information Administration (EIA), which included
a “No IRA” scenario and three IRA implementation
scenarios. EIA’s modeling yielded emissions reductions

that range between a 54% (for the “No IRA” case) and 74%
Source: Prepared by CRS; data from EIA, Annual Energy
reduction (for the “High Uptake” IRA case) in CO2
Outlook 2023.
emissions in the electricity sector in 2035 compared to
Notes: See main report text for further details regarding the
2005 levels.
projected CO2 emissions scenarios and their assumptions.
On May 11, 2023, the U.S. Environmental Protection Agency (EPA) proposed a rule that, if finalized, would ultimately limit
CO2 emissions from both new and existing fossil-fuel-fired electric generating units. The proposed limits vary by the type of
unit, size or capacity of the unit, whether the unit is new or existing, the remaining lifespan of the unit, and the frequency the
unit is used for electricity generation. This proposal is likely to receive considerable attention from policymakers and
stakeholders, and any future final rule is likely to be subject to litigation.
If Congress wishes to further incentivize U.S. GHG emissions reduction, options may include market-based approaches, such
as carbon pricing mechanisms, or regulatory standards for particular facilities or sectors. IRA climate provisions may support
the development of additional policies by reducing the costs of lower-carbon energy sources and technologies. If these
additional policies are implemented, they may help achieve the U.S. 2030 emissions reduction target. On the other hand,
additional policies and regulations are likely to face opposition from some policymakers and stakeholders.
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GHG Emissions in the U.S. Electricity Sector: Background, Policies, and Projections

Introduction
The primary greenhouse gas (GHG)1 emitted by human activities is carbon dioxide (CO2), most
of which is produced through the combustion of fossil fuels. Although fossil fuels have facilitated
economic growth in the United States and around the world, CO2 emissions from fossil fuel
combustion have contributed to an increase in the atmospheric concentration of CO2 of about
40% over the past 150 years.2 According to a 2023 report from the Intergovernmental Panel on
Climate Change (IPCC):
Human activities, principally through emissions of greenhouse gases, have unequivocally
caused global warming.... Continued greenhouse gas emissions will lead to increasing
global warming.... Some future changes are unavoidable and/or irreversible but can be
limited by deep, rapid and sustained global greenhouse gas emissions reduction.3
U.S. GHG emissions levels, particularly from CO2, remain a topic of interest among
policymakers and stakeholders. A wide array of actions that seek to reduce GHG emissions are
under way or being developed by federal governments and subnational entities (e.g., U.S. states
or regional partnerships).4 Federal climate change policies continue to evolve and currently
include a range of activities implemented under various legal authorities, such as the Clean Air
Act.
The 117th Congress enacted two laws, in particular, that include a number of provisions projected
to affect U.S. GHG emissions levels.
1. On November 15, 2021, President Biden signed the Infrastructure Investment and
Jobs Act (IIJA; P.L. 117-58). IIJA is a broad infrastructure law that addressees
multiple economic sectors that produce GHG emissions, including transportation
and energy, among others.5
2. On August 16, 2022, President Biden signed a budget reconciliation measure
commonly referred to as the Inflation Reduction Act of 2022 (IRA; P.L. 117-
169). Each of the eight IRA titles contains some number of provisions that

1 GHGs in the atmosphere trap solar radiation as heat, warming the Earth’s surface and oceans. The primary GHGs
emitted by humans (and estimated by the Environmental Protection Agency in its annual inventories) include carbon
dioxide (CO2), methane (CH4), nitrous oxide (N2O), sulfur hexafluoride, chlorofluorocarbons, hydrofluorocarbons, and
perfluorocarbons.
2 For more information on climate change science, see CRS Report R43229, Climate Change Science: Key Points, by
Jane A. Leggett.
3 Intergovernmental Panel on Climate Change, Synthesis Report of the IPCC Sixth Assessment Report—Summary for
Policymakers, April 2023, at https://www.ipcc.ch/report/ar6/syr/.
4 A number of U.S. states have taken action requiring GHG emissions reductions. For example, a coalition of 11 states
from the Northeast and Mid-Atlantic regions participate in the Regional Greenhouse Gas Initiative, a cap-and-trade
system that took effect in 2009 and applies to CO2 emissions from electric power plants (see CRS Report R41836, The
Regional Greenhouse Gas Initiative: Background, Impacts, and Selected Issues, by Jonathan L. Ramseur). California
established a cap-and-trade program that took effect in 2013. California’s cap covers multiple GHGs, which account for
approximately 85% of California’s GHG emissions. For more details, see the California Air Resources Board website,
at https://www.carb.ca.gov/cc/capandtrade/capandtrade.htm. In addition, Washington State established a cap-and-trade
program comparable to California’s that started in 2023 (see State of Washington Department of Ecology,
“Washington’s Cap-and-Invest Program,” at https://ecology.wa.gov/Air-Climate/Climate-Commitment-Act/Cap-and-
invest).
5 For more details, see CRS Report R47034, Energy and Minerals Provisions in the Infrastructure Investment and Jobs
Act (P.L. 117-58), coordinated by Brent D. Yacobucci.
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directly or indirectly address issues related to climate change, including reduction
of U.S. GHG emissions.6
In addition, on May 11, 2023, the U.S. Environmental Protection Agency (EPA) proposed a rule
that would seek to limit GHG emissions from both new and existing fossil-fuel-fired electric
generating units. This proposal is expected to generate considerable debate among policymakers
and stakeholders and, if finalized, would likely be subject to litigation.
International negotiations continue to generate attention to current and projected U.S. GHG
emissions levels. The United Nations Framework Convention on Climate Change (UNFCCC) is
the principal international treaty to acknowledge and address human-driven climate change. The
United States ratified the treaty in 1992.7 Pursuant to the 2015 Paris Agreement (PA), the second
major subsidiary agreement under the UNFCCC,8 each country must submit a GHG emissions
reduction pledge referred to as a nationally determined contribution (NDC). Targets and actions
pledged in NDCs are nonbinding. Participating countries must update their NDCs every five
years. U.S. NDCs include the following:
• 2015 NDC: reduce net GHG emissions9 by 26%-28% below 2005 levels by
2025; and
• 2021 NDC: reduce net GHG emissions by 50%-52% below 2005 levels by
2030.10
Whether the United States ultimately achieves its GHG emissions targets will likely depend in
part on GHG emissions from electric power plants—one of the largest sources of U.S. GHG
emissions. An understanding of GHG emissions from the electricity sector and the underlying
factors that affect the sector’s emissions levels might help inform the discussion among
policymakers regarding GHG emissions mitigation in the electricity sector and in other sectors of
the economy.
This report examines recent trends in GHG emissions—particularly CO2 emissions—from
electricity generation and the factors that affect emissions levels in that sector. The first section
provides context by including an overview of various sources of GHG emissions in the United
States and a comparison of emissions levels to U.S. emissions reduction pledges. The second
section discusses CO2 emissions from the electricity sector, including sources, recent trends, and
other factors. The third section discusses federal and state policies that address GHG emissions in
the electricity sector, both directly and indirectly. The fourth section provides projections of GHG
emissions in the electricity sector, with a particular focus on the role of recently enacted
legislation. The final section provides concluding observations.

6 For more details, see CRS Report R47262, Inflation Reduction Act of 2022 (IRA): Provisions Related to Climate
Change, coordinated by Jane A. Leggett and Jonathan L. Ramseur; and CRS Report R47385, U.S. Greenhouse Gas
Emissions Trends and Projections from the Inflation Reduction Act, by Jonathan L. Ramseur.
7 U.S. Treaty Number 102-38.
8 See CRS In Focus IF11746, United States Rejoins the Paris Agreement on Climate Change: Options for Congress, by
Jane A. Leggett.
9 Net emissions includes the sum of gross emissions estimates and removal estimates (see text box “Emissions Data in
This Report”).
10 According to the Biden Administration, the 2021 NDC “exceeds a straight-line path to achieve net-zero emissions,
economy-wide, by no later than 2050.” The White House, “The United States of America Nationally Determined
Contribution Reducing Greenhouse Gases in the United States: A 2030 Emissions Target,” April 22, 2021, at
https://www4.unfccc.int/sites/ndcstaging/PublishedDocuments/United%20States%20of%20America%20First/
United%20States%20NDC%20April%2021%202021%20Final.pdf.
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Emissions Data in This Report
This report uses GHG emissions data from two different sources: EPA and the U.S. Energy Information
Administration (EIA). Estimates of total and net GHG emissions (“economy-wide”) come from EPA’s annual GHG
emissions inventory. These estimates provide a big-picture view of U.S. GHG emissions levels and GHG emissions
sources, particularly in the context of recent GHG emissions reduction goals. EPA released the most recent
version of its inventory in April 2023. This version includes GHG emissions data through 2021.
Although EPA’s inventory includes CO2 emissions, this report generally uses CO2 emissions data from EIA,
because EIA’s CO2 emissions data are released on a monthly basis, including annual numbers for 2022. This allows
for more recent comparisons of trends in electricity-sector emissions and related topics. CO2 emissions have
historically accounted for approximately 80% of total U.S. GHG emissions. A comparison of recent CO2 emissions
data from EPA and EIA reveals that their values vary by approximately 1%. Moreover, changes in U.S. GHG
emissions levels are largely due to changes in U.S. CO2 emissions levels. The fluctuations in CO2 emissions in EIA's
reports generally track with the annual percentage changes in total GHG emissions from EPA's inventories. Non-
CO2 GHG emissions (provided in EPA’s inventory) have remained relatively constant during that time frame.
GHG emissions are typically measured in tons of CO2-equivalent. This unit of measure is used because GHGs vary
by global warming potential (GWP). GWP is an index developed by the IPCC that allows comparisons of the heat-
trapping ability of different gases over a period of time, typically 100 years. Consistent with international GHG
reporting requirements, EPA’s most recent GHG inventory uses the GWP values presented in the IPCC’s 2013
Fifth Assessment Report. For example, based on these GWP values, a ton of methane is 28 times more potent than
a ton of CO2 when averaged over a 100-year time frame. The IPCC has since updated the 100-year GWP
estimates, with some increasing and some decreasing. For example, the IPCC 2021 Sixth Assessment Report
reported the 100-year GWP for methane as 27.
Gross emissions refer to total emissions from all sources. This value does not account for removals of CO2
emissions from the atmosphere by emission sinks, such as forests, vegetation, and soils. U.S. sinks removed about
754 mil ion metric tons (MMT) in 2021, about 12% of gross U.S. emissions.11 Net emissions include the sum of
gross emissions estimates and removal estimates. The U.S. nationally determined contribution (NDC) is measured
in terms of net emissions.
Historical U.S. GHG Emissions and Recent Trends
GHG emissions data and trends can be presented in several ways, with each presentation
providing a different perspective. The GHG emissions in EPA’s inventory and in this report
generally involve annual emissions levels. Other GHG emissions measures include cumulative
GHG emissions, GHG emissions intensities (e.g., emissions per a monetary value, such as gross
domestic product), and GHG emissions per capita. The following sections discuss recent U.S.
emissions levels and trends, the sources of U.S. GHG emissions, and how these sources have
changed in recent years.
U.S. GHG Emissions and Reduction Pledges
Figure 1 illustrates net U.S. GHG emissions between 1990 and 2022. As the figure indicates,
U.S. GHG emissions increased 20% between 1990 and 2007 and have generally decreased since
that time. As discussed below, a range of factors have played a role in this downward trend,
including the evolving electricity generation portfolio, technological developments, and relatively
short-term economic conditions. For example, the economic downturn in 2008 and 2009 resulted
in a decrease of energy consumption (including electricity) across all economic sectors. This
decline played a key role in the 10% decrease in emissions levels during that time. Over the next
10 years (2010 through 2019), annual emissions levels fluctuated with a downward trend,
ultimately decreasing by 7%. Between 2019 and 2020, emissions decreased by 9%, accounting

11 EPA, Inventory of U.S. Greenhouse Gas Emissions and Sinks, 2023, at https://www.epa.gov/ghgemissions/inventory-
us-greenhouse-gas-emissions-and-sinks.
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for the largest annual decline in EPA’s inventory history. According to EPA, the decrease was
“largely due to the impacts of the coronavirus (COVID-19) pandemic on travel and economic
activity.”12 In 2021, GHG emissions rebounded, increasing by 6%. Based on more recent CO2
emissions data from EIA, CRS estimates that total GHG emissions will increase by 1% between
2021 and 2022, which will still be below prepandemic levels.13
In addition, Figure 1 compares U.S. GHG emissions (including the estimate for 2022) and the
NDC pledges for 2025 and 2030 and President Biden’s goal to achieve net-zero emissions in
2050. As the figure indicates, the estimated 2022 emissions were 16% below 2005 levels.
Recent analyses from groups in the private sector, academia, and the federal government have
used computer simulation models to prepare estimates of U.S. net GHG emissions through 2030.
The results of these projections indicate U.S. net GHG emissions would decrease by 30% to 43%
by 2030 compared with 2005 levels, thus not meeting the 2030 reduction target.14
Figure 1. Historical U.S. GHG Net Emissions Compared with U.S. Emissions Targets

Source: Prepared by CRS; actual U.S. GHG emissions from EPA, Inventory of U.S. Greenhouse Gas Emissions and
Sinks: 1990–2021, April 2023. See “Emissions Data in This Report” textbox for further details.
Notes: NDC = nationally determined contribution pursuant to the United Nations Framework Convention on
Climate Change (UNFCCC) Paris Agreement. MMTCO2e = mil ion metric tons of CO2 equivalent. This measure
is used because GHGs vary by global warming potential (GWP). GWP is an index that allows comparisons of the
heat-trapping ability of different gases over a period of time. The GHG emissions in the figure are net GHG
emissions. Net GHG emissions account for removals of CO2 emissions from the atmosphere by emission sinks,
such as forests, vegetation, and soils. The U.S. NDC is measured in terms of net emissions.
CRS calculated the 2022 U.S. GHG emissions estimate based on CO2 data from EIA. EIA provides energy-related
CO2 emissions on a more up-to-date schedule than EPA’s inventory, which includes GHGs from all sources. The
CO2 emissions in EIA’s reports account for approximately 80% of total U.S. GHG emissions, and their
fluctuations generally track with the annual percentage changes in total GHG emissions from EPA’s inventories.
EIA data indicate that CO2 emissions from the energy sector increased by 1% between 2021 and 2022. CRS
applied this percentage increase to total net GHG emissions in 2021, resulting in an estimate of 5,642 MMTCO2e

12 EPA, Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990-2020, 2022.
13 For more details on this estimate, see the “Notes” in Figure 1.
14 For more details and discussion, see CRS Report R47385, U.S. Greenhouse Gas Emissions Trends and Projections
from the Inflation Reduction Act, by Jonathan L. Ramseur.
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in 2022. EIA, Monthly Energy Review, Table 11.1, March 2023, at https://www.eia.gov/totalenergy/data/monthly/
#environment.
U.S. GHG Emissions Sources
GHG emissions are produced throughout the United States from millions of discrete sources:
power plants, industrial facilities, vehicles, households, commercial buildings, and agricultural
activities (e.g., soils and livestock).15 Figure 2 illustrates the breakdown of U.S. GHG emissions
by gas and type of source. The figure indicates that CO2 from the combustion of fossil fuels—
petroleum, coal, and natural gas—accounted for 73% of total U.S. GHG emissions in 2021. This
contribution has decreased in recent years; in 2012, CO2 from the combustion of fossil fuels
accounted for 78% of total GHG emissions.16
Figure 2. U.S. GHG Emissions by Source and Gas
2021 Data Reported in Metric Tons of CO2-Equivalent

Source: Prepared by CRS; data from EPA, Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990–2021, April
2023. See “Emissions Data in This Report” textbox for further details.
Notes: N2O is nitrous oxide. The “Various GHGs—other sources” category includes the fol owing:
Methane (CH4) from livestock (3%); hydrofluorocarbons released during the production of ozone-depleting
substances (3%); CO2 from nonenergy fuel uses (2%); CH4 from landfil s (2%); CO2 from iron and steel
production (1%); CH4 from coal mines (1%); and CH4 from manure management (1%). Multiple smal er sources
account for the remaining 6%. These percentages may not add up precisely due to rounding.
U.S. GHG Emissions by Economic Sector
Another common method of reporting GHG emissions is by sector. Figure 3 illustrates the GHG
emissions by sector between 1990 and 2021. As the figure indicates, GHG emissions in the
electric power sector historically accounted for the largest percentage of total U.S. GHG
emissions. However, starting in 2005, GHG emissions in the electricity sector began to decrease.
Between 2005 and 2021, electricity sector emissions decreased by 36%. By comparison,
emissions in the transportation and industrial sectors decreased by 8% and 6%, respectively,

15 GHG emissions are also released through a variety of natural processes such as methane emissions from wetlands.
This report focuses on human-related (anthropogenic) GHG emissions.
16 Based on comparable data from EPA’s GHG Inventory, released in 2014.
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during this time frame. Since 2017, emissions in the transportation sector have surpassed
emissions in the electricity sector.
Figure 3. U.S. GHG Emissions by Sector
1990-2021

Source: Prepared by CRS; data from EPA, Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990–2021, April
2023. See “Emissions Data in This Report” textbox for further details.
Electricity Sector Emissions: Context and Trends
As discussed above, CO2 emissions from the combustion of fossil fuels account for 73% of all
U.S. GHG emissions. The electric power sector contributes the second-largest percentage (31%)
of CO2 emissions from fossil fuel combustion (six percentage points less than the transportation
sector). This section provides further background and context regarding GHG emissions in the
electricity sector.
Electricity Generation Levels and Emissions
Figure 4 compares U.S. electricity generation with CO2 emissions from the electricity sector
between 1973 and 2021. As the figure illustrates, U.S. electricity generation generally increased
between 1973 and 2007 and then decreased in 2008 and 2009. Historically, CO2 emissions from
electricity generation followed a similar course. However, in 2010, these trends decoupled. While
electricity generation generally remained flat after 2010, CO2 emissions continued a general trend
of reduction. Thus in 2021, electricity generation was 5% higher than generation in 2005, while
CO2 emissions were 36% below 2005 levels—equivalent to electricity sector CO2 emission levels
in 1983.
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Figure 4. Electricity Generation and CO2 Emissions from U.S. Electricity Sector
1973-2021

Source: Prepared by CRS; data from EIA, Monthly Energy Review, Table 7.2 (net electricity generation) and Table
11.6 (emissions), at https://www.eia.gov/totalenergy/data/monthly/.
Notes: Electricity generation in this figure is annual, net electricity generation from all sources, measured in
gigawatt hours.
The decrease in CO2 emissions in the electricity sector over the past 15 years was a result of
several factors, including changes in the electricity generation portfolio (discussed below),
technology developments, weather variability,17 and overall U.S. economic conditions, typically
measured in terms of the U.S. gross domestic product (GDP). Historically, annual U.S. GDP
decreases are a relatively uncommon occurrence; the United States has seen an annual decrease in
GDP seven times over the past 50 years. The 2.6% GDP decrease in 2009 and 2.8% decrease in
2020 were the two largest GDP decreases during that time frame.18 These economic downturns
resulted in decreases in energy consumption (including electricity) across all economic sectors.

17 See, for example, EIA, “Record U.S. Electricity Generation in 2018 Driven by Record Residential, Commercial
Sales,” 2019, at https://www.eia.gov/todayinenergy/detail.php?id=38572.
18 Bureau of Economic Analysis, “National Data, National Income and Product Accounts,” Table 1.1.1. Percent
Change From Preceding Period in Real Gross Domestic Product, at https://apps.bea.gov.
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Role of Electricity Generation Portfolio
A primary factor affecting CO2 emissions levels in the electricity sector is the electricity
generation portfolio. Electricity is generated from a variety of sources in the United States. Some
sources—nuclear, hydropower, and some renewables—directly produce no CO2 emissions when
used for electricity generation. Fossil fuels emit different amounts of CO2 emissions per unit of
electricity generated (often described as carbon intensity). Figure 5 illustrates the relative
comparison of CO2 emissions per unit of electricity produced from coal, petroleum, and natural
gas. As the figure indicates, petroleum-fired electricity produces approximately 80% of the CO2
emissions of coal-fired electricity per kilowatt-hour of electricity. Natural-gas-fired electricity
from a steam generation unit produces approximately 60% of the CO2 emissions of coal-fired
electricity per kilowatt-hour of electricity. Natural-gas-fired electricity from a combined cycle
unit produces approximately 43% of the CO2 emissions of coal-fired electricity per kilowatt-hour
of electricity. Therefore, a shift in the carbon intensity of the U.S. electricity generation portfolio
(all else being equal) would likely have an impact on emissions from the electricity sector, which
in turn, would affect total U.S. GHG emissions.
Figure 5. Comparison of Fossil Fuels’ Carbon Intensity in Electricity Generation

Source: Prepared by CRS; data from EIA, “How Much Carbon Dioxide Is Produced per Kilowatthour When
Generating Electricity with Fossil Fuels?” at https://www.eia.gov/tools/faqs/faq.php?id=74&t=11.
Notes: Carbon content values are derived by multiplying the fuel’s CO2 emissions factor by the heat rate of a
particular electric generating unit. In this figure, CRS used the coal emissions factor for bituminous coal and the
petroleum emissions factor measure for distil ate oil (Number 2 fuel oil). Natural gas has only one emissions
factor. The heat rates of different electricity unit types can vary substantially. CRS used EIA’s average steam
generation value for coal, petroleum, and natural gas, as well as the average combined cycle value for natural gas.
The above comparison does not account for the so-called life-cycle emissions associated with the energy supply
chain (e.g., fugitive methane emissions from natural gas production). For more information, see CRS Report
R44090, Life-Cycle Greenhouse Gas Assessment of Coal and Natural Gas in the Power Sector, by Richard K. Lattanzio.
Figure 6 illustrates the percentage of electricity generated by source between 2005 and 2022. As
the figure indicates, the U.S. electricity generation portfolio has changed considerably. During
this time frame (2005-2022), highlights include the following:
• Coal-fired generation decreased by 59%. Its contribution to total electricity
generation decreased from 50% to 19%.
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• Natural-gas-fired generation increased by 122%. Its contribution to total
electricity generation increased from 19% to 39%. In 2016, natural gas
surpassed coal in terms of percentage of total generation.
• Non-hydro renewable energy generation—mainly wind and solar—increased by
645% (a seven-fold increase). Its contribution to total electricity generation
increased from 2% to 17%.
Figure 6. Percentage of Total Electricity Generation by Energy Source
2005-2022

Source: Prepared by CRS; data from EIA, Electric Power Monthly, Table 1.1, at http://www.eia.gov/beta/epm/.
Notes: Renewable sources include wind, utility scale and distributed solar, wood fuels, landfil gas, biogenic
municipal solid waste, other biomass, and geothermal. Petroleum includes petroleum liquids and petroleum coke.
EIA began to col ect estimates for distributed solar in 2014. Electricity generation in this figure is annual, net
electricity generation from all sources, measured in gigawatt hours.
Several factors played a role in these recent changes. Due in large part to technological advances,
particularly directional drilling and hydraulic fracturing,19 U.S. natural gas production increased
by 98% between 2005 and 2022.20 Relatedly, the weighted average annual price of natural gas
dropped by about 13% between 2005 and 2021. By comparison, the weighted average annual coal
price increased by about 46% during that time frame.21 This change in relative fuel prices has
played a key role in altering the economics of power generation, leading to considerable natural
gas displacement of coal in particular regions of the country.22 These market forces have played a

19 Hydraulic fracturing is an industry technique that uses water, sand, and chemicals under pressure to enhance the
recovery of natural gas and oil from certain geologic formations. It has taken on new prominence as it has been applied
to tight oil and shale gas formations as an essential method for resource extraction. See CRS Report R45988, U.S.
Natural Gas: Becoming Dominant, by Michael Ratner.
20 EIA, “U.S. Dry Natural Gas Production,” at http://www.eia.gov/dnav/ng/hist/n9070us2a.htm.
21 EIA, Electric Power Annual, Table 7.4, at https://www.eia.gov/electricity/annual/html/epa_07_04.html.
22 For more discussion, see CRS Report R47521, Electricity: Overview and Issues for Congress, by Ashley J. Lawson.
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role in the retirement of coal-fired electric power plants: Between 2006 and 2021, the number of
U.S. coal-fired power plants decreased from 616 to 269.23
Figure 7 provides a more detailed breakdown of the changes in generation from renewable
energy sources, not including hydroelectricity. The majority of the increased generation from
renewable energy over the past 14 years has been from wind power, which increased 24-fold
between 2005 and 2022.
Figure 7. Percentage of Total Electricity Generation from Renewable Energy Sources
(Not Including Hydroelectricity)
2005-2022

Source: Prepared by CRS; data from EIA, Electric Power Monthly, Table 1.1A, at https://www.eia.gov/electricity/
monthly/.
Notes: Utility-scale and small-scale solar generation (e.g., rooftop solar on commercial building and residences)
are counted separately, because EIA began to provide estimates for small-scale solar in 2014. Including both
utility data and small-scale estimates would increase the percentage of solar generation in 2022 from 3.4% to
4.8%. The “other” category includes landfil gas, biogenic municipal solid waste, other biomass, and geothermal
sources. Electricity generation in this figure is annual, net electricity generation from all sources, measured in
gigawatt hours.
The figure also provides estimates of small-scale solar generation (e.g., rooftop solar on
commercial building and residences).24 In 2014, EIA began to provide estimates for small-scale
solar generation, which has increased five-fold since that time. Including both utility data and

23 EIA, Electric Power Annual, Table 4.1, 2022, at https://www.eia.gov/electricity/annual/. This includes electric
utilities, independent power producers, and plants in the commercial and industrial sectors.
24 For more information on solar energy, see CRS Report R46196, Solar Energy: Frequently Asked Questions,
coordinated by Ashley J. Lawson.
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small-scale estimates would increase the percentage of solar generation in 2022 from 3.4% to
4.8%.
Energy from wood fuels has remained relatively constant during this time frame. Although the
total percentage of electricity from “other” renewable sources has remained relatively constant,
the use of landfill gas increased by 75% between 2005 and 2022.
Policies Addressing Electricity Sector Emissions
Policymaking entities in the United States—Congress, federal agencies, state and local
governments—have proposed and established a variety of climate change policy approaches.
Many GHG emissions reduction programs at the state levels (e.g., the Regional Greenhouse Gas
Initiative) and federal legislative proposals have focused on CO2 emissions from the electricity
generation sector due to the sector’s large GHG emissions contribution and the relatively limited
number of emissions sources.25 As discussed below, enacted legislation in the 117th Congress
included provisions that seek to reduce CO2 emissions in the electricity sector, among other
sectors.
Federal Policies26
Federal climate policies have involved a range of activities implemented under various legal
authorities that have influenced emissions in a range of sectors. These activities have included
regulatory standards, tax incentives, data gathering and reporting, and financial support for GHG
mitigation technologies.
A 2007 Supreme Court decision established one of the key underpinnings of the federal GHG
policy landscape. In Massachusetts v. EPA, the Court ruled that EPA has authority under the Clean
Air Act to regulate GHG emissions from motor vehicles as air pollutants. At that time, the
decision led to a shift in federal policies toward more direct regulation of GHG emissions,
including emissions in the electricity sector.
Clean Power Plan and Affordable Clean Energy Rulemakings
Executive branch policies and actions addressing U.S. GHG emissions typically reflect the policy
objectives of the Administration at the time. Both the Obama and Trump Administrations issued
EPA rulemakings that would regulate GHG emissions from power plants. These include the 2015
Clean Power Plan (CPP)27 and the 2019 Affordable Clean Energy (ACE)28 rulemakings. These

25 See CRS Report R45472, Market-Based Greenhouse Gas Emission Reduction Legislation: 108th Through 117th
Congresses, by Jonathan L. Ramseur; and CRS In Focus IF11316, A Brief History of U.S. Electricity Portfolio
Standard Proposals, by Ashley J. Lawson.
26 For more details regarding the history of federal climate change policies, see CRS Report R46947, U.S. Climate
Change Policy, coordinated by Richard K. Lattanzio.
27 During the Obama Administration, the U.S. Environmental Protection Agency (EPA) promulgated a final rule for
CO2 emissions from existing fossil-fuel-fired electric power plants (EPA, “Carbon Pollution Emission Guidelines for
Existing Stationary Sources: Electric Utility Generating Units,” Final Rule, 80 Federal Register 64661, October 23,
2015). In 2017, President Trump issued an executive order that directed EPA to review the CPP (and other
rulemakings) and “as soon as practicable, suspend, revise, or rescind the guidance, or publish for notice and comment
proposed rules suspending, revising, or rescinding those rules.”
28 In a July 2019 final rulemaking, EPA repealed the CPP and replaced it with new emissions guidelines for coal-fired
power plants, known as the Affordable Clean Energy (ACE) rule (EPA, “Repeal of the Clean Power Plan; Emission
Guidelines for Greenhouse Gas Emissions From Existing Electric Utility Generating Units; Revisions to Emission
Guidelines Implementing Regulations,” 84 Federal Register 32520, July 8, 2019).
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rulemakings, and related efforts that followed, generated considerable interest and controversy.
Both the CPP and ACE rules were the subject of extensive litigation, ultimately involving the
Supreme Court.29 On June 30, 2022, the Supreme Court decided West Virginia v. EPA, and held
that the EPA exceeded its authority under the CAA in its 2015 CPP rule.30 Under that decision,
EPA retains the ability to regulate GHG emissions from power plants and other sources, but it
now faces more constraints in how it regulates those emissions.31 As a result of this decision, the
ACE rule, which had been previously vacated, was reinstated in October 2022.32 Although the
ACE rule is in effect, EPA has extended its implementation deadlines, “making it clear that states
are not expected to take immediate action.”33 EPA proposed to repeal the ACE rule in its 2023
rulemaking, discussed below.
In addition, a related 2015 final rule establishing GHG emissions standards for new fossil-fuel-
fired utility boilers and natural-gas-fired stationary combustion turbines remains in place. The
New Source Performance Standard for new and modified power plants relies in part on carbon
capture and sequestration (CCS) technology to reduce emissions by about 20% compared with
the emissions of what was considered (at the time of the rule) a state-of-the-art coal-fired plant
without CCS.34
2023 Proposed Rule for Coal- and Gas-Fired Electric Power Plants
On May 11, 2023, the EPA proposed a rule that would seek to limit GHG emissions from both
new and existing fossil-fuel-fired electric generating units.35 The proposed limits vary by the type

29 A comprehensive discussion of the history and factors that have played a role in the development of these rules is
beyond the scope of this report. For more background on these legal developments, see CRS Legal Sidebar LSB10791,
Supreme Court Addresses Major Questions Doctrine and EPA’s Regulation of Greenhouse Gas Emissions, by Kate R.
Bowers.
30 See CRS Legal Sidebar LSB10791, Supreme Court Addresses Major Questions Doctrine and EPA’s Regulation of
Greenhouse Gas Emissions, by Kate R. Bowers.
31 Ibid.
32 For a more detailed discussion of these developments, see the section “D.C. Circuit Order to Reinstate the ACE
Rule” in EPA’s 2023 Proposed Rule, discussed below.
33 EPA, “Greenhouse Gas Standards and Guidelines for Fossil Fuel-Fired Power Plants Proposed Rule,” Factsheet,
2023, at https://www.epa.gov/stationary-sources-air-pollution/greenhouse-gas-standards-and-guidelines-fossil-fuel-
fired-power.
34 See EPA, “Standards of Performance for Greenhouse Gas Emissions from New, Modified, and Reconstructed
Stationary Sources: Electric Utility Generating Units,” 80 Federal Register 64509, October 23, 2015.
For more background on CCS, see CRS Report R44902, Carbon Capture and Sequestration (CCS) in the United
States, by Angela C. Jones and Ashley J. Lawson.
35 EPA, “New Source Performance Standards for Greenhouse Gas Emissions from New, Modified, and Reconstructed
Fossil Fuel-Fired Electric Generating Units; Emission Guidelines for Greenhouse Gas Emissions from Existing Fossil
Fuel-Fired Electric Generating Units; and Repeal of the Affordable Clean Energy Rule” (hereinafter “2023 Proposal”).
The EPA Administrator signed the proposed rule on May 8, 2023. The version released on May 11, 2023, is an
unofficial version that has not been published in the Federal Register. The text of the proposal and supporting
documents are available at https://www.epa.gov/stationary-sources-air-pollution/greenhouse-gas-standards-and-
guidelines-fossil-fuel-fired-power.
Leading up to the proposal, EPA solicited “pre-proposal” outreach (in September 2022) with questions for stakeholders
regarding its strategy to address CO2 emissions from existing fossil-fuel-fired power plants. See EPA, “Pre-Proposal
Public Docket: Greenhouse Gas Regulations for Fossil Fuel-fired Power Plants,” at https://www.epa.gov/stationary-
sources-air-pollution/pre-proposal-public-docket-greenhouse-gas-regulations-fossil-fuel; and EPA, “Questions for
Consideration,” at https://downloads.regulations.gov/EPA-HQ-OAR-2022-0723-0002/content.pdf.
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of unit (e.g., coal or natural gas), size or capacity of the unit, whether the unit is new or existing,
the remaining lifespan of the unit, and the frequency the unit is used for electricity generation.36
For example, the limits for existing coal-fired units would apply on January 1, 2030. The limits
for units that plan to operate after 2039 are based on a 90% rate of carbon capture and
sequestration (CCS).37 Existing coal-fired units that make a federally enforceable commitment to
cease operations before 2040 have less-stringent emissions limitations. For these units, the limits
are based on substituting natural gas for coal (referred to as “co-firing”) at a rate of 40%, which
EPA states would equate to a 16% reduction in the unit’s emission rate (measured in tons of CO2
emissions per megawatt hour of electricity generation).38
For existing natural-gas-fired combustion units with relatively large capacities that operate on a
frequent basis,39 EPA proposes an emissions limit based on either (1) the use of CCS by 2035 or
(2) co-firing with low-GHG hydrogen40 at a rate of 30% by 2032 and a rate of 96% by 2038. EPA
proposes a revised framework for new gas-fired units that varies based on the unit’s capacity and
frequency of operation. The new source standards for the larger, baseload units are similar to the
proposed limits for existing natural gas-fired units of comparable size and operating frequency.41
EPA proposes these emissions limits pursuant to authorities in the Clean Air Act. Under this
statutory framework, the states establish, implement, and enforce the standards proposed by EPA.
EPA proposes several compliance options that states can choose to adopt, including emissions
trading or state-wide averaging of emissions. EPA notes that states must ensure that use of these
compliance flexibilities will result in a level of emission performance that is equivalent to each
source individually achieving its standard of performance.42
This proposal is likely to receive considerable attention from policymakers and stakeholders. This
rulemaking would follow from the legal developments with the CPP and ACE rules. As with
those rulemakings, any future final rule based on the May 2023 proposal is likely to be subject to
litigation. Therefore, its ultimate fate and potential effects are uncertain. If the rule were finalized
and allowed to go into effect, the rule’s potential implementation and effect on emissions would
not operate in a policy vacuum; it would be influenced by a range of other state and federal
policies, including climate-related provisions enacted in recent legislation, particularly the
Inflation Reduction Act (discussed below).

36 Some electric generating units produce “base load power,” which means the unit typically operates throughout all
hours of the year. In contrast, “peaking units” operate only during certain times of the day, week, or year to meet the
fluctuating demand from users.
37 EPA states this would reduce CO2 emissions from these units by 88.4%. 2023 Proposal, p. 22.
38 Coal-fired units that commit to permanently cease operations by December 31, 2034, and operate at 20% capacity,
are subject to the same emissions limit.
39 This includes units with a capacity greater than 300 megawatts with a “capacity factor” of 50% or more. A capacity
factor is a measure of how much a unit operates relative to how much it could potentially operate. See 2023 Proposal,
p. 306.
40 EPA proposes a definition for low-GHG hydrogen that aligns with the highest of the four tiers of tax credit available
for hydrogen production in the Internal Revenue Code (IRC) Section 45V(b)(2)(D). This tax credit was created by IRA
(discussed below). In addition, EPA proposes to adopt the Department of the Treasury’s eligibility, monitoring,
verification, and reporting protocols for IRC Section 45V (see 2023 Proposal, p. 333).
41 These units are currently subject EPA’s 2015 final rule establishing GHG emissions standards for new fossil-fuel-
fired utility boilers and natural-gas-fired stationary combustion turbines. See EPA, “Standards of Performance for
Greenhouse Gas Emissions from New, Modified, and Reconstructed Stationary Sources: Electric Utility Generating
Units,” 80 Federal Register 64509, October 23, 2015.
42 2023 Proposal, p. 575.
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State and Local Policies
Authority over the electricity generation profile currently resides primarily in the states.43 Some
state and local governments have taken a variety of actions—both legal mandates and voluntary
efforts—for approximately 20 years. Selected examples of currently implemented policies in the
electricity sector include the following:44
• California and Washington implement a GHG emissions cap-and-trade program
that covers electric power, selected industries, and fossil fuel distributors.45
• Eleven U.S. states participate in the Regional Greenhouse Gas Initiative
(RGGI),46 a cap-and-trade program that covers CO2 emissions from electric
power.
• Thirty states, three U.S. territories, and the District of Columbia require a
minimum amount of electricity generation by low- or non-emitting energy
sources such as renewables.47
• Governors from 23 states and Puerto Rico announced a commitment to reduce
net GHG emissions from their states by at least 50%-52% below 2005 levels by
2030 and to achieve net-zero GHG emissions no later than 2050.48
Climate Change Legislation
Historically, Members of Congress have expressed various perspectives regarding climate change
issues. Members seeking to limit GHG emissions from the electricity sector (and other sectors)
have considered a range of policy options, including
• carbon pricing frameworks (e.g., carbon taxes or cap-and-trade programs);49

43 For an overview of the current regulatory framework for the electricity sector, see CRS Report R47521, Electricity:
Overview and Issues for Congress, by Ashley J. Lawson.
44 Seventeen states have adopted California’s more stringent vehicle emissions standards, and 45 states and the District
of Columbia provide incentives for electric vehicles, hybrids, or both. California Air Resources Board, “Low Emissions
Vehicle Program,” at https://ww2.arb.ca.gov/our-work/programs/low-emission-vehicle-program. In addition, the
California Air Resources Board adopted regulations in August 2022 to phase out the sale of conventional gas-powered
vehicles by 2035. New York, Washington, and Massachusetts have similar requirements in various stages of
development. The regulations were sent to the state’s Office of Administrative Law, which will make a determination
by November 22, 2022 (see California Air Resources Board, “Advanced Clean Cars II,” at https://ww2.arb.ca.gov/
rulemaking/2022/advanced-clean-cars-ii).
45 For more information, see the California Air Resources Board website at https://ww2.arb.ca.gov/our-work/programs/
cap-and-trade-program. Washington State established a comparable cap-and-trade program that started in 2023 (see
State of Washington Department of Ecology, “Washington’s Cap-and-Invest program,” at https://ecology.wa.gov/Air-
Climate/Climate-Commitment-Act/Cap-and-invest).
46 The Regional Greenhouse Gas Initiative (RGGI) states are Connecticut, Delaware, Maine, Maryland, Massachusetts,
New Hampshire, New Jersey, New York, Rhode Island, Virginia, and Vermont.
47 Database of State Incentives for Renewables & Efficiency, “Renewable & Clean Energy Standards,” at
https://s3.amazonaws.com/ncsolarcen-prod/wp-content/uploads/2019/07/RPS-CES-June2019.pdf.
48 The degree to which state and local governments can achieve these targets without federal action is uncertain, as the
legal authorities and jurisdictions over GHG emissions sources may be limited. U.S. Climate Alliance, “U.S. Climate
Alliance Commits to Achieve Net-Zero Emissions No Later than 2050,” press release, April 23, 2021, at
https://www.usclimatealliance.org/publications/newtargets.
49 For more information, see CRS Report R45472, Market-Based Greenhouse Gas Emission Reduction Legislation:
108th Through 117th Congresses, by Jonathan L. Ramseur.
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• clean energy standard;50
• research funding or tax policies that support low-emissions technologies; and
• creation of publicly funded entities to facilitate private investment into domestic
low-carbon, climate-resilient infrastructure (i.e., green banks).
Other legislative approaches have sought to prohibit certain approaches. For example, a number
of congressional resolutions introduced in recent years have stated that multisector carbon pricing
approaches are not in the economic interests of the United States.51 In addition, some Members
have introduced bills that would limit the authority to regulate GHG emissions under the Clean
Air Act.
Votes on comprehensive climate change policy have been relatively rare in either chamber of
Congress.52 Prior to the 117th Congress, examples of enacted legislation involving climate change
mitigation in the electricity sector included tax incentives to promote renewable energy sources
and carbon capture and sequestration efforts.53 During the 117th Congress, both President Biden
and majority leadership in the House and the Senate called for comprehensive approaches to
address climate change. The following sections focus on two enacted legislative measures in the
117th Congress: IIJA and the budget reconciliation measure commonly referred to as the Inflation
Reduction Act, or IRA. These acts include provisions that are likely to have direct or indirect
effects on GHG emissions levels, particularly the provisions in IRA.
Infrastructure Investment and Jobs Act (IIJA)
On November 15, 2021, President Biden signed the IIJA (P.L. 117-58). IIJA is a broad
infrastructure law that addresses a range of sectors, including the electricity sector.54 IIJA
provisions involve a number of issues that may affect GHG emissions from the electricity sector,
including the following:
• energy efficiency and renewable energy;
• electric grid reliability, resilience, and cybersecurity;
• carbon capture, utilization, and storage;
• hydrogen research and development;
• nuclear energy;

50 For more information on clean energy standards and related policies, see CRS Report R45913, Electricity Portfolio
Standards: Background, Design Elements, and Policy Considerations, by Ashley J. Lawson.
51 For example, from the 112th Congress through the 115th Congress, Members introduced resolutions in both the House
and Senate expressing the view that a carbon tax is not in the economic interests of the United States. In 2016 and
2018, the House passed resolutions “expressing the sense of Congress that a carbon tax would be detrimental to the
United States economy” (H.Con.Res. 89 and H.Con.Res. 119, respectively). In the 117th Congress, during debate on
S.Con.Res. 5, the Senate voted (50-50, not agreed to) on S.Amdt. 887, which would have established “a deficit-neutral
reserve fund relating to prohibiting a Federal carbon tax.”
52 One example is H.R. 2454, the American Clean Energy and Security Act of 2009 (“Waxman-Markey”), in the 111th
Congress, which would have established an economy-wide cap-and-trade system to reduce GHG emissions. The House
passed H.R. 2454 in 2009. Companion legislation in the Senate, S. 1733, was reported from the Committee on
Environment and Public Works; the bill was not brought up for consideration on the Senate floor.
53 For more information on the energy tax incentives available before the 117th Congress, see CRS Report R46865,
Energy Tax Provisions: Overview and Budgetary Cost, by Molly F. Sherlock.
54 IIJA provisions include climate mitigation policies and programs in surface transportation with increased funding for
public transportation and intercity passenger rail. For more details, see CRS In Focus IF11921, Surface Transportation
and Climate Change: Provisions in the Infrastructure Investment and Jobs Act (P.L. 117-58), by William J. Mallett.
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• battery manufacturing, recycling, and critical minerals; and
• fossil energy programs.55
A number of studies have estimated the impact of IIJA on GHG emissions. For example, a 2022
study from Princeton University estimated that U.S. emissions would decrease to 26% below
2005 levels without IIJA and 27% below 2005 levels with IIJA.56 This analysis did not include
potential effects (e.g., changes in passenger and freight miles traveled) from IIJA funding for
transportation, rail, and public transit. However, a 2021 analysis from the Georgetown Climate
Center concluded that the emissions effects from the IIJA transportation provisions are uncertain
and could result in an increase or decrease in emissions. This analysis concluded emissions
effects would depend on implementation and funding decisions made by state, federal, and local
governments.57
Inflation Reduction Act (IRA)
On August 16, 2022, President Biden signed H.R. 5376 (P.L. 117-169), the budget reconciliation
measure commonly referred to as the Inflation Reduction Act of 2022 (IRA). The eight titles in
IRA address a range of issues, including climate change matters, among other policy objectives.
Each of the titles contains some number of provisions that directly or indirectly address issues
related to climate change, including reduction of U.S. GHG emissions.58 Several IRA sections
would influence GHG emissions in the electricity sector, including provisions that
• modify, extend, or provide new tax credits for electricity from “clean” and
renewable resources, alternative fuels, energy efficiency, and clean vehicles;59
• provide funding for energy efficiency projects;
• provide funding for low-emissions fuels and technologies;
• provide funding for energy rebates and efficiency, electricity transmission,
industrial and energy infrastructure;
• provide funding to support zero-emissions technologies in low-income areas;
• provide funding for a tribal electrification program.
Several recent analyses from groups in the private sector, academia, and the federal government
used computer simulation models to prepare estimates of U.S. net GHG emissions through 2030.
Figure 8 illustrates these results. These models compare baseline scenarios with emissions
scenarios that include IRA. Based on the results from these models, IRA’s climate change
provisions are likely to result in net GHG emissions reductions as compared to emissions

55 For more details on the energy provisions, see CRS Report R47034, Energy and Minerals Provisions in the
Infrastructure Investment and Jobs Act (P.L. 117-58), coordinated by Brent D. Yacobucci.
56 Princeton University REPEAT, Preliminary Report: The Climate and Energy Impacts of the Inflation Reduction Act
of 2022, August 2022, at https://repeatproject.org/docs/REPEAT_IRA_Prelminary_Report_2022-09-21.pdf.
57 Georgetown Climate Center, “Issue Brief: Estimating the Greenhouse Gas Impact of Federal Infrastructure
Investments in the IIJA,” December 2021, at https://www.georgetownclimate.org/articles/federal-infrastructure-
investment-analysis.html.
58 For more details on the climate-change-related provisions of the budget reconciliation measure commonly referred to
as the Inflation Reduction Act of 2022 (IRA), see CRS Report R47262, Inflation Reduction Act of 2022 (IRA):
Provisions Related to Climate Change, coordinated by Jane A. Leggett and Jonathan L. Ramseur.
59 For more information on these tax provisions, see CRS Report R47202, Tax Provisions in the Inflation Reduction Act
of 2022 (H.R. 5376), coordinated by Molly F. Sherlock.
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scenarios without IRA.60 The projected results in the figure indicate that even though U.S. net
GHG emissions will decrease by 30% to 43% by 2030 including provisions in the IRA compared
with 2005 levels, they still would not meet the U.S. 2030 reduction target.
Figure 8. Net U.S. GHG Emissions, Selected Emission Estimates, and U.S. NDC

Sources: Prepared by CRS; actual U.S. GHG emissions from EPA, Inventory of U.S. Greenhouse Gas Emissions and
Sinks: 1990–2021, April 2023; Rhodium Group, A Turning Point for US Climate Progress: Assessing the Climate and
Clean Energy Provisions in the Inflation Reduction Act, August 12, 2022, at https://rhg.com/research/climate-clean-
energy-inflation-reduction-act/; Princeton University REPEAT, Electricity Transmission is Key to Unlock the Full
Potential of the Inflation Reduction Act, September 2022, at https://repeatproject.org/docs/
REPEAT_IRA_Transmission_2022-09-22.pdf; Energy Innovation, Modeling the Inflation Reduction Act Using the
Energy Policy Simulator, August 23, 2022, at https://energyinnovation.org/publication/modeling-the-inflation-
reduction-act-using-the-energy-policy-simulator/; and Department of Energy, “The Inflation Reduction Act Drives
Significant Emissions Reductions and Positions America to Reach Our Climate Goals,” August 2022, at
https://www.energy.gov/sites/default/files/2022-08/8.18%20InflationReductionAct_Factsheet_Final.pdf.
Notes: NDC = nationally determined contribution pursuant to the UNFCCC Paris Agreement. MMTCO2e =
mil ion metric tons of CO2 equivalent. This measure is used because GHGs vary by global warming potential
(GWP). GWP is an index that allows comparisons of the heat-trapping ability of different gases over a period of
time. The GHG emissions in the figure are net GHG emissions. Net GHG emissions account for removals of
CO2 emissions from the atmosphere by emissions sinks, such as forests, vegetation, and soils. The U.S. NDC is
measured in terms of net emissions.

60 For more information, see CRS Report R47385, U.S. Greenhouse Gas Emissions Trends and Projections from the
Inflation Reduction Act, by Jonathan L. Ramseur.
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Emissions Projections in the Electricity Sector
Multiple factors will likely affect CO2 emissions levels from the electricity sector. Some of these
factors, which are identified below, are interrelated:
• electricity generation portfolio (i.e., whether recent trends in coal, natural gas,
and renewable energy use continue);
• prices of fossil fuels—particularly natural gas—and renewable energy
technologies;
• federal and/or state policy developments;
• economic impacts (e.g., level of GDP growth); and
• improvements in demand-side energy efficiency (e.g., commercial and residential
electricity use).
Some groups have prepared U.S. GHG emissions projections for IRA scenarios that include
projections of emissions for the U.S. electricity sector. Figure 9 illustrates the results of four
scenarios from the U.S. Energy Information Administration’s (EIA’s) Annual Energy Outlook
2023 and two scenarios from documentation associated with EPA’s 2023 proposed rule on
emissions from fossil-fuel-fired electric power plants (discussed above).61
EIA’s analysis included three IRA scenarios and one scenario without IRA. The IRA scenarios
included different assumptions about the outcome of specific IRA provisions. IRA creates new
and revises existing tax credits that encourage electricity generation from less carbon-intensive
sources than fossil fuels, such as renewable sources or nuclear power. The tax credits include a
base credit with tiers of additional credit if certain conditions are met. These conditions include
prevailing wage or apprenticeship requirements, domestic content requirements, and whether a
facility is located in an “energy community.”62 EIA’s “IRA Low Uptake” case generally assumes
facilities will receive the base credit amounts. The “IRA High Uptake” scenario generally
assumes facilities will receive all of the available tiers of credit. The “IRA Reference” scenario
reflects EIA’s view of the “most likely tax credit uptake,” which includes a mixture of base tax
credit and some bonus credits.63
As the figure illustrates, EIA projects that each scenario results in decreased emissions compared
to 2022 levels. The IRA “Reference” and “High Uptake” scenarios yield similar projections, with
CO2 emissions in the electricity sector decreasing by 68% and 70%, respectively, compared to
2005 CO2 levels by 2030. By comparison, the “No IRA” and “Low Uptake” scenarios indicated
CO2 emissions in the electricity sector would decrease by 51% and 53%, respectively, compared
to 2005 CO2 levels by 2030. Note that the 2030 emissions reductions in the electricity sector are
lower than the projected reductions in total U.S. GHG emissions, as illustrated in Figure 8.
Figure 9 indicates that emissions in the electricity sector will continue to decrease after 2030.
EIA’s IRA “Reference” and “High Uptake” scenarios result in emissions decreases of 70% and

61 For more information on the U.S. Energy Information Administration’s Annual Energy Outlook, see CRS In Focus
IF11691, The Annual Energy Outlook (AEO): A Brief Overview, by Ashley J. Lawson and Kelsi Bracmort.
62 The IRA defines energy communities, for purposes of bonus tax credits, as those meeting certain criteria related to
employment in fossil fuel industries, proximity to closed coal mines or retired coal-fired power plants, or brownfield
sites. Energy communities will change over time as these criteria change. An estimate of areas currently meeting some
of these criteria is at U.S. Department of Energy, “Energy Community Tax Credit Bonus,” at
https://arcgis.netl.doe.gov/portal/apps/experiencebuilder/experience/?id=a2ce47d4721a477a8701bd0e08495e1d.
63 For more details about EIA’s assumptions for their different scenarios, see the Appendix to the Annual Energy
Outlook 2023, at https://www.eia.gov/outlooks/aeo/IIF_IRA/#appendix.
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74%, respectively, compared to 2005 CO2 levels by 2035. By comparison, the “No IRA” and
“Low Uptake” scenarios indicate emissions decreases of 54% and 56%, respectively, compared to
2005 CO2 levels by 2035.
In addition, Figure 9 includes emissions projections that EPA prepared as part of its 2023
proposed rule for coal- and natural-gas-fired power plants (discussed above).64 In EPA’s reference
case (i.e., IRA provisions without the 2023 proposed rule), EPA projected that CO2 emissions in
the electricity sector would decrease by 60% in 2030 compared to 2005 levels, and by 75% in
2035 compared to 2005 levels. EPA’s projection for 2035 is nearly identical to EIA’s 2035 “High
Uptake” projection.
The figure also illustrates EPA’s projected emissions results from its 2023 proposed rule. As the
figure indicates, EPA projects that the proposed rule would result in further emissions decreases
below EPA’s IRA reference case. EPA estimates that CO2 emissions in the electricity sector would
decrease by 63% in 2030 compared to 2005 levels, and by 76% in 2035 compared to 2005 levels.
Figure 9. EIA and EPA Projections of CO2 Emissions in the Electricity Sector
Actual Levels and Projected Scenarios Through 2035

Source: Prepared by CRS with data from EIA, Annual Energy Outlook 2023, at https://www.eia.gov/outlooks/aeo/;
and EPA, Regulatory Impact Analysis for the Proposed New Source Performance Standards for Greenhouse Gas Emissions
from New, Modified, and Reconstructed Fossil Fuel-Fired Electric Generating Units, 2023, at https://www.epa.gov/
stationary-sources-air-pol ution/greenhouse-gas-standards-and-guidelines-fossil-fuel-fired-power.
Notes: EIA modeled three IRA scenarios and one scenario without IRA provisions. The IRA scenarios included
different assumptions about the implementation of specific IRA provisions. IRA creates new and revises existing
tax credits that encourage electricity generation from less carbon-intensive sources than fossil fuels, such as

64 See EPA, Regulatory Impact Analysis for the Proposed New Source Performance Standards for Greenhouse Gas
Emissions from New, Modified, and Reconstructed Fossil Fuel-Fired Electric Generating Units; Emission Guidelines
for Greenhouse Gas Emissions from Existing Fossil Fuel-Fired Electric Generating Units; and Repeal of the
Affordable Clean Energy Rule, 2023, at https://www.epa.gov/stationary-sources-air-pollution/greenhouse-gas-
standards-and-guidelines-fossil-fuel-fired-power; and EPA, Analysis of the Proposed Greenhouse Gas Standards and
Guidelines, 2023, at https://www.epa.gov/power-sector-modeling/analysis-proposed-greenhouse-gas-standards-and-
guidelines.
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renewable sources or nuclear power. The tax credits include a base credit with tiers of additional credit if
certain conditions are met. These conditions include prevailing wage or apprenticeship requirements, domestic
content requirements, and whether a facility is located in an “energy community.” The IRA “Reference” scenario
reflects EIA’s view of the “most likely tax credit uptake,” which includes a mixture of base tax credit and some
bonus credits. EIA’s “IRA Low Uptake” case generally assumes facilities wil receive the base credit amounts. The
“IRA High Uptake” scenario assumes facilities wil receive all of the available tiers of credit.
EPA’s “Reference Case” includes IRA provisions, but does not include effects from the 2023 proposed rule.
EPA’s “2023 Proposed Rule” scenario includes IRA provision and effects from the proposed rule addressing
fossil-fuel-fired electric power plants. For more information about EPA’s modeling assumptions, see
https://www.epa.gov/power-sector-modeling/analysis-proposed-greenhouse-gas-standards-and-guidelines.
Other groups have prepared projections of emissions levels in the electricity sectors as part of
their analyses of the emissions impacts from IRA. These groups measured total GHG emissions,
rather than just CO2 emissions.65 For example, a 2022 analysis from the Rhodium Group included
three IRA scenarios and estimated that GHG emissions in the electricity sector would decrease
between approximately 70% and 80% below 2005 GHG emissions levels.66
As illustrated above, GHG emissions projections generally involve a range of estimates, as they
contain considerable uncertainty. For example, one factor of uncertainty specific to the electricity
sector is the rate at which electricity transmission is expected to expand over the next decade.
New transmission lines are likely needed to access some, though not all, new low- or zero-
emissions energy sources.67 A 2022 analysis from Princeton examined the specific role of this
factor by isolating this variable in its IRA modeling scenarios.68 The Princeton model found that
the annual rate of transmission expansion is likely to play a pivotal role in the degree to which
IRA provisions reduce emissions in the electricity sector. In part prompted by concerns about the
pace of transmission development, some Members have focused on options for accelerating
transmission planning, siting, and permitting.69
Another factor of uncertainty is the degree to which carbon capture and storage (CCS) is
implemented in the future. Some models estimate CCS to increase substantially after 2030.70

65 In the electricity sector, CO2 emissions accounted for 98% of total GHG emissions in 2021.
66 Rhodium Group, A Turning Point for US Climate Progress: Assessing the Climate and Clean Energy Provisions in
the Inflation Reduction Act, August 12, 2022, at https://rhg.com/research/climate-clean-energy-inflation-reduction-act/.
Rhodium Group estimates are measured in total GHG emissions, rather than CO2 emissions. CRS calculated the 70%-
80% reduction range based on a 2005 GHG emissions level of 2,457 MMTCO2e from EPA’s inventory (accounting for
GHG emissions in the electricity sector).
67 A number of nonemitting energy sources incentivized by IRA do not require new transmission lines. Examples
include distributed solar generation, retrofits of existing power plants with carbon capture and storage or with hydrogen
blending, and rebuilds of existing power plants with nuclear energy or other nonemitting energy source such as solar
energy combined with energy storage.
68 Princeton University Rapid Energy Policy Evaluation and Analysis Toolkit (REPEAT), Electricity Transmission Is
Key to Unlock the Full Potential of the Inflation Reduction Act, September 2022, at https://repeatproject.org/docs/
REPEAT_IRA_Transmission_2022-09-22.pdf; Princeton University REPEAT, Preliminary Report: The Climate and
Energy Impacts of the Inflation Reduction Act of 2022, August 2022, at https://repeatproject.org/docs/
REPEAT_IRA_Prelminary_Report_2022-09-21.pdf. Other energy models—such as those used by EIA and Rhodium
Group—do not explicitly project transmission capacity.
69 For more information on transmission development, see CRS In Focus IF12253, Introduction to Electricity
Transmission, by Ashley J. Lawson.
70 For example, the Rhodium Group study estimated that installed carbon capture would more than double between
2030 and 2035. The 2022 Princeton study indicated similar results. See Rhodium Group, A Turning Point for US
Climate Progress; and Princeton University REPEAT, Preliminary Report: The Climate and Energy Impacts of the
Inflation Reduction Act of 2022, August 2022. For further information on carbon capture and sequestration, see CRS
Report R44902, Carbon Capture and Sequestration (CCS) in the United States, by Angela C. Jones and Ashley J.
Lawson.
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link to page 25 link to page 25 GHG Emissions in the U.S. Electricity Sector: Background, Policies, and Projections

Concluding Observations
International negotiations and domestic policy developments continue to generate congressional
interest in current and projected U.S. GHG emissions levels. The United States has pledged to
reduce its net GHG emissions by 50%-52% below 2005 levels by 2030. Recent analyses indicate
U.S. net GHG emissions would decrease by 30% to 43% by 2030 compared with 2005 levels,
thus not meeting the 2030 reduction target.71
U.S. GHG emissions levels will likely depend, to some degree, on CO2 emissions from power
plants. Multiple factors generally affect GHG emissions levels from the electric power sector. In
particular, the following recent changes in the U.S. electricity generation portfolio between 2005
and 2022 have played a key role in reducing emissions to date:
• coal’s contribution to total electricity generation has decreased from 50% to 19%;
• natural gas’s contribution to total electricity generation has increased from 19%
to 39%; and
• renewable energy (other than hydroelectricity) generation has increased from 2%
to 17%; these increases primarily involve wind and solar sources.
Although models generally project that these trends will continue, the degree to which they will
continue is uncertain. Moreover, the projected trends in the electricity sector do not appear
sufficient to meet the U.S. GHG emissions reduction pledges, according to the various models.
The emissions levels in other sectors, particularly transportation and industry, also play important
roles in overall U.S. emissions. The emissions models do not project comparable emissions
reduction in the other key sectors: transportation and industry. As an illustrative example, Figure
10 displays the results from one of the studies, depicting the GHG emissions reductions estimated
by sector: electric power, industry, transportation, and carbon removal. Compared with a baseline
scenario (without IRA), electric power sector emissions decrease by 51%. In contrast, industry
and transportation sector emissions are projected to decrease by 4% and 1%, respectively.72 On
the other hand, many of the IRA provisions may take longer than 2030 to have full effect, such as
tax incentives for electric or zero-emission vehicles that would penetrate vehicle markets slowly
and would have more influence on GHG emissions after 2030. Therefore, these estimates likely
do not represent a full accounting of potential effects of the law.

71 These models compare scenarios with and without IRA. Based on the results from these models, IRA’s climate
change provisions are likely to result in net GHG emissions reductions as compared to emissions scenarios without
IRA. Each of the analyses included multiple IRA scenarios to account for uncertain factors, such as future oil and
natural gas prices, the rate of increase in electricity transmission, and implementation of IRA provisions, among other
factors. For more details and discussion, see CRS Report R47385, U.S. Greenhouse Gas Emissions Trends and
Projections from the Inflation Reduction Act, by Jonathan L. Ramseur.
72 The Energy Innovation model produced comparable results for the electric power and transportation sectors (Figure 2
in Energy Innovation estimates from Energy Innovation, Modeling the Inflation Reduction Act). The Princeton model
produced larger reductions in the transportation sector compared with the other models (Princeton REPEAT, Electricity
Transmission, p. 9). See Energy Innovation, Modeling the Inflation Reduction Act Using the Energy Policy Simulator,
August 23, 2022, at https://energyinnovation.org/publication/modeling-the-inflation-reduction-act-using-the-energy-
policy-simulator/; and Princeton University REPEAT, Electricity Transmission Is Key to Unlock the Full Potential of
the Inflation Reduction Act, September 2022, at https://repeatproject.org/docs/REPEAT_IRA_Transmission_2022-09-
22.pdf.
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GHG Emissions in the U.S. Electricity Sector: Background, Policies, and Projections

Figure 10. Estimated GHG Emissions Reductions by Sector in 2030
Based on Rhodium Group Modeling

Source: Prepared by CRS; emissions estimates from Rhodium Group, A Turning Point for US Climate Progress:
Assessing the Climate and Clean Energy Provisions in the Inflation Reduction Act, August 12, 2022, at https://rhg.com/
research/climate-clean-energy-inflation-reduction-act/.
Notes: MMTCO2e = mil ion metric tons of CO2 equivalent. This measure is used because GHGs vary by global
warming potential (GWP). GWP is an index that allows comparisons of the heat-trapping ability of different
gases over a period of time. Carbon removal includes “forest and soil practices, direct air capture and other
actions.”
The GHG emissions levels in the various economic sectors are interrelated in complicated ways.
For example, climate mitigation policies that increase the use of electric vehicles and
electrification of industrial processes (i.e., using electricity instead of fossil fuels for onsite
operations) will, all else being equal, increase overall electricity generation and emissions in the
electricity sector. The net effects on U.S. emissions from these relationships will depend, in part,
on the degree and pace of the electrification in the transportation and industrial sectors and the
degree and pace of carbon intensity changes in the electricity generation portfolio.
Climate-related provisions in recent legislation, particularly the tax incentives and funding
provisions in IRA, are projected to play a role in GHG emissions levels from the electricity sector
and other sectors. EPA’s 2023 proposed rule for fossil-fuel-fired electric power plants could
provide additional emissions reductions, but the fate of this proposal is uncertain.
If Congress wishes to incentivize U.S. GHG emissions reduction beyond the projections from the
models discussed in this report, a range of policy options remain available. IRA contains a
number of climate-related provisions across multiple economic sectors. The general approach of
IRA’s climate provisions is to promote GHG reduction through tax incentives and direct funding.
Policymakers could increase and/or extend the funding amounts or tax incentives in these
provisions. Alternatively, policymakers could employ different approaches in subsequent
legislation. Options include market-based approaches, such as carbon pricing mechanisms (e.g.,
fee on emissions or a cap-and-trade program) or regulatory standards for particular facilities or
sectors.73 To some degree, such efforts are under way at the state and local level.

73 For more discussion of general approaches to GHG emissions mitigation, see CRS In Focus IF11791, Mitigating
Greenhouse Gas Emissions: Selected Policy Options, by Jonathan L. Ramseur et al.
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GHG Emissions in the U.S. Electricity Sector: Background, Policies, and Projections

IRA climate provisions may support the development of additional requirements from the federal
government, such as the 2023 proposed rule, or state and local governments by reducing the costs
of lower-carbon energy sources and technologies. In particular, the IRA provisions may
complement EPA’s regulations requiring emissions performance standards at electric power plants
by reducing the costs of potential compliance options. If these additional policies are
implemented, they may help achieve the U.S. 2030 emissions reduction target. However, the role
of these regulations is uncertain, as their implementation is likely to face opposition from some
policymakers and stakeholders.

Author Information

Jonathan L. Ramseur

Specialist in Environmental Policy

Acknowledgments
Amber Wilhelm, CRS Visual Information Specialist, helped create many of the figures in this report.

Disclaimer
This document was prepared by the Congressional Research Service (CRS). CRS serves as nonpartisan
shared staff to congressional committees and Members of Congress. It operates solely at the behest of and
under the direction of Congress. Information in a CRS Report should not be relied upon for purposes other
than public understanding of information that has been provided by CRS to Members of Congress in
connection with CRS’s institutional role. CRS Reports, as a work of the United States Government, are not
subject to copyright protection in the United States. Any CRS Report may be reproduced and distributed in
its entirety without permission from CRS. However, as a CRS Report may include copyrighted images or
material from a third party, you may need to obtain the permission of the copyright holder if you wish to
copy or otherwise use copyrighted material.

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