Hydrogen in Electricity’s Future

Hydrogen in Electricity’s Future

Hydrogen in Electricity’s Future
June 30, 2020
The U.S. Department of Energy’s (DOE’s) Office of Energy Efficiency and Renewable Energy
(EERE) describes hydrogen as an “energy carrier,” as it allows the transport of energy that can be
Richard J. Campbell
later converted to other forms of useful energy. Moreover, due to its high energy content and
Specialist in Energy Policy
clean-burning properties, hydrogen is being investigated for its potential to replace or reduce the

use of fossil fuels and to reduce greenhouse gas (GHG) emissions.

Natural gas is currently the fuel most used for electric power generation in the United States, and
the DOE’s Energy Information Administration expects it to be the predominant fuel for the production of electricity well into
the 2040s. Natural gas is a fossil fuel that when burned to produce electric power, results in carbon dioxide (CO2) emissions,
varying from 42% to 63% of the CO2 emissions of coal. When potential climate impacts are considered by electric utilities,
increasing renewable sources of electricity and switching to natural gas generation from coal have been strategies that a
number of companies have followed. Total CO2 emissions have increased with increased electricity production from natural
gas-fired generation.
If reducing or eliminating fossil fuel use is a goal for the electric power sector, then the expanded use of hydrogen due to its
potential to decarbonize the sector could be an option. Combustion turbines capable of burning hydrogen could be used in
order to increase power generation on a large scale, and could potentially replace natural gas-fired generation. There are
technical and cost issues with how such a transition could be accomplished. Another potential option for the use of hydrogen
is as a fuel for electricity production in fuel cells, as water and heat are the only by-products.
Hydrogen gas can be produced in a variety of ways, but it must be extracted from the various compounds containing
hydrogen, using appropriate technologies. An increased use of hydrogen in the electric power sector for power generation
would likely require an increased, more economical supply of hydrogen. With U.S. prices for natural gas currently below $2
per million BTU in several markets and projected to stay low, this presents a long-term challenge to the cost effective use of
hydrogen. Other challenges are generally focused on two areas: the storage of hydrogen, and the transportation of hydrogen.
Storing hydrogen requires the input of external energy to compress the gas. Building new pipelines for hydrogen
transportation faces technical barriers beyond the initial high capital costs of pipeline construction, with embrittlement and
escape of hydrogen (the smallest element) via permeation among known issues. According to one report, developing a
system for hydrogen storage and transportation to provide the same utility as the natural gas system would require a
significantly large, coordinated program of infrastructure upgrades and construction. Another article proposed using the
existing natural gas pipeline system, and decarbonizing natural gas on-site as one way to avoid much of the need for
hydrogen transport and storage.
A recent analysis by the U.S. Global Change Research Program found that if GHG emissions continued at forecast rates and
adaptation actions were not undertaken, climate change impacts would damage U.S. infrastructure, communities, and the
economy. If Congress chooses to pursue further GHG emissions reduction, then addressing carbon dioxide emissions from
natural gas may be an option. Congress may examine the question of whether and how to lower the costs of producing and
using hydrogen for power generation. Alternatively, Congress may consider how to address the unaddressed negative
externalities of carbon dioxide emissions, with a tax or some other limit on CO2 emissions as a potential option. Congress
may also consider further research, development, demonstration, and deployment to facilitate the economic use of hydrogen
for electric power, including the use of tax incentives or credits for such purposes.

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Contents
Introduction ..................................................................................................................................... 1
Why Hydrogen Is Being Discussed for Electric Power .................................................................. 2
Mitigation of Climate Change Impacts ..................................................................................... 3
Methods and Sources for Producing Hydrogen ............................................................................... 4
Fossil Fuel Sources ................................................................................................................... 5
Renewable Sources ................................................................................................................... 5
Nuclear Power for Hydrogen Production .................................................................................. 6
Commercial Readiness .............................................................................................................. 6
Hydrogen for Large Scale Electric Power Generation .................................................................... 7
Hydrogen-Fueled Combustion Turbines ................................................................................... 8
Fuel Cells for Hydrogen Power ................................................................................................. 9
Energy Carrier to Fuel ...................................................................................................... 10
Estimates of the Cost of Producing Hydrogen ............................................................................... 11
Further Electrifying the U.S. Economy ......................................................................................... 13
NREL’s Electrification Futures Study .................................................................................... 13
Challenges Associated with Hydrogen for Power ......................................................................... 15
Transportation of Hydrogen .................................................................................................... 15
Hydrogen Storage.................................................................................................................... 16
Estimate of the Cost of Hydrogen Storage and Transportation ............................................... 17
Natural Gas Decarbonization On-Site ..................................................................................... 17
Recent Legislation ......................................................................................................................... 18
Bills in the 116th Congress....................................................................................................... 18
Issues for Congress ........................................................................................................................ 18

Figures
Figure 1. Hydrogen Production Technologies ................................................................................. 7

Tables
Table 1. Selected Hydrogen Production Methods ......................................................................... 12

Appendixes
Appendix. Sources of Hydrogen ................................................................................................... 20

Contacts
Author Information ........................................................................................................................ 23

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Introduction
Hydrogen is the simplest, and one of the most abundant elements on the Earth. The hydrogen
atom is composed of a proton and an electron, and combines with other elements to form a
number of common compounds including water (H2O), and methane (CH4), the primary
constituent of natural gas.1
Hydrogen is a commercially important element. Large amounts of hydrogen are combined
with nitrogen from the air to produce ammonia (NH3) through a process called the Haber
process.… Liquid hydrogen is used in the study of superconductors and, when combined
with liquid oxygen, makes an excellent rocket fuel.2
The U.S. Department of Energy’s (DOE’s) Office of Energy Efficiency and Renewable Energy
(EERE) describes hydrogen as an “energy carrier,” as it allows the transport of energy that can be
later converted to other forms of useful energy (such as mechanical work or heat (or thermal)
energy used for physical or chemical processes).3 Hydrogen (with an energy density of about 142
megajoules per kilogram (MJ/kg))4 also has one of the highest energy density values per unit of
mass,5 containing more than three times the energy of most hydrocarbon fuels.6
Hydrogen gas is highly flammable, requiring a small amount of energy to ignite and burn, and
when hydrogen is burned with oxygen, it burns cleanly with the only by-products being heat and
water.7 Because of its high energy content and clean-burning properties, hydrogen is being
investigated for its potential to replace fossil fuels and reduce greenhouse gas8 (GHG) emissions.
Freeing hydrogen from its compound forms requires the application of energy, and it can take
more energy to produce hydrogen than it provides “when it is converted to useful energy.
However, hydrogen is useful as an energy source/fuel because it has a high energy [density].”9

1 Thomas Jefferson National Accelerator Facility, The Element Hydrogen, 2020, https://education.jlab.org/itselemental/
ele001.html.
2 Ibid.
3 DOE, Office of Energy Efficiency and Renewable Energy, Hydrogen: A Clean, Flexible Energy Carrier, February
21, 2017, https://www.energy.gov/eere/articles/hydrogen-clean-flexible-energy-carrier.
4 For conversion to U.S. units: 1 MJ/kg = 430 British thermal units per pound (Btu/lb).
5 Futek Global Energy Technology-Japan, Hydrogen Fuelled Electricity Generation, 2020,
http://www.futeklighting.net/images/Hydrogen%20Fuelled%20Electricity%20Generation.pdf.
6 Energy density is the amount of energy stored in a given system, substance, or region of space per unit volume. It
therefore has units of energy per length cubed or energy per mass. Arthur Golnik, “Energy Density of Gasoline,” The
Physics Factbook, 2003, https://hypertextbook.com/facts/2003/ArthurGolnik.shtml. (Energy density is a volume-based
measurement. It is used colloquially to refer to energy per unit mass, however the appropriate tem for energy per unit
mass is “specific energy.”)
For example, the energy density of methane is 55.5 MJ/kg, natural gas is 47.2 MJ/kg, and gasoline is 45.8 MJ/kg. Dr.
Jean-Paul Rodrigue, The Geography of Transport Systems, Department of Global Studies and Geography, Hofstra
University, Energy Content of some Combustibles, 2020, https://transportgeography.org/?page_id=5837.
7 Michelle Fung, “Energy Density of Hydrogen,” The Physics Factbook, 2005, https://hypertextbook.com/facts/2005/
MichelleFung.shtml.
8 According to the Environmental Protection Agency (EPA), greenhouse gases are any gas that absorbs infrared
radiation in the atmosphere. There are six greenhouse gases addressed by EPA regulatory actions: carbon dioxide
(CO2), methane (CH4), nitrous oxide (N2O), and fluorinated gases—sulfur hexafluoride (SF6), hydrofluorocarbons
(HFCs), and perfluorocarbons (PFCs). Carbon dioxide is the most prevalent GHG produced by combustion of fossil
fuels. See https://www.epa.gov/ghgemissions/overview-greenhouse-gases.
9 Energy Information Administration, “Hydrogen Explained,” January 21, 2020, https://www.eia.gov/energyexplained/
hydrogen/.
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Interest in reducing GHG emissions from electric power generation to mitigate climate change
risks has increased the focus on the potential use of hydrogen to produce electricity. While
renewable energy technologies (e.g., wind and solar power) are seeing increased deployment at
utility scale, these technologies are generally intermittent or variable in their production of
electricity, and are often backed up by electricity generated from fossil fuels (primarily natural
gas). While increased deployment of energy storage devices and better forecasting techniques
may help renewable electricity to become power “on-demand” resources, the economics and
deployment of grid battery storage resources are still developing.10 In the meantime, GHG
emissions from natural gas-fired generation are rising from increasing natural gas utilization for
power generation.11
This report is focused on the current and potential sources of hydrogen, and several of the various
technologies and processes for its economic production and use. Replacing fossil fuels with
hydrogen for the generation of electricity may provide one potential avenue for reducing GHG
emissions. However, hydrogen production and technologies to use hydrogen as a fuel for power
generation currently present higher cost options, if the potential negative externalities12 of carbon
dioxide emissions are not considered.
Why Hydrogen Is Being Discussed for Electric
Power
According to the U.S. Department of Energy’s Energy Information Administration (EIA), natural
gas is currently the fuel most used for electric power generation in the United States,13 and it is
expected to be the predominant fuel for the production of electricity well into the 2040s.
EIA projects that coal as a source of electricity generation will continue to decline in share until
about 2025, when power generation from coal is expected to stabilize at about 13% of annual
U.S. generation.14 This is due to EIA’s expectation that the remaining coal plants will be “more
efficient and continue to operate throughout the projection period.” EIA also projects renewable
electricity will overtake natural gas in the 2040s to 2050s.15 Given that renewable generation from
wind and solar sources is intermittent and variable, to balance these changing levels of
generation, fast ramping generation (capable of quickly increasing or decreasing output) is used
that today is typically fueled by natural gas.
However, natural gas is a fossil fuel that when burned to produce electric power results in various
air emissions including carbon dioxide. Natural gas combustion for power generation generally
results in about half the carbon emissions produced by burning coal per unit of energy output or

10 CRS Report R45980, Electricity Storage: Applications, Issues, and Technologies, by Richard J. Campbell.
11 EIA, “EIA Projects U.S. Energy-Related CO2 Emissions Will Remain Near Current Level Through 2050,” March
20, 2019, https://www.eia.gov/todayinenergy/detail.php?id=38773.
12 “With a negative externality, like pollution, the market tends to over produce the relevant commodity. Too much
electricity is produced using coal because the buyers of that electricity do not face the full costs of their actions. If they
did, they would buy less.” Stephen King, Global Warming, Externalities and Government Failure, June 24, 2013,
http://economicstudents.com/2013/06/global-warming-externalities-and-government-failure/.
13 U.S. Energy Information Administration, “Electricity Explained—Electricity in the United States,” March 20, 2020,
https://www.eia.gov/energyexplained/electricity/electricity-in-the-us.php.
14 EIA, Annual Energy Outlook 2020, Electricity, January 29, 2020, https://www.eia.gov/outlooks/aeo/pdf/
AEO2020%20Electricity.pdf.
15 Ibid.
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heat content.16 The technology and process used can vary in efficiency for power production (e.g.,
a natural gas-fired combined-cycle power plant vs. a simple cycle combustion turbine), resulting
in carbon dioxide emissions varying “anywhere from 42% to 63% of the CO2 emissions of coal,
depending upon the power plant technology.”17 Despite the lower per-unit emissions, the growth
in overall natural gas power generation has made it the top source of CO2 emissions in the sector.
[I]n 2015, natural gas emissions surpassed coal emissions, and the [Annual Energy Outlook
(AEO)] AEO2019 Reference case projects that natural gas CO2 emissions will continue
increasing as natural gas use increases. The U.S. electric power sector—now the largest
consuming sector for natural gas—has added generating capacity from natural gas in recent
years and has used those power plants more often.18
EPA has identified transportation and electric power generation as the two main sources of U.S.
GHG emissions resulting from human activities:19
 Transportation (28.2% of 2018 anthropogenic greenhouse gas emissions). The
transportation sector generated the largest share of anthropogenic greenhouse gas
emissions. Greenhouse gas emissions from transportation primarily come from burning
fossil fuel for cars, trucks, ships, trains, and planes. Over 90% of the fuel used for
transportation is petroleum based, primarily gasoline and diesel.
 Electricity production (26.9% of 2018 anthropogenic greenhouse gas emissions). The
production of electricity generated the second largest share of anthropogenic greenhouse
gas emissions. Approximately 63% of U.S. electricity comes from burning fossil fuels,
mostly natural gas and coal.
 Industry (22.0% of 2018 anthropogenic greenhouse gas emissions). Greenhouse
gas emissions from industry primarily come from burning fossil fuels for energy,
as well as greenhouse gas emissions from certain chemical reactions necessary to
produce goods from raw materials.
 Commercial and Residential (12.3% of 2018 anthropogenic greenhouse gas
emissions). Greenhouse gas emissions from businesses and homes arise primarily
from fossil fuels burned for heat, and from the handling of waste.
The percentages above do not add to 100%, with the remaining balance coming from other
sources.
Mitigation of Climate Change Impacts
There is a policy debate regarding the extent to which GHG emissions are responsible for climate
change. However, a general consensus exists among most climate change scientists that “climate
change is occurring, and rigorous scientific research demonstrates that the greenhouse gases
emitted by human activities are the primary driver.”20 The question of how to reduce those

16 EIA, “How Much Carbon Dioxide Is Produced When Different Fuels Are Burned?,” March 17, 2020,
https://www.eia.gov/tools/faqs/faq.php?id=73&t=11.
17 CRS Report R44090, Life-Cycle Greenhouse Gas Assessment of Coal and Natural Gas in the Power Sector, by
Richard K. Lattanzio.
18 EIA, EIA Projects U.S. Energy-Related CO2 Emissions Will Remain near Current Level Through 2050, March 20,
2019, https://www.eia.gov/todayinenergy/detail.php?id=38773.
19 EPA, “Sources of Greenhouse Gas Emissions,” April 11, 2020, https://www.epa.gov/ghgemissions/sources-
greenhouse-gas-emissions.
20 National Aeronautics and Space Administration, “Scientific Consensus: Earth’s Climate Is Warming,” June 26, 2020,
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emissions therefore arises. One report has suggested that GHG emissions from these sectors could
be mitigated with “aggressive” energy efficiency targets.21
However, when potential climate impacts are considered, some in the electric utility industry and
others advocate wider actions to achieve a greater reduction in carbon dioxide emissions.22 While
increasing renewable sources of electricity and switching to natural gas generation from coal has
been a strategy that a number of electric utilities have followed, EIA reports that CO2 emissions
have increased recently with the increased production of electricity using natural gas.23
Hydrogen, when burned in the presence of oxygen, produces only water as a by-product.
[Hydrogen] is highly flammable, needing only a small amount of energy to ignite and burn.
Hydrogen burns cleanly. When it is burned with oxygen, the only by products are heat and
water.24
If reducing or eliminating fossil fuel use is a goal for the electric power sector, then the expanded
use of hydrogen due to its potential to decarbonize the sector could be an option. Combustion
turbines capable of burning hydrogen could be utilized in order to increase power generation on a
large scale, and could potentially replace natural gas-fired generation. However, there are
technical and cost issues with how such a transition could be accomplished, and several of these
issues are discussed later in this report.
Another potential option would be to increase hydrogen as an energy carrier via an energy storage
application:
The solution, some propose, is to store energy chemically—in the form of hydrogen fuel.…
This involves using devices called electrolyzers that make use of renewable energy to split
water into hydrogen and oxygen gas.… It’s an efficient energy carrier, and can be easily
stored in pressurized tanks. When needed, the gas can then be converted back into electrical
energy via a fuel cell and fed into the grid.25
Methods and Sources for Producing Hydrogen
Generally, large reserves of hydrogen do not occur naturally on Earth, being found mostly in
compound form with other elements in liquids, gases, or solids.26 Hydrogen is also found in
biological organisms, and as a result, can be found in biomass and fossil fuels that originated
from biological sources. Hydrogen must therefore be extracted from these various sources using

https://climate.nasa.gov/scientific-consensus/.
21 The report from the American Council for an Energy Efficient Economy concludes that, if pursued aggressively,
energy efficiency can reduce energy-related carbon emissions in the U.S. in 2050 by as much as 57% relative to current
projections. Steven Nadel and Lowell Ungar, Halfway There: Energy Efficiency Can Cut Energy Use and Greenhouse
Gas Emissions in Half by 2050, American Council for an Energy-Efficient Economy, September 2019,
https://www.aceee.org/research-report/u1907.
22 For example, see Southern Company, Climate, 2020, https://www.southerncompany.com/corporate-responsibility/
environment/air-and-climate.html?msclkid=1776f9920500144e9c26a70fa9e28039.
23 EIA, “EIA Projects U.S. Energy-Related CO2 Emissions Will Remain near Current Level Through 2050,” March 20,
2019, https://www.eia.gov/todayinenergy/detail.php?id=38773.
24 Michelle Fung, “Energy Density of Hydrogen,” The Physics Factbook, 2005, https://hypertextbook.com/facts/2005/
MichelleFung.shtml.
25 Sandy Ong, Redox-Flow Cell Stores Renewable Energy as Hydrogen, IEEE Spectrum, April 13, 2020,
https://spectrum.ieee.org/energywise/energy/renewables/storing-renewable-energy-hydrogen-redoxflow-cell.
26 Jordan Hanania, James Jenden, and Kailyn Stenhouse, et al., “Hydrogen,” Energy Education, January 8, 2017,
https://energyeducation.ca/encyclopedia/Hydrogen.
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appropriate technologies. Some refer to hydrogen produced from fossil fuels as “blue hydrogen,”
if the separated carbon is captured and sequestered, and “gray hydrogen” if it is not; and
hydrogen produced from renewable processes as “green hydrogen.” An increased use of
hydrogen in the electric power sector for power generation would likely require an increased,
more economical supply of hydrogen than possible with current processes. This section
summarizes the current methods and sources of hydrogen production.
Fossil Fuel Sources
According to DOE, over 95% of U.S. hydrogen production comes from steam-methane reforming
(SMR). In this process, natural gas (which is principally methane) reacts with high pressure, high
temperature steam, in the presence of a catalyst to produce a mixture of mostly hydrogen and
carbon monoxide (i.e., a synthetic natural gas27 or “syngas”). Further processing reduces the
carbon monoxide, and results in a gaseous stream that is mostly hydrogen.28
Coal, an organic hydrocarbon, is another potential source of hydrogen. Hydrogen can be obtained
from coal through gasification and other methods. Gasification is accomplished in a high-
temperature pressure vessel. Coal gasification refers to a process where oxygen (or air) and steam
would directly contact the coal causing a series of chemical reactions to occur that convert the
feedstock to syngas, with some ash/slag (mineral residues) resulting.29 Coal gasification offers the
capability for CO2 to be separated from the gaseous stream, allowing it to be potentially
sequestered (e.g., carbon capture and sequestration) or reused (e.g., carbon capture, utilization, or
storage).30
Renewable Sources
Hydrogen can be produced from renewable processes in several ways. According to one article,
these pathways include:31
 Electrolysis—splitting water molecules into their elemental components, using
electricity from a range of renewable sources;
 Biomass conversion—via either thermochemical or biochemical conversion to
intermediate products that can then be separated or reformed to hydrogen; or
fermentation techniques that produce hydrogen directly; and
 Solar conversion—by either thermolysis,32 using solar-generated heat for high
temperature chemical cycle hydrogen production or photolysis, in which solar

27 “Synthetic natural gas (SNG): (Also referred to as substitute natural gas) A manufactured product, chemically similar
in most respects to natural gas, resulting from the conversion or reforming of hydrocarbons that may easily be
substituted for or interchanged with pipeline-quality natural gas.” EIA, “Glossary,” 2020, https://www.eia.gov/tools/
glossary/index.php?id=S.
28 DOE, Office of Energy Efficiency and Renewable Energy, Hydrogen Production: Natural Gas Reforming, 2020,
https://www.energy.gov/eere/fuelcells/hydrogen-production-natural-gas-reforming.
29 National Energy Technology Laboratory, “Gasification Introduction,” 2020, https://www.netl.doe.gov/research/Coal/
energy-systems/gasification/gasifipedia/intro-to-gasification.
30 CRS In Focus IF11501, Carbon Capture Versus Direct Air Capture, by Ashley J. Lawson.
31 Dale Gardner, “Hydrogen Production from Renewables,” Renewable Energy Focus, January 1, 2009,
http://www.renewableenergyfocus.com/view/3157/hydrogen-production-from-renewables/.
32 Thermal decomposition, or thermolysis, is the splitting of water at very high temperatures. Ibid.
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photons are used in biological or electrochemical systems to produce hydrogen
directly.
The article stated that the order of the listing of the technologies is “in general, also representative
of the technological maturity of these pathways, and thus roughly the chronological order in
which we might expect to see them commercially available.”33 This perspective aligns with that
of the Department of Energy’s expected time frames for these technologies (see Figure 1).
Nuclear Power for Hydrogen Production
Nuclear power plants could also be used to produce hydrogen through electrolysis and other
methods. According to the Department of Energy,
Nuclear power plants can produce hydrogen in a variety of methods that would greatly
reduce air emissions while taking advantage of the constant thermal energy and electricity
it reliably provides. Existing nuclear plants could produce high quality steam at lower costs
than natural gas boilers and could be used in many industrial processes, including steam-
methane reforming. However, the case for nuclear becomes even more compelling when
this high-quality steam is electrolyzed and split into pure hydrogen and oxygen. A single
1,000 megawatt [MW] nuclear reactor could produce more than 200,000 tonnes of
hydrogen each year. Ten nuclear reactors could produce about 2 million tonnes annually
or one-fifth of the current hydrogen used in the United States.34
Exelon Corporation plans to install a one MW electrolyzer to demonstrate hydrogen production at
one of its nuclear power plants. The installation would be a part of the DOE’s H2@Scale
initiative, a program that is exploring the potential for wide-scale hydrogen production and
utilization in the United States.35
Commercial Readiness
Figure 1 presents the Department of Energy’s perspective on the timing of commercial-readiness
and production scales associated with various hydrogen production technologies. These
technologies are summarized in the following paragraphs. More detail on several of the methods
discussed below is provided in the Appendix.

33 Ibid.
34 DOE, “Could Hydrogen Help Save Nuclear?,” November 26, 2018, https://www.energy.gov/ne/articles/could-
hydrogen-help-save-nuclear.
35 S&P Global Market Intelligence, “Exelon Expects to Soon Name Nuclear Plant Getting Hydrogen Electrolyzer,”
June 9, 2020, https://www.spglobal.com/marketintelligence/en/news-insights/latest-news-headlines/exelon-expects-to-
soon-name-nuclear-plant-getting-hydrogen-electrolyzer-58968111.
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Figure 1. Hydrogen Production Technologies
Time frames and production scales

Source: U.S. Department of Energy, Office of Energy Efficiency and Renewable Energy at
https://www.energy.gov/eere/fuelcells/hydrogen-production.
Notes: Solar thermochemical hydrogen (STCH); Photoelectrochemical (PEC); Carbon Capture and
Sequestration (CCS); Production and Delivery (P&D); Research and Development (R&D).
Hydrogen for Large Scale Electric Power Generation
Hydrogen burned as a fuel could lower GHG emissions, since hydrogen combustion does not
produce CO2. The potential use of hydrogen as a fuel for electric power generation is based
largely on its high energy density. According to DOE:
Hydrogen has the highest energy per mass of any fuel; however, its low ambient
temperature density results in a low energy per unit volume, therefore requiring the
development of advanced storage methods that have potential for higher energy density….
On a mass basis, hydrogen has nearly three times the energy content of gasoline—120
[megajoules per kilogram (MJ/kg)]36 for hydrogen versus 44 MJ/kg for gasoline. On a
volume basis, however, the situation is reversed; liquid hydrogen has a density of 8
[megajoules per liter (MJ/L)] whereas gasoline has a density of 32 MJ/L.37
Hydrogen has characteristics that may be useful as a power generation fuel, including its wide
flammability limits (e.g., once a hydrogen stream is ignited, it is easy to maintain a hydrogen
flame), a high spontaneous ignition temperature of 650o C (i.e., it needs a spark to ignite below

36 One megajoule per kilogram (MJ/kg) is approximately equivalent to 430 British thermal units per pound (Btu/lb).
37 DOE, “Hydrogen Storage,” 2020, https://www.energy.gov/eere/fuelcells/hydrogen-storage.
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this temperature and so enhances safety), and the primary product of its combustion is water (as
the hydrogen combines with oxygen to form H2O) with little or no CO2 emissions.38
Hydrogen-Fueled Combustion Turbines
Hydrogen has characteristics that make it an attractive choice as a fuel. However, shifting electric
power generation from natural gas to hydrogen would likely require hundreds of billions of
dollars of investment by the electric power industry.
Hydrogen’s high flammability means that it burns at a high temperature that makes it unsuitable
for use directly in the combustion turbines used to burn natural gas today. An article in 2019
addressed the question of what effect hydrogen would have on the furnace, flame, and exhaust in
a natural gas combustion plant.39 In addition to identifying several advantages of hydrogen, it
cited several disadvantages as well:
 the higher flame speed, which increases the flame temperature locally, which can
generate high levels of nitrogen oxides (NOx), pollutants which contribute to
ozone formation (a precursor to smog);
 the wide flammability, which would require consideration in the safety
assessments;
 hydrogen has a different Wobbe Index40 than methane, which has to be taken into
account in design; and
 hydrogen has a different combustion air requirement index (a measurement of the
air required for a gas to ignite) compared to methane (and therefore would
necessitate modifications to most combustion turbines to allow the use of
hydrogen as a fuel).
Nevertheless, the article concluded that there “are many ways of accommodating high hydrogen
fuel gases [e.g., fuel mixtures with a high proportion of hydrogen] whilst still keeping the flame
cool enough to minimize [NOx] formation. The key is to slow down the rate at which the fuel and
air mix.”41
According to Bloomberg New Energy Finance (BNEF), since the 1990s, “there have been about
150 to 200 turbines globally that used gases with different amounts of hydrogen…. About 30 to
50 of the units likely operated with hydrogen making up more than 50% of the fuel volume.”42
Another article in Power Engineering reported that today’s natural gas-fired turbines would
require modifications to the combustion elements to burn hydrogen. The compressor, turbine
fans, and other auxiliary components would be expected to remain the same. However, due to the

38 Mike Menzies, Hydrogen: The Burning Question, September 23, 2019, https://www.thechemicalengineer.com/
features/hydrogen-the-burning-question/.
39 Ibid.
40 “The Wobbe Index is a measure of the interchangeability of fuel gases and their relative ability to deliver energy. It
gives an indication of whether a turbine or burner will be able to run on an alternative fuel source without tuning or
physical modifications.” Native Dynamics, “Wobbe Index,” 2020, https://neutrium.net/properties/wobbe-index/.
41 Mike Menzies, Hydrogen: The Burning Question, September 23, 2019, https://www.thechemicalengineer.com/
features/hydrogen-the-burning-question/.
42 Will Mathis and Akshat Rathi, “Green Hydrogen Could Price Gas Out of Power Markets by 2050,” Bloomberg New
Energy Finance, January 14, 2020, https://www.bloomberg.com/news/articles/2020-01-14/green-hydrogen-could-price-
gas-out-of-power-markets-by-2050.
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lower volumetric energy density of gaseous hydrogen, some piping and valves would have to be
larger to accommodate the higher gas volumes necessary to produce the same energy content.43
One recent article estimates that replacing natural gas-fired power generation with hydrogen-fired
power generation would require an investment of $637 billion by 2050 for hydrogen storage
infrastructure alone to provide the same level of energy security.44
Some of the newer gas turbines currently in service may possibly be converted to burn a mixture
of natural gas and hydrogen, while many older turbines may not be suitable for a retrofit.
In the U.S., [Mitsubishi Hitachi Power Systems (MHPS)] recently was awarded a contract
by Intermountain Power Agency to supply two of its M501JAC gas-fired turbines for a
long-term hydrogen transition project in Utah. The M501JACs will utilize a 30-percent
mix of hydrogen in only five years, with the long-term goal to burn 100 percent by 2045.45
Control of the flame temperature in combustion turbines burning a hydrogen-natural gas mixture
is an issue that may need to be addressed to minimize NOx emissions. NOx control technologies
are required for all fossil-fueled power generators, including natural gas-fired combustion
turbines. However, current designs for hydrogen-fueled turbines “will emit the same NOx levels
as natural gas-fired systems today, but will emit no sulfur dioxide, particulate matter, nor carbon
dioxide and will only have a water byproduct.”46
Advanced NOx emission technologies are being developed and deployed in new gas turbines.
Using [dry low emissions (DLE)] burners, the flame temperature is controlled and kept the
same. However, the more compact flame, near the burner tip, tends to raise NOx emission
levels slightly. This latter can most likely be improved by tuning of the burner design but
also mitigated by secondary NOx emission control systems.47
Fuel Cells for Hydrogen Power
Fuel cells use the chemical energy of hydrogen or another fuel “to cleanly and efficiently produce
electricity.”48 If the fuel cell uses hydrogen as the fuel, “electricity, water, and heat are the only
products.” DOE states that fuel cells “can provide power for systems as large as a utility power
station and as small as a laptop computer.”49

43 Rod Walton, “Just What Goes into Converting a Gas-Fired Turbine to Hydrogen? The MHPS Perspective on
Carbon-Free Thermal Power,” Power Engineering, March 12, 2020, https://www.power-eng.com/2020/03/12/just-
what-goes-into-converting-a-gas-fired-turbine-to-hydrogen-the-mhps-perspective-on-carbon-free-thermal-power/.
44 “Hydrogen Economy Outlook,” Bloomberg New Energy Finance, March 30, 2020, https://data.bloomberglp.com/
professional/sites/24/BNEF-Hydrogen-Economy-Outlook-Key-Messages-30-Mar-2020.pdf.
45 Rod Walton, “Hydrogen-Fired Power Promises Carbon-Free Future but Requires Nearly $800B Investment,” Power
Engineering, March 30, 2020, https://www.power-eng.com/2020/03/30/hydrogen-fired-power-promises-carbon-free-
future-but-requires-nearly-800b-investment/.
46 Rod Walton, “Just What Goes into Converting a Gas-Fired Turbine to Hydrogen? The MHPS Perspective on
Carbon-Free Thermal Power,” Power Engineering, March 12, 2020, https://www.power-eng.com/2020/03/12/just-
what-goes-into-converting-a-gas-fired-turbine-to-hydrogen-the-mhps-perspective-on-carbon-free-thermal-power/.
47 Gas Turbine World, “Working Toward 100% Hydrogen,” March 20, 2020, https://gasturbineworld.com/working-
toward-100-percent-hydrogen/.
48 DOE, Energy Efficiency and Renewable Energy-Fuel Cell Technologies Office, “Fuel Cells,” 2020,
https://www.energy.gov/eere/fuelcells/fuel-cells.
49 Ibid.
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Fuel cells are classified according to the type of electrolyte they use, and are designed to meet
different operating requirements. Fuel cells do not burn their fuel, but use an efficient
electrochemical reaction to produce electricity.
Fuel cells can operate at higher efficiencies than combustion engines, and can convert the
chemical energy in the fuel to electrical energy with efficiencies of up to 60% [compared
to existing fossil power plants with efficiencies about 40%]. Fuel cells have lower
emissions than combustion engines. Hydrogen fuel cells emit only water, so there are no
carbon dioxide emissions and no air pollutants that create smog and cause health problems
at the point of operation.50
While fuel cells were first used in mostly niche applications, electric utilities are increasing their
deployment of fuel cells.
More homes, businesses and utilities are turning to fuel-cells to meet their power
generation needs. Installing groups of modular fuel-cell systems to create small power
plants ranging from 5 MW to 63 MW in size is a growing market…. In addition, fuel cells,
which use hydrogen and oxygen to generate electricity, have no moving parts, making them
inherently quiet and ideal for use in urban settings where the power is actually consumed.
This limits the need for transmission and distribution lines, thus reducing the risk of power
outages caused by ice storms and heavy winds…. Fuel cells are not a new technology. They
have been long associated with the NASA space program and transportation vehicles. In
recent years, though, the applications and markets for fuel cells have expanded. Fuel cells
are being used for primary power, backup power, emergency power, and auxiliary power.
They are used to power hotels, hospitals, universities, and data centers.51
Several large-scale fuel-cell power plants have been built in Connecticut, Delaware, and
California.52
Energy Carrier to Fuel
Using an electrolyzer, hydrogen can be produced directly from water. Assuming GHG emissions
are a consideration, the power for the process would be produced using low carbon or carbon-free
energy such as wind, solar photovoltaic (PV), or nuclear power, and the hydrogen produced could
be stored until a time of day when higher prices of electricity would favor the conversion of that
hydrogen back to electricity. This has been described as the arbitrage opportunity for energy
storage.53 Electricity demand and production varies during the day, and the opportunity exists to
store energy during low demand periods and use it during high demand periods. Electrolyzers can
be used to supplement power generation at peak periods to avoid the need to build additional
generation capabilities. Using this cycle, both hydrogen and electricity would be produced free of

50 Ibid.
51 Russell Ray, “Fuel Cells to Play Important Role in Power Generation,” Power Engineering, February 15, 2016,
https://www.power-eng.com/2016/02/15/fuel-cells-to-play-important-role-in-power-generation/.
52 Jeff St. John, “Bloom Energy and Power Secure Land Country’s Biggest Fuel Cell Deployment to Date,” Greentech
Media, August 16, 2017, https://www.greentechmedia.com/articles/read/bloom-energy-and-powersecure-land-
countrys-biggest-fuel-cell-deployment-to.
53 “An arbitrage opportunity … exists under some circumstances to take advantage of power storage in regulatory
regimes that attach value to such opportunities. Under such a scenario, electricity can be purchased from the grid and
stored during times of lower demand. An energy storage system can be charged at this time so that the stored energy
can be used or sold at another time when the price or costs are higher. Alternatively, energy storage can provide the
opportunity to store excess energy production that may otherwise be curtailed from renewable sources such as wind or
solar PV.” See CRS Report R45980, Electricity Storage: Applications, Issues, and Technologies, by Richard J.
Campbell.
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GHG emissions. Producing and taking advantage of hydrogen for energy storage is the first step
to taking advantage of the arbitrage opportunity. The second step is to use hydrogen to generate
power, in this case using a fuel cell, to send power back to the grid. At present, two different
devices are needed for the electrolyzer and power generation processes.54
Estimates of the Cost of Producing Hydrogen
Since hydrogen gas does not occur naturally in abundance on the Earth, it has to be produced
from other hydrogen-containing compounds. Table 1 summarizes recent estimates of the cost of
producing hydrogen using selected technologies, and the estimated efficiencies of the selected
processes are also summarized. The table shows how the efficiency of the steam reforming
process using a low cost natural gas feedstock is a key factor in achieving the low cost of
hydrogen production.
A report from BNEF in 2020 considered how to bring down the cost of producing hydrogen from
renewable sources.55 BNEF estimates the current cost of producing renewable hydrogen in 2018
dollars at about $2.50 to $4.50 per kg (or approximately $18.60 to $33.50 per million BTUs).
This compares to BNEF’s estimate of fossil fuel-derived hydrogen of $1.00 to $1.75 per kg
(equating to approximately $7.40 to $13 per million BTUs).
By comparison, the per BTU price of hydrogen is much higher than the per BTU price of natural
gas (currently below $2 per million in several markets). This cost difference presents a long-term
challenge to the use of hydrogen as a substitute for natural gas.56 BNEF’s report suggested that
one approach to addressing this challenge would be a tax on carbon emissions.57 The report
suggested a carbon price of $55 per ton of carbon dioxide by 2050, equating to a price of natural
gas at least $6.50 per million BTU. BNEF estimates that by 2050, renewable hydrogen could be
produced at prices between $0.80 to $1.60 per kg, if such policies were in place.58

54 “[C]ommercial electrolyzers and fuel cells use different catalysts to speed up the two reactions, meaning a single
device can’t do both jobs. To get around this, researchers have been experimenting with a newer type of fuel cell,
called a proton conducting fuel cell (PCFC), which can make fuel or convert it back into electricity using just one set of
catalysts.” Robert F. Service, “New Fuel Cell Could Help Fix the Renewable Energy Storage Problem,” Science,
March 12, 2019, https://www.sciencemag.org/news/2019/03/new-fuel-cell-could-help-fix-renewable-energy-storage-
problem.
55 Will Mathis and Akshat Rathi, “Green Hydrogen Could Price Gas Out of Power Markets by 2050,” Bloomberg New
Energy Finance, January 14, 2020, https://www.bloomberg.com/news/articles/2020-01-14/green-hydrogen-could-price-
gas-out-of-power-markets-by-2050.
56 EIA, “Natural Gas Weekly Update,” April 15, 2020, https://www.eia.gov/naturalgas/weekly/.
57 Will Mathis and Akshat Rathi, “Green Hydrogen Could Price Gas Out of Power Markets by 2050,” Bloomberg New
Energy Finance, January 14, 2020, https://www.bloomberg.com/news/articles/2020-01-14/green-hydrogen-could-price-
gas-out-of-power-markets-by-2050.
58 Rod Walton, “Hydrogen-fired Power Promises Carbon-Free Future but Requires Nearly $800B Investment,” Power
Engineering, March 30, 2020, https://www.power-eng.com/2020/03/30/hydrogen-fired-power-promises-carbon-free-
future-but-requires-nearly-800b-investment/.
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Table 1. Selected Hydrogen Production Methods
Selected Factors for Comparison
Estimate
of
Hydrogen
Process
Estimated Cost
Production
Feedstock
Efficiency
of H2 (2018)
Method
Considered
Advantages
Disadvantages
(%)
$/kg
Steam
Natural Gas
Developed
CO, CO2
74–85
1.80-2.27
Reforming
technology and
produced. Price
existing
volatility of natural
infrastructure.
gas can lead to
feedstock supply
issue.
Partial
Petroleum coke
Established
Along with H2
60–75
1.48
Oxidation
technology.
production, heavy

oils and soot can
result depending on

feedstock used.

Gasification
Coal or Biomass Abundant,
Fluctuating H2
30–40
1.63–2.05
cheap
yields due to
feedstock.
feedstock
impurities, and
seasonal biomass
availability.
Formation of tar.
Pyrolysis
Biomass
Abundant,
Tar formation.
35–50
1.59–1.70
cheap
Fluctuating H2
feedstock.
yields because of
feedstock
impurities and
seasonal availability.
Electrolysis
Water
Established
Storage and
60–80
7.50-10.30
technology
transportation
Zero emissions.
issues.
Existing
infrastructure.
O2 as a
byproduct.
Source: CRS. Adapted from S. Shiva Kumar and V. Himabindu, “Hydrogen Production by PEM Water
Electrolysis—A Review,” Materials Science for Energy Technologies, vol. 2, no. 3 (December 2019), pp. 442-454,
and Abdalla M.Abdalla, Shahzad Hossein, and Ozzan B. Nisfindy, et al., “Hydrogen Production,Storage,
Transportation and Key Challenges with Applications: A Review,” Energy Conversion and Management, vol. 165
(July 1, 2018), pp. 602-627. Wil Mathis and Akshat Rathi, “Big Oil’s Long Bet on Hydrogen Offers a Climate
Lifeline,” Bloomberg New Energy Finance, June 25, 2020, https://www.bloomberg.com/news/articles/2020-06-25/
big-oil-s-long-bet-on-hydrogen-offers-a-climate-lifeline.
Notes: Cost is given per unit of mass (in kilograms (kg)) as of 2018. CO = Carbon monoxide. CO2 = Carbon
dioxide. H2 = Hydrogen (molecular). O2 = Oxygen (molecular). Efficiency estimates are from the Faradaic
efficiency, defined as the ratio between experimentally evolved volume of gas value (hydrogen or oxygen) and
theoretically calculated volume of gas value.
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Further Electrifying the U.S. Economy
As of 2018, the transportation sector surpassed the power generation sector as the main source of
U.S. GHG emissions.59 If reducing GHG emissions is a goal for Congress, then Congress may
consider measures focused on fossil fuel use in both sectors, as well as in the industrial sector. A
transition from internal combustion engines in transportation to all-electric or fuel cell vehicles
could contribute to further electrification of U.S. transportation. Such a transition may take into
account the different ways that transportation and industry use fossil fuels, and consider what
applications could economically and efficiently substitute electricity-based technologies for fossil
fuels.
NREL’s Electrification Futures Study
In 2017, the National Renewable Energy Laboratory (NREL) issued the first part in its
Electrification Futures Study (EFS), which was intended to “develop and assess electrification
scenarios designed to quantify potential energy, economic, and environmental impacts to the U.S.
power system and broader economy.”60 This first report was focused on estimated cost and
performance data for end-use technologies for the transportation, residential, and commercial
buildings sectors through 2050.61
In 2018, NREL issued the second report from the study, and focused on how the potential for
electrification might impact the demand side of the U.S. energy system. The report presented
scenarios with various degrees of future electrification in all major end-use sectors of the U.S.
energy system and quantifies impacts on the amount and shape of electricity demand.62 The
scenarios reflected electricity demand growth ranges through 2050 that resulted from “various
electric technology adoption and efficiency projections in the transportation, residential and
commercial buildings, and industrial sectors.”63
Among the conclusions reached by the report (with emphasis added):
The transportation sector experiences the greatest technology transition toward electric
vehicles in the scenarios from this study…. These estimates foresee ranges of stock
penetrations of plug-in electric vehicles in the 2050 light-duty fleet from roughly 11% in
the Reference scenario to nearly 84% in the High scenario…. This expansion is most
pervasive in the High scenario, which is designed to include plug-in electric vehicle
sales shares beyond many existing studies and where over 240 million light-duty
electric cars and trucks, 7 million medium- and heavy-duty electric trucks, and 80,000

59 EPA, “Sources of Greenhouse Gas Emissions,” 2020, https://www.epa.gov/ghgemissions/sources-greenhouse-gas-
emissions.
60 National Renewable Energy Laboratory, Electrification Futures Study, 2020, https://www.nrel.gov/analysis/
electrification-futures.html.
61 “These projections will be used in future EFS reports to present a range in comparative electricity use and cost across
electrification scenarios, highlighting the uncertainty inherent in such values…. These costs can appropriately be used
as rough initial approximations for the types of cost, the relative costs among options, and the order of magnitude of
costs of end-use electrification.” Paige Jadun, Colin McMillan, and Daniel Steinberg, et al., Electrification Futures
Study: End-Use Electric Technology Cost and Performance Projections Through 2050, National Renewable Energy
Laboratory, 2017, https://www.nrel.gov/docs/fy18osti/70485.pdf.
62 However, for this analysis, NREL focused only on direct electric technologies and the impacts of electrification:
“[W]e make no attempt to compare a broader suite of technology or fuel (e.g., hydrogen- or biomass-based) options....”
Trieu Mai, Paige Jadun, and Jeffrey Logan, et al., Electrification Futures Study: Scenarios of Electric Technology
Adoption and Power Consumption for the United States, National Renewable Energy Laboratory, 2018,
https://www.nrel.gov/docs/fy18osti/71500.pdf.
63 Ibid.
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electric transit buses are estimated to be on U.S. roads by 2050. For comparison, there
were about 560,000 plug-in electric vehicles on U.S. roads by the end of 2016.…
The buildings and industrial sectors generally see less potential for transformational change
nationwide, but electrification in these sectors could acutely affect certain regions and end
uses. Still, a significant increase in building appliance manufacturing and adoption would
be needed in our scenarios as the electric devices are found to provide up to 61% of space
heating, 52% of water heating, and 94% of cooking services in the combined commercial
and residential sectors by 2050 in the High scenario, compared with 17%, 26%, and 34%,
respectively, in the Reference scenario.…
Electrification has the potential to significantly increase overall demand for electricity,
although even in the High scenario, compound annual electricity consumption growth rates
are below long-term historical growth rates. The Reference scenario has the most limited
impacts from electrification, but continued growth in both population and the U.S.
economy leads to a compound annual growth rate (from 2016 to 2050) in electricity
demand of 0.65% and 4,722 terawatt-hours (TWh) of total consumption by 2050. In the
Medium and High scenarios, total 2050 electricity demand is estimated to be 934 TWh
(20%) and 1,782 TWh (38%) greater, respectively, than in the Reference. Compound
annual growth rates are found to be 1.2% and 1.6% in these scenarios, respectively. These
growth rates are well below the historical rate from 1950 to 2016 (4% per year), and fall
below the 1.8% per year growth rate observed over the same duration (34 years, 1982–
2016) as the study future period. However, comparing absolute year-to-year changes in
consumption (rather than compound annual growth rates) in the scenarios shows how
widespread electrification can lead to historically unprecedented growth. In the High
scenario, the average increase (during 2016–2050) in annual electricity consumption is
about 80 TWh per year, compared with 50 to 55 TWh per year over the prior 34 years. The
vast majority of this increase occurs in the transportation sector. Building electrification
leads to more-limited incremental growth in annual electricity consumption in part because
of the high efficiency of heat pumps and their partial displacement of inefficient electric
resistance heaters.…
In addition to growth in annual electricity consumption—driven to a large degree by greater
adoption of plug-in electric vehicles—electrification has the potential to significantly shift
load shapes, particularly due to increased reliance on electric heat pumps for space and
water heating needs…. In 2015, all states excluding those in or near the Pacific Northwest
are estimated to be primarily summer peaking, with a majority of the top 100 load hours
falling in June, July, or August. Under the Medium and High electrification scenarios,
growth in winter electricity consumption outpaces consumption in non-winter months in
many regions, in large part because of greater adoption of electric air source heat pumps in
the Midwest and Northeast regions, which have colder climates. Along with the shift in
when peak demand occurs, the size of the peak also increases. The aggregate and coincident
peak national hourly demand in 2050 is estimated to be 19% and 33% greater in the
Medium and High scenario, respectively, than in the Reference scenario, where peak
demand is estimated to reach 838 gigawatts (GW) in 2050…. How electrification impacts
load shape [i.e., hourly and seasonal demand] could have significant impact on
electric utility planning, grid operations, reliability assessments, and electricity
markets.…
Widespread end-use electric technology adoption would result in substantial shifts in fuel,
electricity, and total energy consumption. In 2050, electricity’s share (of total final energy)
increases to 32% in the Medium and 41% in the High scenario—significantly above the
23% in the Reference scenario and 19% in 2016…. The impacts to electricity share vary
significantly by sector, with the largest growth found in transportation for the Medium and
High scenarios and the least change occurring in industry. Consistent with observed trends
since 1950 the buildings sectors remain the most electrified in all scenarios and with
growing electricity shares of final energy. For example, the commercial buildings sector is
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nearly 75% electric under the High scenario. Electrification would also lead to reduced use
of gasoline, diesel, and natural gas fuel. Demand-side fuel use reductions of 74% gasoline,
35% diesel, and 37% natural gas in 2050 are found in the High scenario, relative to the
Reference. It is possible that some of the reduced on-site natural gas use would be
offset by greater gas-fired generation.64
One possible assessment that may reasonably be made from the report is that electrification
would increase demand for electricity, and natural gas use would likely increase. If no changes in
environmental regulations occur in the timeframe to 2050, then it would be reasonable to follow
EIA’s reference projections (discussed earlier in this report) that natural gas and renewable
sources would be the major generation sources by that time. NREL’s study does not directly
address the potential for climate change to drive electrification, instead positing environmental
benefits as one of several purposes for the study:
A second motivation for exploring electrification is the potential externality benefits of
electrification, including security and environmental benefits. As electricity relies almost
entirely on domestic generators and fuels in the contiguous United States, electrification
may increase energy security. Recent studies also identify electrification as [a] key
component of pathways to reducing greenhouse gas emissions. A related benefit is the
overall higher energy efficiency of electric technologies, which could—all else being
equal—reduce the negative impacts of energy use. However, the efficiency and
environmental benefits of electrification ultimately depend on sources used to generate
electricity.65
Challenges Associated with Hydrogen for Power
When hydrogen is discussed as a fuel for power generation, the technical challenges for its use
generally are focused on two areas: the storage of hydrogen and the transportation of hydrogen.
Due to its small molecular size, hydrogen gas is difficult to contain, which makes its storage or
transportation more challenging. In addition, at room temperature and standard atmospheric
pressure, hydrogen has low energy density per volume. Storing hydrogen requires the input of
external energy to cool or compress the gas.
Transportation of Hydrogen
According to DOE, the existing hydrogen gas pipeline network provides a low-cost option for
delivering large volumes of hydrogen.66
Approximately 1,600 miles of hydrogen pipelines are currently operating in the United
States. Owned by merchant hydrogen producers, these pipelines are located where large
hydrogen users, such as petroleum refineries and chemical plants, are concentrated such as
the Gulf Coast region.67
Beyond the initial high capital costs associated with pipeline construction, expanding the network
of pipelines for hydrogen transportation presents unique technical barriers. DOE states that
ongoing research is focusing on overcoming issues such as:

64 Ibid.
65 Ibid.
66 DOE-EERE, Office of Fuel Cell Technologies, “Hydrogen Pipelines,” 2020, https://www.energy.gov/eere/fuelcells/
hydrogen-pipelines.
67 Ibid.
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 the potential for hydrogen to embrittle the steel and welds used to fabricate the
pipelines;
 the need to control the potential for hydrogen permeation68 and leaks; and
 the need for lower cost, more reliable, and more durable hydrogen compression
technology.69
DOE is investigating potential methods to address these issues, including the use of fiber
reinforced polymer (FRP) pipelines for hydrogen distribution.70 DOE estimates that the
“installation costs for FRP pipelines are about 20% less than that of steel pipelines because the
FRP can be obtained in sections that are much longer than steel, minimizing welding
requirements.”71
Adapting the natural gas delivery infrastructure to accommodate hydrogen may be another
option, with natural gas pipelines prospectively carrying a blend of natural gas and hydrogen
(e.g., up to about 15% hydrogen content). DOE expects that converting existing natural gas
pipelines to deliver 100% hydrogen would likely require “more substantial modifications.”72
Other existing elements on pipeline systems, such as compressors for long distance transmission
and pressure reduction stations, may also be examined for the potential for leaks or “material
integrity concerns.”73
Hydrogen Storage
Hydrogen can be stored as either a gas or a liquid.
Storage of hydrogen as a gas typically requires high-pressure tanks (350–700 bar [5,000–
10,000 (pounds per square inch) psi] tank pressure). Storage of hydrogen as a liquid
requires cryogenic temperatures because the boiling point of hydrogen at one atmosphere
pressure is −252.8 °C.74
Storing hydrogen therefore requires the input of energy to compress the gas. For electric power
generation purposes, storage can potentially be accomplished in a large pressure vessel or a
cavern. “Very large amounts of hydrogen can be stored in constructed underground salt caverns of
up to 500,000 cubic meters at 2,900 psi, which would mean about 100 Gigawatt-hours (GWh) of
stored electricity.”75

68 “Hydrogen permeation is the diffusion of hydrogen ions through the thin metal isolation diaphragms used in pressure
transmitters either through interstitial or substitutional (vacancy) mechanisms.” Yokogawa Corporation of America,
Hydrogen Permeation, 2018, https://www.yokogawa.com/us/library/resources/application-notes/hydrogen-permeation/.
69 DOE-EERE, Office of Fuel Cell Technologies, “Hydrogen Pipelines,” 2020, https://www.energy.gov/eere/fuelcells/
hydrogen-pipelines.
70 Ibid.
71 Ibid.
72 Ibid.
73 Paul E.Dodds and Stéphanie Demoullin, “Conversion of the UK Gas System to Transport Hydrogen,” International
Journal of Hydrogen Energy, March 2, 2013, https://www.sciencedirect.com/science/article/pii/S0360319913006800.
74 DOE-EERE, Office of Fuel Cell Technologies, Hydrogen Storage, 2020, https://www.energy.gov/eere/fuelcells/
hydrogen-storage.
75 Energy Storage Association, Hydrogen Energy Storage, 2020, https://energystorage.org/why-energy-storage/
technologies/hydrogen-energy-storage/.
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DOE further states that “[a] national hydrogen infrastructure could require geologic
(underground) bulk storage to handle variations in demand throughout the year. In some regions,
naturally occurring geologic formations, such as salt caverns and aquifer structures, might be
used, while in other regions, specially engineered rock caverns are a possibility.”76
Bulk storage of natural gas in salt caverns is a common practice, and there are four existing salt
caverns used for hydrogen storage today.77
Estimate of the Cost of Hydrogen Storage and Transportation
Developing a system to transport and store hydrogen could entail substantial costs, whether for a
completely new system or a gradually upgraded and modified system.
According to a report from BNEF, to develop a system for hydrogen storage and transportation to
provide the same utility as the natural gas system that currently exists, “a huge, coordinated
program of infrastructure upgrades and construction would be needed. For instance, 3-4 times
more storage infrastructure would need to be built at a cost of $637 billion by 2050 to provide the
same level of energy security as natural gas.”78
Natural Gas Decarbonization On-Site
An article in 2018 looked at potential economic models for decarbonizing natural gas delivered to
a power plant or industrial facility, and producing a syngas.79 Under the scenarios presented in the
article, facilities (e.g., potentially power plants) receive natural gas from the natural gas pipeline
system and “transform it locally into hydrogen, capturing carbon, and eliminating the need for
hydrogen transport and storage, as natural gas is the energy carrier vector.”80
The direct application of natural gas decarbonization to carbon capture [can be
accomplished] in a natural gas combined cycle…. [N]atural gas enters a pyrolysis reactor
operating at 1,200 °C achieving a molar conversion of methane into hydrogen close to
80%. The gas output from the reactor is a mixture of hydrogen and natural gas, which is
almost 50/50 in weight.81
The author estimated that such a decarbonization and capture process would consume “[a]lmost
40% of the initial energy content of natural gas.” A main benefit of the process is that the carbon
emissions from natural gas combustion are avoided, and would avoid “the energy required for its
further sequestration or reduction for CO2 utilization.”82

76 DOE-EERE, Office of Fuel Cell Technologies, “On-Site and Bulk Hydrogen Storage,” 2020,
https://www.energy.gov/eere/fuelcells/site-and-bulk-hydrogen-storage.
77 Ibid.
78 BNEF, “‘Hydrogen Economy’ Offers Promising Path to Decarbonization,” March 30, 2020, https://about.bnef.com/
blog/hydrogen-economy-offers-promising-path-to-decarbonization/.
79 Alberto Abánades, “Natural Gas Decarbonization as Tool for Greenhouse Gases Emission Control,” Frontiers in
Energy Research, June 19, 2018, https://www.frontiersin.org/articles/10.3389/fenrg.2018.00047/full.
80 Ibid.
81 Ibid.
82 Ibid.
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Recent Legislation
A number of bills have been introduced in the 116th Congress proposing federal support for
hydrogen transportation infrastructure. Several other bills addressed hydrogen for (smaller scale)
energy storage applications. Also, a number of bills have been introduced that consider a goal of
100% renewable energy for electricity. However, these bills do not focus on hydrogen as a fuel
for electric power generation. Accordingly, these bills are not included in this summary.
Bills in the 116th Congress
Several bills have been introduced that would provide tax credits for carbon capture. However, it
may be unclear whether most of these would support hydrogen production. To the extent that a
carbon capture facility uses a syngas process, a potential pathway could exist for such a facility to
produce hydrogen gas. Two bills that explicitly include syngas processes are summarized below.
The Carbon Capture Improvement Act of 2019 (S. 1763), introduced in June 2019, would
authorize the issuance of tax-exempt facility bonds for the financing of qualified carbon dioxide
capture facilities. Carbon dioxide capture facilities in the bill would generally include any facility
capturing carbon dioxide emissions from fuel combustion, gasification, bioindustrial, and
fermentation processes, with certain exceptions.
The Carbon Capture Improvement Act of 2019 (H.R. 3861), introduced in July 2019, is a
companion bill to S. 1763.
Issues for Congress
An analysis by the U.S. Global Change Research Program completed in November 2018 found
that if GHG emissions continued at forecast rates and adaptation actions were not undertaken,
climate change impacts would damage U.S. infrastructure, communities, and the economy.83 With
growing amounts of today’s electricity coming from (generally GHG emissions-free) renewable
sources, some stakeholders advocate a shift of U.S. national electric power generation to come
from sources that do not emit carbon dioxide. However, natural gas for power generation is
expected to increase, and fossil fuel-fired power often fills in for the variable generation from
renewables.
If Congress chooses to pursue further GHG emissions reduction, then addressing carbon dioxide
emissions from natural gas may be an option. Removing carbon from natural gas or replacing
natural gas for electric power generation may not be easy or inexpensive, and if achieved, would
likely be accomplished in a phased approach over several decades. Alternatively, Congress may
examine how to lower the costs of producing and using hydrogen for power generation. In
addition, Congress may consider how to address the unrealized negative externalities of carbon
dioxide emissions, with a tax or some other limit on CO2 emissions as a potential option.84

Congress may consider further research, development, demonstration, and deployment of electric
power generation facilities that use hydrogen as a primary fuel, avenues for the transportation of
hydrogen to power plants, and methodologies for the economic conversion of natural gas to

83 U.S. Global Change Research Program, Fourth National Climate Assessment, November 2018,
https://nca2018.globalchange.gov/. See also CRS Insight IN11065, An Electric Grid Based on 100% Renewable
Energy?, by Richard J. Campbell.
84 CRS Report R45625, Attaching a Price to Greenhouse Gas Emissions with a Carbon Tax or Emissions Fee:
Considerations and Potential Impacts, by Jonathan L. Ramseur and Jane A. Leggett.
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hydrogen on-site at power plants. Congress may also consider avenues to accelerate a transition
to hydrogen for electric power plants and infrastructure, using tax incentives or credits for such
purposes.

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Appendix. Sources of Hydrogen
Natural Gas Reforming
With steam-methane reforming (SMR), natural gas (which is principally methane) under pressure
(3–25 bar),85 reacts with high temperature steam (700°C–1,000°C) in the presence of a catalyst in
the first part of a two-stage process. In the second stage, the gas mixture is passed through a
water-gas shift reactor86 with steam and a catalyst. This converts most of the carbon monoxide to
carbon dioxide, and produces more hydrogen. Carbon dioxide and other impurities are removed
from the resulting gas stream to leave mostly pure hydrogen.87 The SMR process also can be used
with other hydrocarbon fuels (e.g., ethanol, propane, gasoline) to produce hydrogen.88
Coal/Biomass Gasification
Coal is an organic hydrocarbon that can be used as a hydrogen source using gasification to extract
the hydrogen.
Specifically, hydrogen is produced by first reacting coal with oxygen and steam under high
pressures and temperatures to form synthesis gas, a mixture consisting primarily of carbon
monoxide and hydrogen. After the impurities are removed from the synthesis gas, the
carbon monoxide in the gas mixture is reacted with steam through the water-gas shift
reaction to produce additional hydrogen and carbon dioxide. Hydrogen is removed by a
separation system, and the highly concentrated carbon dioxide stream can subsequently be
captured and stored.89
Gasification would be accomplished in a gasifier, which is generally a high-temperature pressure
vessel. Oxygen (or air) and steam would directly contact the coal causing a series of chemical
reactions to occur that convert the feed to syngas, and ash/slag (mineral residues).90
Other feedstocks (such as forest or crop residues, and dedicated biomass crops) could potentially
be gasified. However, each feedstock has its own challenges with respect to availability, and the
degree of formation of undesirable materials (e.g., tars, CO and CO2) that can impact production
efficiency and facility maintenance.91

85 One bar = 14.5 pounds per square inch, or atmospheric pressure at sea level.
86 The water-gas shift reactor converts the carbon monoxide present in syngas into carbon dioxide and generates more
hydrogen.
87 Air Liquide, Steam Methane Reforming—Hydrogen Production, 2020, https://www.engineering-airliquide.com/
steam-methane-reforming-hydrogen-production.
88 DOE, Office of Energy Efficiency and Renewable Energy, “Hydrogen Production: Natural Gas Reforming,” 2020,
https://www.energy.gov/eere/fuelcells/hydrogen-production-natural-gas-reforming.
89 DOE, Office of Energy Efficiency and Renewable Energy, “Hydrogen Production: Coal Gasification,” 2020,
https://www.energy.gov/eere/fuelcells/hydrogen-production-coal-gasification.
90 National Energy Technology Laboratory, “Gasification Introduction,” 2020, https://www.netl.doe.gov/research/Coal/
energy-systems/gasification/gasifipedia/intro-to-gasification.
91 DOE- Office of Fossil Energy, “Gasification Systems,” 2020, https://www.energy.gov/fe/science-innovation/clean-
coal-research/gasification.
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Electrolysis of Water
Hydrogen can be produced directly from water. This can be accomplished using electrolysis,
which involves passing an electrical current between positive and negative electrodes through
water (containing various catalysts). Electrolysis breaks the chemical bonds present in the liquid
water molecule, separating the hydrogen and oxygen atoms into individual gases.92
The electrolysis process takes place at room temperature. A commonly used electrolyte in
water electrolysis is sulfuric acid, and the electrodes are of platinum (Pt), which does not
react with sulfuric acid. The process is ecologically clean because no greenhouse gases are
formed, and the oxygen produced has further industrial applications. However, in
comparison with the foregoing methods described, electrolysis is a highly energy-
demanding technology.93
According to one article,94 there are four main methods for electrolysis of water to produce
hydrogen:
 Alkaline water electrolysis takes advantage of free ions in alkaline95 water to conduct
electricity for electrolysis to occur. Alkaline electrolyzers contain a water solution
containing approximately 25% to 30% potassium hydroxide. Several megawatt industrial
electrolyzers are used in industry for large-scale production of hydrogen.
 Solid oxide electrolyzer cells use a solid oxide fuel cell that achieves the electrolysis of
water by using a solid oxide, or ceramic, electrolyte to produce primarily hydrogen gas
and oxygen.
 Microbial electrolysis cells (MECs) use bacteria that thrive in an electrochemical
environment to break down organic matter. When aided by the addition of a low voltage,
MECs can produce hydrogen gas.
 Proton exchange membrane (PEM) water electrolysis uses a polymer electrolyte
in the form of a thin, permeable sheet, and a platinum catalyst. In PEM water
electrolysis, water is electrochemically split into hydrogen and oxygen at the
respective electrodes (i.e., hydrogen at the cathode and oxygen at the anode).
Other Processes
Several other processes can be used to produce hydrogen from various fuel stock sources. These
processes are either recently developed or are reported to be less productive in terms of the
volumes of hydrogen produced. They include:
 Partial Oxidation. The process of partial oxidation reacts the methane and other
hydrocarbons in natural gas with a limited amount of oxygen (typically from air) that is

92 Christos M. Kalamara and Angelos M. Efstathiou, Hydrogen Production Technologies: Current State and Future
Developments, Hindawi, https://www.hindawi.com/journals/cpis/2013/690627/.
93 Ibid.
94 S. Shiva Kumar and V. Himabindu, “Hydrogen Production by PEM Water Electrolysis—A Review,” Materials
Science for Energy Technologies, December 2019, pp. 442-454, https://www.sciencedirect.com/science/article/pii/
S2589299119300035#b0210.
95 “The “alkaline” in alkaline water refers to its pH level. The pH level is a number that measures how acidic or
alkaline a substance is on a scale of 0 to 14. For example, something with a pH of 1 would be very acidic and
something with a pH of 13 would be very alkaline.” See Healthline, “What Is Alkaline Water?,” 2020,
https://www.healthline.com/health/food-nutrition/alkaline-water-benefits-risks.
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not enough to completely oxidize the hydrocarbons to carbon dioxide and water. With
less oxygen available, the reaction products contain primarily hydrogen and carbon
monoxide (and nitrogen, if the reaction is carried out with air rather than pure oxygen),
and a relatively small amount of carbon dioxide and other compounds. In a subsequent
water-gas shift reaction, the carbon monoxide reacts with water to form carbon dioxide
and more hydrogen. It can be a faster process than steam reforming and requires a smaller
reactor vessel. However, this process produces less hydrogen per unit of the input fuel
than is obtained by steam reforming of the same fuel.96
 Pyrolysis. In this process, an organic material, such as biomass, is heated in the absence
of oxygen. Because there is no oxygen present, the material does not combust but the
biomass components (e.g., cellulose, hemicellulose, lignin) that comprise the material
thermally decompose into combustible gases and charcoal. Pyrolysis of biomass produces
three products: one liquid (bio-oil), one solid (bio-char), and one gaseous (syngas). The
proportion of these products depends on several factors, including the composition of the
feedstock and process parameters. The amount of syngas produced depends on these
parameters, and may be in the range of 10% to 15% by weight.97
According to DOE, other technologies are being investigated to produce hydrogen.98 These
include direct solar water splitting (i.e., photolytic processes that use light energy to split water
into hydrogen and oxygen), and photobiological processes.99
 Thermochemical Water Splitting. This process uses high temperatures—from
concentrated solar power or from the waste heat of nuclear power reactions—and
chemical reactions to produce hydrogen and oxygen from water.
Thermochemical water splitting processes use temperatures of 500°–2,000°C to
drive a series of chemical reactions that produce hydrogen. The chemicals used in
the process are reused within each cycle, creating a closed loop that consumes
only water and produces hydrogen and oxygen.
 Photoelectrochemical (PEC) Water Splitting. The PEC water splitting process
uses semiconductor materials to convert solar energy directly to chemical energy
in the form of hydrogen. The semiconductor materials used in the PEC process
are similar to those used in photovoltaic solar electricity generation, but for PEC
applications the semiconductor is immersed in a water-based electrolyte, where
sunlight energizes the water-splitting process.
 Photobiological. With photobiological hydrogen production processes,
microorganisms (such as green microalgae or cyanobacteria) use sunlight to split
water into oxygen and hydrogen ions. The hydrogen ions can be combined
through direct (e.g., using enzymes) or indirect (e.g., using catalyts) routes, and
are released as hydrogen gas.

96 DOE, Office of Energy Efficiency and Renewable Energy, “Hydrogen Production: Coal Gasification,” 2020,
https://www.energy.gov/eere/fuelcells/hydrogen-production-coal-gasification.
97 U.S. Department of Agriculture, “What Is Pyrolysis?,” April 14, 2017, https://www.ars.usda.gov/northeast-area/
wyndmoor-pa/eastern-regional-research-center/docs/biomass-pyrolysis-research-1/what-is-pyrolysis/.
98 DOE, Office of Energy Efficiency and Renewable Energy, “Hydrogen Production Processes,” 2020,
https://www.energy.gov/eere/fuelcells/hydrogen-production-processes.
99 Ibid.
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 Photofermentative. Some photosynthetic microbes use sunlight as the driver to
break down organic matter, releasing hydrogen.
Gas permeable membranes100 are another potential technology for hydrogen separation, most
likely from syngas.
Membrane gas separation does not require moving parts; it has small footprint and it is a
compact system; it provides operating flexibility to feed fluctuations; it demands
comparatively lower energy requirement leading to lower operating costs; it does not
involves chemicals, make-up, and solvents; it is easy start-up and shut-down; it requires
minimal maintenance and operator attention; it allows a modular design; it requires
minimal utilities; and it is easy to control. Among the main drawbacks, it can be mentioned
no economy of scale due to the modular design; pretreatment of streams with particulates,
organic compounds, or moisture can be difficult and/or expensive; sensitivity to chemicals
can be problematic in some cases; requirement of electrical power for compression (high-
quality energy).101

Author Information

Richard J. Campbell

Specialist in Energy Policy

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100 “Gases with high solubility and small molecules pass through the membrane very quickly. Less soluble gases with
larger molecules take more time to permeate the membrane. In addition, different membrane materials separate
differently. The driving force needed to separate gases is achieved by means of a partial pressure gradient.” Evonik
Resource Efficiency GmbH, “Principle of Selective Permeation,” 2020, https://www.sepuran.com/product/sepuran/en/
pages/selective-permeation.aspx.
101 Patricia L. Mores, Ana M. Arias, and Nicolás J. Scenna, et al., Membrane-Based Processes: Optimization of
Hydrogen Separation by Minimization of Power, Membrane Area, and Cost, Molecular Diversity Preservation
International, November 12, 2018, https://www.researchgate.net/publication/328932122_Membrane-
Based_Processes_Optimization_of_Hydrogen_Separation_by_Minimization_of_Power_Membrane_Area_and_Cost.
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