![](images/Logos/Hydrogen-insight.jpg)
12 April
2023
By
Leigh Collins
![](images/images_04_18_2023/pic5.jpg)
US Treasury Secretary Janet Yellen, who will ultimately decide the new
definition for green hydrogen.
Photo:
Getty
Allowing
US green hydrogen projects to use existing renewables 'could increase
emissions by a factor of five'
As world waits for US Treasury to decide on rules for clean H2
production, research firm Energy Innovation finds that facilities
built using strict regulations would be profitable from day one.
Allowing US green hydrogen projects to use
existing renewable energy sources would result in 1.5 to five times
higher greenhouse gas (GHG) emissions than from grey hydrogen
production (from unabated fossil fuels), according to a new analysis
by San Francisco-based research firm Energy Innovation.
This is because that renewable energy, which
would have been used by the grid, would have to be replaced by coal-
and gas-fired power that would not otherwise have been generated.
The finding highlights the importance of the forthcoming US definition
of green hydrogen that the US Treasury is now working on — which will
determine which projects would be eligible for hydrogen tax credits of
up to $3/kg under Section 45V of last year’s Inflation Reduction Act
(IRA).
“A highly polluting start to the industry would
undermine public trust and support for hydrogen, as well as damage
credibility among [international] trading partners,” the research firm
explains in its new 38-page report, Policy Design for Robust Growth of
Clean Electrolytic Hydrogen in the United States.
It could also lead to legal challenges, given the IRA’s requirement to
account for lifecycle greenhouse gas emissions in clean hydrogen
production, and could drive up air pollution and electricity prices,
causing a public backlash.
A “loose” definition of green hydrogen could result in taxpayers
subsidising an increase in greenhouse gas emissions at a cost of $3bn
per million tonnes of renewable H2 while “worsening GHGs from hydrogen
production by up to five times and setting the industry up for failure
once the tax credits expire [after ten years]”.
Energy Innovation says that while some respondents to the Treasury’s
recent public consultation on the matter have argued that a stricter,
“accurate” definition that incorporates the three principles of
additionality, deliverability and time-matching (see below) would make
compliance too expensive and throttle the growth of green hydrogen,
that is very much not the case.
“Because these principles would be financially
viable from the start, [the US] Treasury should have confidence that
adopting accurate 45V guidance will spur robust growth of clean
electrolytic hydrogen [ie, produced using an electric current to split
water molecules into H2 and oxygen], reducing GHG emissions today and
long after the policy expires,” the report explains.
“Accurate 45V emissions accounting is essential for reducing near-term
and long-term GHG emissions, ensuring the clean hydrogen industry
maintains sustainable growth over time.
“Loose guidance would set the industry up for failure by propping up
business models and infrastructure that can’t survive without such
lucrative subsidies.”
The three principles
Designing an “accurate” system for green hydrogen production that does
not increase GHG emissions will require “a framework that adheres as
closely as possible to three principles”: additionality,
deliverability and time-matching.
“Additionality requires electrolyzers to draw electricity from new
sources of clean electricity that were induced as a direct result of
the electrolyzer coming online,” the report explains.
Additionality can be achieved in three ways: the
construction and use of new clean energy production facilities;
increasing an existing renewables project’s capacity, which it refers
to as an “uprate”; and using clean electricity that would have
otherwise been curtailed.
However, the study points out that “curtailment alone will rarely be
enough to finance electrolyzer deployments at today’s capital costs”.
“Even in high-renewable markets like California, curtailment is
minimal in much of the year. So, while an additionality framework
should ideally have a mechanism to give credit to capturing
otherwise-curtailed clean electricity, it should be viewed as a
supplement to building new clean energy projects rather than an option
that can support 45V-compliant projects by itself.”
“Deliverability” is defined as requiring “electrolyzers to use local
sources of clean electricity that are physically deliverable to the
electrolyzer, including accounting for congestion and transmission
line losses”.
This is crucial due to potential transmission constraints.
“Consider a new wind farm built in wind-rich West Texas [that is
supposed to power] an electrolyzer built in Houston [in east Texas].
During times of high congestion, West Texas wind is likely being
curtailed [because the local grid cannot cope with all the wind power
coming on line at the same time], while in import-constrained Houston,
the electrolyser might cause a local fossil-fuel resource to ramp up
[to meet its power demand].
“This dynamic can show up anywhere in the country
where transmission congestion limits the delivery of clean energy
resources to electrolyzers.”
To avoid this problem, electrolysers should be located within the same
“bidding zone” as the power source, Energy Innovation explains, while
acknowledging that these do not currently exist.
“Time-matching” is defined as the requirement for electrolyzers to run
at the same time as clean electricity generation”.
Without time-matching, a new solar farm delivering, say 100GWh of
clean energy a year could be said to power electrolysers around the
clock that require 100GWh of electricity annually. But in the real
world, the solar array could deliver more renewable energy during the
day than the electrolysers and even the local grid requires, while it
would produce zero power at night, when fossil-fuel power could well
be required to supply the electrolyser.
Project economics
Energy Innovation finds that green hydrogen projects using both
wind and solar resources that are “oversized” relative to the
electrolyser’s capacity will be “financially viable from the outset”
across much of the US if they can also sell power to the grid. It says
that this is the case even when power prices are low, the renewable H2
is sold for $1/kg (the same price as grey hydrogen made from steam
methane reformation) and current project costs are used.
For example, a 1MW electrolyser in West Texas
linked to 3MW of solar and 2MW of wind, would generate profits of
$143,000 per year. Most of the revenue (79%) would come from hydrogen
sales and the $3/kg tax credits, with 16% coming from selling excess
power to the grid, and 5% by selling electricity to the grid when the
wholesale power price is high. This project would see its electrolyser
operating at a capacity factor of 88.1% — ie, at 88.1% of its annual
maximum output.
Similarly, a 1MW electrolyser in southwest Minnesota, powered by 2MW
of solar and 4MW of wind, would generate profits of $61,000 annually,
it says.
“Electrolyzers do not need to run around the clock to be profitable,”
the study points out. “In fact, utilization does little to reduce the
cost of hydrogen beyond a 50-70% utilization rate, after which
electricity prices are the major determinant of hydrogen production
costs.
“This share will fall as electrolyzer capital costs continue to
decline, meaning more projects will be economic in more places with
time.
“When capital costs are lower and electrolyzers
only need to run 20-30% of the time to be profirable, solar-only
projects will become [economically] viable.”
The report adds that while some industrial hydrogen consumers may need
a constant 24-hour supply of H2, “this does not mean that
electrolyzers must run around the clock”.
“Instead, developers can oversize their electrolyzers relative to
their offtakers’ needs and build hydrogen storage to smooth
fluctuations in production.”
The study points out that the Treasury’s forthcoming rules for green
hydrogen production are so important that it “will largely determine
the climate impact of electrolytic hydrogen production and the
long-term growth and viability of the burgeoning clean hydrogen
industry”.
It concludes that because projects meeting the three principles will
be profitable from day one, the “Treasury should adopt accurate 45V
guidance with confidence that it will spur robust growth of clean
electrolytic hydrogen, supporting GHG emissions reductions today and
long after the policy expires.”
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