Mitsubishi Heavy Industries Technical Review Vol. 58 No. 3 (September 2021)
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Development of Hydrogen/Ammonia Firing
Gas Turbine for Decarbonized Society

MASAKAZU NOSE*1

TOMO KAWAKAMI*1

SOUSUKE NAKAMURA*2 HIDETOSHI KUROKI*3
MASAHITO KATAOKA*4 MASANORI YURI*5

In the midst of globally accelerating moves toward a decarbonized society, Mitsubishi
Power, Ltd. (Mitsubishi Power) has made continuous efforts to develop hydrogen/ammonia-firing
Gas Turbine Combined Cycle (GTCC) power generation systems. The development of a gas
turbine combustor that can operate with a mix of natural gas and 30 vol% of hydrogen has been
completed for large frame gas turbines. Mitsubishi Power is also developing a 100%hydrogen-firing combustor. A promising Gas Turbine Combined Cycle using ammonia is also
under development, facilitating energy transportation of hydrogen to further expand the lineup ofcarbon-free power generation systems. With these technologies, Mitsubishi Power is participatingin hydrogen-firing GTCC projects in Europe, North America and other continents targeting
commercialization in the mid-2020s.
By increasing hydrogen demand, especially through large-capacity and high-efficiency
GTCC systems, Mitsubishi Power is set to lead the establishment of an international hydrogen
supply chain and contribute to the realization of a decarbonized society.

|1. Introduction
In 2015, the "Paris Agreement", which constitutes the international framework on preventionof global warming, was adopted at COP 21. Since then, many governments, financial institutions,investors and companies throughout the world have committed to make efforts toward
decarbonization. The actual implementation of the agreement started in 2020 and movements
toward the achievement of CO2 emissions reduction targets are being proactively initiated aroundthe world. The EU, including the environmentally-advanced regions in northern Europe, hasalready announced guidelines for becoming carbon neutral by 2050. China and the United States,
which are the world's largest and second largest CO2 emitters, issued a joint statement recently
committing to cooperate on tackling global warming. Japan being a large energy-consuming
country and mostly dependent on imports for its energy has also committed to become carbon
neutral by 2050.
The Great East Japan Earthquake in 2011 triggered substantial efforts to dispatch renewableenergy, however, roughly 80%(1) of the total electricity supply in the country is produced fromthermal power generation which emits considerable CO2. The degree of dependence on thermal
power generation still remains high representing approximately 44% of the total primary energy
consumption.
GTCC systems provide highly-efficient power generation, therefore emitting the lowest
amount of CO2 among conventional thermal power generation systems. The GTCC deployment*1

Chief Staff Manager, Large Frame Gas Turbine Engineering Department, Gas Turbine Technology & Products Integration
Division, Mitsubishi Power, Ltd.

*2

Manager, Large Frame Gas Turbine Engineering Department, Gas Turbine Technology & Products Integration Division,
Mitsubishi Power, Ltd.

*3

Director, Middle & Small Gas Turbine Engineering Department, Gas Turbine Technology & Products Integration Division,*4

Director, Large Frame Gas Turbine Engineering Department, Gas Turbine Technology & Products Integration Division,*5

Senior General Manager, Gas Turbine Technology & Products Integration Division, Mitsubishi Power, Ltd.

Mitsubishi Power, Ltd.
Mitsubishi Power, Ltd.

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will continue to meet growing energy demand while contributing to effort to reach a decarbonizedsociety. On the other hand, the acceleration of the introduction and dissemination of renewableenergy and the effective utilization of fossil fuels with consideration given to environmental impact
are required.
Mitsubishi Power has continuously worked on the development of decarbonization
technologies for thermal power generation. Development of advanced technologies for GTCC
power generation facilities are focused on:(1) reduction of CO2 emissions by a further increase in efficiency and capacity through higher
combustion gas temperature, and other key technologies(2)(2) promotion of technical development(3) for enhanced gas turbine flexibility targeting a rapid
and flexible response to compensate for power generation fluctuations resulting from theincrease of renewable energy use and(3) promotion of technical development of gas turbines using hydrogen (H2) or ammonia (NH3) as
fuel with lower or zero CO2 emissions, thereby aiming at realizing a decarbonized society by
2050.
In Japan, as a basic hydrogen strategy(4) for a decarbonized society targets thecommercialization of hydrogen power generation by around 2030. The development andcommercialization of technologies for the introduction of equipment to electric power companies
must be promoted in a short period of around 10 years. With the support of the New Energy andIndustrial Technology Development Organization (NEDO), the development of combustors
capable of operating on a mix of natural gas and 30 vol% of hydrogen have been successful forlarge frame gas turbines for power generation(5). The developed combustor is expected to lower the
hurdle for the implementation of hydrogen power generation and promote a smooth shift to ahydrogen society. With the continuous support of NEDO, 100% hydrogen-firing power generationis also under development. Research and development of a GTCC system using ammonia is also
under development, with the associated promising future as an effective hydrogen energy carrier.
This report presents Mitsubishi Power efforts toward the realization of a decarbonizedsociety, mainly covering prior studies about gas turbines for power generation under the applicationof hydrogen and ammonia for power generation projects around the world.

|2. Decarbonized society and gas turbines for power generation
Power generation using renewable energy, including wind and photovoltaic power
generation, will continue to spread and expand globally toward the realization of a decarbonizedsociety. There is an estimation(6) that the reduction of CO2 emissions through the utilization ofrenewable energy will account for about 30% of the total emission in 2060. The output ofrenewable energy is greatly affected by the ambient or meteorological conditions of the sites. The
effective utilization or storage of electric energy surplus needs to be addressed using batteries,
conversion into hydrogen and other technologies to avoid energy waste. Long and significant cycle
fluctuations can involve considerable amounts of energy, converting renewable energy intohydrogen for utilization is effective to avoid energy waste. GTCC power generation has thecapability and operability to follow abrupt output fluctuations of renewable energy and can flexibly
fill the gap between the electric power demand and the renewable energy output. In addition,
GTCC power generation can effectively use hydrogen as fuel, thereby producing large and stablehydrogen demand. Therefore, expectations for GTCC power generation have been growing.
A potential future scenario toward decarbonization is shown in Figure 1. In the mid-term,
the spread of fossil fuel-derived hydrogen (blue hydrogen) using Carbon Capture Utilization andStorage (CCUS) is expected. GTCC will offer increased power generation efficiency and reduced
CO2 emissions while providing conventional inexpensive, safe and stable power generation using
fossil fuels. The utilization of blue hydrogen will be promoted to generate power through theco-firing of hydrogen or ammonia fuels, which do not emit CO2. In the long term, cost reduction
and technical innovation will prioritize the use of renewable energy-derived hydrogen (greenhydrogen), eventually becoming mainstream with hydrogen-firing power generation using greenhydrogen helping reach the goal of eliminating CO2 emissions.
The use of hydrogen for large-capacity and highly-efficient power generation gas turbinesMitsubishi Heavy Industries Technical Review Vol. 58 No. 3 (September 2021)
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offers the environmental and economic advantages described below (Figure 2).
First, existing gas turbine facilities can be used with minimum modifications toward
decarbonization, mainly requiring adjustments of the gas turbine combustion components and fuelsupply systems. This reduce investment costs and lowers the cost hurdle for hydrogen conversion,
promoting a smooth transition to a hydrogen society.
Next, in addition to liquid hydrogen, hydrogen carriers such as methylcyclohexane andammonia can be transported and hydrogenerated to be used as fuel. There are flexible options for
carriers and hydrogen with lower purity can be used compared to hydrogen for fuel cell electricvehicles. Therefore, the hydrogen cost can be reduced.
Lastly, power generation hydrogen-firing gas turbines require large amounts of hydrogencompared to fuel cell electric vehicles (the hydrogen consumption of one large frame GT equates 2
million fuel cell vehicles). The hydrogen use for power generation is expected to facilitate largehydrogen demand and to promote the expansion of the supply chain and the reduction of hydrogencost.
As described above, it is considered that the utilization of hydrogen for large-capacity andhighly-efficient gas turbines for power generation has an essential and important role in realizing adecarbonized society.

Figure 1

Scenario toward decarbonization

Figure 2

Environmental and economic advantages of hydrogen gas turbines|3. Hydrogen-firing gas turbines
The key point in the development of hydrogen-firing gas turbines is the development of
combustors, which are the heart of gas turbines and combustion technologies.
Targeting higher efficiency for power generation large frame gas turbines typically involves
increase of the Turbine Inlet Temperature (TiT), as well as the combustion temperature, leading to
an exponential increase in NOx emissions. Mitsubishi Power large frame gas turbines applyMitsubishi Heavy Industries Technical Review Vol. 58 No. 3 (September 2021)
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premixing combustion method to the Dry Low NOx (DLN) combustor. Fuel and air is mixed prior
to combustion to reduce NOx emissions. This approach results in a lower flame temperature in the
combustor compared with the conventional diffusion combustion method, therefore, steam or water
injection for NOx reduction is unnecessary and prevents a decrease in the cycle efficiency. On theother hand, the stable combustion range is narrow, there is a risk of the occurrence of combustion
dynamics and backfire (flashback) and unburned hydrocarbons tend to be discharged.
Hydrogen has a higher combustion speed in comparison with natural gas. Therefore, in thecase of natural gas and hydrogen co-firing or hydrogen firing in a premixed combustor, the risk of
the occurrence of flashback is higher than firing natural gas. There is a possibility that flame fromthe flashback moves back upstream of the combustor, causing overheating of upstream
components. Therefore, combustors for hydrogen-firing gas turbines should be designed to prevent
flashback while also reducing NOx emissions with stable combustion. Figure 3 provides an
overview of Mitsubishi Power combustors for gas turbines hydrogen co-firing and hydrogen firing.

Figure 3(1)

Combustors for hydrogen-firing gas turbines

Dry Low NOx (DLN) multi-nozzle combustor for hydrogen co-firing
Figure 4 gives an overview of the newly developed combustor for hydrogen co-firing
based on the conventional DLN combustor. It aims reduced risk of flashback under operation
with hydrogen co-firing. The air supplied from the compressor to the combustor passes througha swirler and forms a rotating flow. Fuel is supplied from a small hole provided on the surfaceof the swirler and mixed rapidly with the surrounding air by the swirling flow. On the other
hand, a low flow rate region exists in the center part of the swirling flow (hereinafter referred toas "vortex core") and it is considered that flashback occurs as flame moves back toward the low
flow rate region. The new-type combustor injects air from the tip of the nozzle to raise the flow
velocity of the vortex core, so that the injected air compensates for the low flow velocity regionof the vortex core and prevents the occurrence of flashback.
The main combustion issues of gas turbine combustors are emissions, including NOx andcombustion oscillation. Since they are affected by the combustion pressure condition,verification is needed under actual equipment pressure condition. Combustion tests need to be
conducted under the actual equipment pressure (hereinafter referred to as "actual pressure
combustion test") using one full-scale hydrogen co-firing combustor out of 16 to 20 combustors(60 and 50 Hz respectively) installed in the actual equipment, to evaluate the hydrogen co-firing
effects on the combustion characteristics.

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Figure 4

Combustor for hydrogen co-firing

Figure 5 shows the change in NOx with respect to the hydrogen mixing ratio under air
and fuel ratio conditions in the test that correspond to the rated load of a gas turbine with aturbine inlet temperature of 1600°C. It was observed that as the hydrogen mixing ratio
increased, NOx gradually increased by a small amount. It is considered that when hydrogen ismixed in the fuel, the combustion speed increases, the flame position in the combustor moves
to the upstream and combustion occurs under an insufficient mix of fuel and air ratio. However,even under the condition where 30 vol% of hydrogen was mixed in the fuel, NOx was almost
the same as that in the operation with natural gas and no hydrogen, within the operable range.
Figure 6 shows the change in combustion dynamics under the same condition. The
combustion vibration pressure level is also equal to or lower than that in the operation withnatural gas and it was verified that the combustion dynamics was not greatly affected by achange in the hydrogen mixing ratio. In addition, no flashback was observed in 30 vol%hydrogen co-firing. With these test results, it became clear that the DLN multi-nozzle
combustor for hydrogen co-firing can be operated without the occurrence of flashback or asignificant increase in combustion dynamics.

Figure 5 Change in NOx with respect tohydrogen mixing ratio(when NOx is 1 with 0% hydrogen)(2)

Figure 6 Change in combustion dynamics
with respect to hydrogen mixing ratio(when the combustion vibration 1 with
0% hydrogen)

Multi-cluster combustor for hydrogen firing
When the concentration of hydrogen becomes higher than 30% vol, the fuel and air
mixing method using swirling flow adopted for the hydrogen co-firing combustor described in
the previous section (shown in Figure 4) involves higher risk of flashback occurring in the low
flow velocity region of the vortex core. A smaller scale of air and hydrogen mixing method
without applying swirling flow is considered to provide resistance to flashback. Mitsubishi
Power is developing a hydrogen-firing combustor based on the so-called multi-cluster designthat was developed for IGCC(7) applications and currently in operation at the Osaki CoolGen

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facility in Japan. This design shown in Figure 7, has a greater number of fuel supply holes
compared to the eight nozzle design of the hydrogen co-firing combustor described in the priorsection. The size of the holes is smaller. It is possible to mix supplied air and hydrogen on asmaller scale resulting in a more effective flame dispersion allowing high flashback resistanceand lower NOx combustion.

Figure 7(3)

Multi-cluster combustor

Diffusion combustor
A diffusion combustor injects fuel and combustion air separately into the combustor.
Compared with the premixed combustion method, the flame temperature is higher and theamount of NOx emissions increases and imposes steam or water injection as a countermeasure
for NOx reduction. On the other hand, it features a relatively wide stable combustion range andis more tolerant to fuel property fluctuations.
Figure 8 shows Mitsubishi Power diffusion combustor. This mature design has a longtrack of successful operation with fuels featuring a wide range of hydrogen content (up to 90vol%). A long list of plants that have successfully operated with these combustors under highhydrogen content includes, among others, refineries and other industrial plants’ off-gas . These
include small to medium size gas turbine for power generation facilities and also succeeded in ahydrogen-firing combustion test as part of the International Clean Energy Network Using
Hydrogen (World Energy NETWORK (WE-NET) technological research and development
project(8). The application of this diffusion combustor to the hydrogen-firing conversion
project at Vattenfall's Magnum power plant in the Netherlands will be described in point 5
below.

Figure 8

Diffusion combustor|4. Ammonia-firing gas turbine
The stable application of large amount of hydrogen for a large frame gas turbine for powerMitsubishi Heavy Industries Technical Review Vol. 58 No. 3 (September 2021)
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generation imposes stringent requirements to its supply chain including production, transportationand storage of hydrogen. One alternative to liquefied hydrogen is the use of other chemicalcompounds such as ammonia (NH3), methylcyclohexane and others, as carriers for transportationand storage of hydrogen. Compared to liquid hydrogen or methylcyclohexane, ammonia has ahigher volumetric hydrogen density and is a carrier that can transport and store hydrogen with highefficiency. In addition, existing transportation and storage infrastructure for liquefied petroleum gas
and other industrial applications can be used for ammonia simplifying the development ofhydrogen processing infrastructure. This facilitates hydrogen usage in remote locations including
islands where large-scale hydrogen infrastructure development is difficult. Ammonia can also be
directly combusted as a carbon-free fuel. Early introduction of ammonia-based power generationequipment is expected to be considered by power companies and independent power providers(IPPs) as a future use in a carbon-free fuel society.
Mitsubishi Power has commenced the development of a 40 MW-class gas turbine system forsmall to medium-scale power plants that uses 100% ammonia as a fuel for gas turbine power
generation. One challenge that is being addressed with the direct combustion of ammonia is the
production of nitrogen oxide (NOx) caused by oxidation resulting from the combustion of thenitrogen component of the fuel. Mitsubishi Power is aiming to resolve this issue through theestablishment and commercialization of a gas turbine system that combines NOx removal
equipment with a newly developed combustor that reduces NOx emissions. This is being applied to
the H-25 series gas turbines (output: 40MW class) shown in Figure 9(9). The direct combustion ofammonia has never been applied to this scale of power output gas turbine and it is expected that it
will increase demand of hydrogen and ammonia and contribute to decarbonization.

Figure 9

H-25 series gas turbine

Table 1 lists issues to be considered for the combustion of ammonia in large frame gas
turbines. Mitsubishi Power is evaluating the use of waste heat from a gas turbines in GTCC
systems used to reconvert ammonia into hydrogen and nitrogen as shown in Figure 10.
Simultaneous efforts include the developed hydrogen co-firing combustor or the developinghydrogen-firing combustor(10).
Decomposing ammonia requires heat in the order of 46 kJ per one mol of ammonia. This
heat is chemically recuperated through a 1.14 times increase in the heat value of the fuel as a resultof the conversion of ammonia to hydrogen. Therefore in principle, there is no reduction in thermal
efficiency with the exception of energy losses that take place at the gas processing unit installed
downstream of the ammonia decomposer.
Table 1

Characteristics of ammonia combustion and consideration for large frame gas turbine

Characteristics of ammonia combustion
Low combustion speed(about 1/5 of that of methane)

Nitrogen contained in fuelConsiderations for large frame gas turbines- The size of the combustor increases to secure the time necessary for completingthe combustion.
- Large frame gas turbines are limited in the size expansion of combustors because
they are multi-combustors.
- The combustion gas temperature of a large frame gas turbine is high and a large
amount of Fuel NOx is generated by the combustion of ammonia.
- Lowering of NOx by two-stage combustion is being considered, but in the case ofa large frame gas turbines, there are many technical problems such as upsizing
and complexity of the combustor.

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Figure 10 Concept of ammonia decomposition gas turbine cycle

It should be noted that in the combustion of ammonia decomposed gas, any trace amount ofresidual ammonia remaining after decomposition would be converted to fuel NOx in the
combustor. It is considered that the fuel NOx is emitted together with the NOx originally producedin the combustor. In order to meet the NOx emission standard value, it is necessary to determine
the amount of NOx increased by the remaining amount of ammonia. A combustion test under theactual pressure using a 1 650℃-class hydrogen co-firing gas turbine combustor was conducted toevaluate how the trace amount of remaining ammonia contained after decomposition affects NOx
while verifying the stability of combustion. Figure 11 shows the relationship between theconcentration of ammonia in the fuel and the concentration of NOx in exhaust gas at a JAC rated
condition turbine inlet temperature of 1650℃ and in co-firing of natural gas and ammonia
decomposition gas (fuel composition: 20 vol% of hydrogen, 6.7 vol% of nitrogen, 73.3 vol% ofnatural gas, trace amount of ammonia). As the concentration of ammonia in fuel increased, theconcentration of NOx increased linearly (indicated by ● marks in the figure) and the conversion
ratio of ammonia to NOx (CR in the figure: Conversion Ratio) was about 90%. Even if theconcentration of ammonia in fuel was changed, the pressure level of combustion dynamics did notlargely change, keeping a sufficient margin to the control value. It was verified that the combustion
was stable without the occurrence of flashback.
Through the development of the gas turbine systems using ammonia as described above, it isexpected to expand the lineup of carbon-free power generation systems.

Figure 11 Relationships between the concentration of ammonia in fuel and theconcentration of NOx in exhaust gas and between the concentration of ammonia in fueland combustion dynamics (at the turbine inlet temperature of 1650℃)|5. Overseas gas turbine projects toward decarbonization
Many comprehensive hydrogen utilization plans are being considered oversees. These
include the production, transportation, storage and utilization of hydrogen for the development oflarge-scale system ranging from the production to the utilization of renewable energy-derived greenhydrogen and plans for the development of systems including CCUS processing of CO2 generated
from hydrogen production under utilization of fossil fuel-derived blue hydrogen. Various effects
from the utilization of hydrogen are expected, such as an increase in the reliability andMitsubishi Heavy Industries Technical Review Vol. 58 No. 3 (September 2021)
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independence of energy in a region, job creation, avoidance of construction of uneconomical grids,
reuse of existing infrastructure and diversification of fuels in multiple industrial sectors.
Transnational projects have been implemented by nations, local governments and consortiums ofcompanies in cooperation.
Among them, three hydrogen gas turbine projects in Europe and the United States involve
Mitsubishi Power’s participation are described below.

5.1

Vattenfall's Magnum power plant

The first project is intended to convert a 1,320 MW-class natural gas-firing GTCC power
generation plant operated by Vattenfall, a Swedish energy company, to hydrogen-firing power
generation. This project aims to convert one of three M701F gas turbines power generation blocks
featured by the Vattenfall's Magnum power plant to a 100% hydrogen-firing power generation
plant by 2027. This plant shown in Figure 12, is located in the Groningen province in thenorthernmost part of the Netherlands. The initial feasibility study (FS) was conducted considering
the application of conventional diffusion combustor technology —and verified that the conversion
to hydrogen-firing power generation is possible. One line of 440 MW-scale natural-gas-firing
GTCC power generation units emits about 1.3 million tons of CO2 annually, most of which can be
reduced by conversion to a hydrogen-firing power generation plant. Evaluation, planning anddesign of specific modification ranges in the gas turbine technological field continue to be
conducted by Mitsubishi Power.

Figure 12 Vattenfall's Magnum power plantin the Netherlands

5.2

Humber Cluster/ Saltend Power Plant

The second project involves a decarbonization efforts for the UK's largest scale industrial
cluster in the delta area of the Humber River basin (east coast of Britain). Several companies andorganizations actively working on decarbonization related industries are globally expanding theirbusinesses toward the utilization of hydrogen (blue hydrogen) produced from natural gas withapplication of carbon dioxide capture and removal technologies, aiming net zero CO2 emissions by2040. In this project, Mitsubishi Power is conducting a technological and feasibility study of theconversion of one of the M701F gas turbines originally supplied to the Saltend Power Plant for thenatural gas-firing GTCC (Figure 13). This effort includes conversion of one unit to 30 vol%hydrogen co-firing toward full hydrogen firing in the future.

Figure 13 Saltend power plant in UKMitsubishi Heavy Industries Technical Review Vol. 58 No. 3 (September 2021)
105.3Intermountain Power Agency in Utah in the United States

The third project involves a brand new GTCC power generation using hydrogen planned by
the Intermountain Power Agency in Utah in the United States. Mitsubishi Power received an orderfor this 840 MW-class GTCC power generation facility with two M501JAC gas turbines as thecore. It aims achieving 30 vol% hydrogen co-firing power generation by 2025, followed by fullhydrogen firing by 2045. This project involves replacement of an existing coal-firing power
generation facility to reach initial CO2 emissions reduction in the order of up to 4.6 million tons per
year. The hydrogen fuel is expected to be supplied from an adjacent energy storage project using
renewable energy-derived electricity in Utah. Mitsubishi Power is involved in this effort and thegenerated electricity will be supplied from the Intermountain Power Plant to a wide area in Utah
and California across the Rocky Mountains.
Mitsubishi Power has promoted utilization of hydrogen for thermal power generation
through participation in various projects in Japan and overseas for power generation usinghydrogen including those mentioned above. Mitsubishi Power will continue generating momentum
for the Energy Transition to low environmental load contributing to the realization of adecarbonized society.

|6. Schedule toward commercialization
The introduction of hydrogen power generation is expected to start in the mid-2020s.
Mitsubishi Power will promote demonstrations using actual gas turbines for the next several years,
based on the results of past element developments, that have included verification tests for eachelement at the basic design stage, reflecting the test results in the detailed design and finallyconducting demonstration using actual equipment. By implementing this development cycle in thesame works, Mitsubishi Power has promoted rapid and secure development and commercialization.
Regarding hydrogen gas turbines, detailed demonstrations will be conducted on hydrogen co-firing(30 vol%) large frame gas turbines for near future commercialization as shown in Figure 14. These
efforts will be followed by commercialization of hydrogen-firing large frame gas turbines in the
project in Utah in the United States. Demonstrations using the H-25 gas turbines will be also
conducted for hydrogen-firing middle and small gas turbines as well as ammonia-firing towardcommercialization.

Figure 14 Schedule toward commercialization|7. Conclusion
This paper describes Mitsubishi Power efforts to use hydrogen and ammonia on power
generation gas turbines. It also discusses the company’s involvement in overseas hydrogen power
generation projects efforts toward the realization of a decarbonized society. The contents describedin point 3 of this paper are part of the outcome of the grant project ("Technology Development
Project for Building a Hydrogen-based Society": JPNP14026) of the New Energy and Industrial
Technology Development Organization (NEDO). In this grant project, Mitsubishi Power workedon the development of combustors for hydrogen and natural gas co-firing gas turbines and foundthat the operation of gas turbines under the 30 vol% co-firing condition is possible by modifying
current combustion hardware.
The development of GTCC using ammonia decomposition gas contents described in point 4

Mitsubishi Heavy Industries Technical Review Vol. 58 No. 3 (September 2021)
11of this paper was implemented by the Cross-ministerial Strategic Innovation Promotion Program(SIP), "Energy Carriers" (Funding agency: JST) and the grant project ("Technology Developmentfor Building a Hydrogen-based Society": JPNP14026) of the New Energy and Industrial
Technology Development Organization (NEDO).
The utilization of fossil fuel-derived hydrogen combined with Carbon Capture Utilizationand Storage (CCUS) will start in the mid-2020s. This will contribute to the realization of a society
using mainly renewable energy-derived hydrogen by 2050. Mitsubishi Power will contribute to
the realization of a decarbonized society by leading the establishment of an international hydrogen
supply chain through hydrogen- and ammonia-firing gas turbines being developed.

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