Please admit California’s Pajaro Valley to the storehouse of evidence that charging a fee to use scarce resources can stretch those resources, to the benefit of all.
Never heard of Pajaro Valley? Me neither, until I came across NY Times climate reporter Coral Davenport’s compelling end-of-year story, Strawberry Case Study: What if Farmers Had to Pay for Water? Turns out I once hitch-hiked there en route to the spectacular Big Sur coast south of Monterey. But the payoff today is in the story’s subhead: With aquifers nationwide in dangerous decline, one part of California has tried essentially taxing groundwater. New research shows it’s working.
California’s Pajaro Valley, at center of this Google Map, hugs the Pacific Coast midway between Santa Cruz and Monterey and straddles the two counties named for those cities.
What’s working? A charge for groundwater extracted to grow strawberries, raspberries, brussels sprouts, lettuce and kale, administered by the state-chartered Pajaro Valley Water Management Agency to prevent saltwater from the adjacent Pacific Ocean from intruding into underground aquifers. The fee, which began several decades ago at a nominal $30 per acre-foot of water to recover PVWMA’s water-metering costs, now runs as high as $400, according to Davenport.
Lest that rise seem meteoric, and today’s price appear punitive, consider that currently the agency’s total annual water fees, $12 million, equate to barely 1 percent of annual Pajaro Valley crop revenues of $12 million. What’s more, an acre-foot — the standard volumetric for water supply — is enormous: enough to provide 3 million tall glasses of water, by my calculations. Even the projected 2025 price of $500 per acre-foot translates to a mere one-sixtieth of a cent per glass.
To be sure, that calculation is merely illustrative; water for drinking and water for growing crops are two different things. But consider what Pajaro Valley growers get from paying for water.
First, their payments are helping assure increased supplies of crop-worthy water. Revenue from the water fees enabled PVWMA to undertake a $6 million project that captures excess rainwater from a creek near the ocean and injects it into underground wells to be used for irrigation, and a $20 million water recycling plant that cleans 5 million gallons of sewage a day and pipes it to farm fields. Next up, Davenport tells us, is an $80 million system to capture and store more rainwater for irrigation. By replenishing and “stretching’ supplies of groundwater, these investments help ensure that brackish water from the ocean doesn’t seep into Pajaro Valley wells.
Just as importantly, the growers receive a potent incentive to use available water supplies more efficiently. “Gone were the days of sprinklers that drenched fields indiscriminately,” Davenport writes. “To save money, many Pajaro farmers invested in precision irrigation technology to distribute carefully measured water exactly where it was needed.” (See text box.) Though the article doesn’t mention it, these investments by dozens of individual growers might not have materialized had not all growers been subject to the same incentives to conserve as well.
Economics
Undergirding Davenport’s upbeat reporting is a 2023 working paper, The Dynamic Impacts of Pricing Groundwater, by three economists at U-C Berkeley’s Dept. of Agricultural and Resource Economics. In academic parlance, “dynamic” doesn’t connote a Marvel superhero, it refers to changes over time. By examining changes in water usage over time, the authors conclude that each “21% price increase led to a … 22% reduction in average annual groundwater extraction” by Pajaro Valley growers.
The implied price-elasticity is roughly negative 1.3. (The paper helpfully reports that “The reduction in annual water use doubles between the first year and the fifth year after the tax, with the implied price elasticity of demand ranging from negative 0.86 to negative 1.97.) This empirically-derived price sensitivity is far greater than the price elasticities assumed in CTC’s carbon-tax model, befitting not only the greater salience of water use for growers vis-a-vis energy use for consumers and even most businesses, but the greater agency of Pajaro Valley growers who, Davenport’s reporting suggests, over time have increasingly bought into PVWMA’s groundwater fee in both theory and execution.
After reading Davenport’s article I reached out to hydrologist, climatologist and water sustainability expert Peter Gleick, whose latest book, The Three Ages of Water: Prehistoric Past, Imperiled Present, and a Hope for the Future, was published last year by Hachette / Public Affairs. Peter praised the article while preferring to denote the PVWMA groundwater charge “not [as a] tax but a fee or simply a price for a commodity.” He added, “When we pay for something, we’re more conscious of how we use it. When something is free, we’re more likely to misuse and abuse it. That’s certainly been the case historically for California groundwater.”
Carbon Taxes?
A number of posts in this space have touted — we might say “flogged” — other instances of resource or externality pricing, as possible templates for large-scale carbon pricing. In 2016 we wrote about Berkeley’s soda tax, actually a tax on the sugar content of soft drinks, and summarized research showing that sales of sugar-sweetened beverages fell 21% in that city while rising 4% in “control groups,” i.e., neighboring municipalities where soft drinks continued untaxed. Last year we explained why Congestion pricing, coming soon to New York City, could bode well for carbon-taxing — a message we previously broadcast several times in 2019 as the enabling legislation was being enacted in Albany, in March and in April.
We also dug deep in 2017, writing about an incipient NYC nickel fee on carryout bags dispensed at supermarkets, grocery and convenience stores. (The fee was a month away from taking effect, and though we haven’t yet seen before/after comparisons, anecdotal evidence suggests that trees in New York City are today far less encumbered by what we referred to then as “gossamer debris stuck, like tumors, to our half-a-million street trees.”) We can also go back half a century, to 1972, when NYC environmental officials conjured a “dirty oil surcharge” that forced petroleum suppliers to cough up a fee for each barrel of high-sulfur oil they brought into the city, a remarkably successful (but little known) instance of externality pricing that I memorialized in a 2009 post for Grist, Pollution Taxes Work.
Needless to say, none of these fees — not the soda tax, not congestion charging, not the carryout bag fee, and not the dirty oil surcharge — has paved the way for full-on carbon pricing. While each of them has been or will be a resounding success, their scale is far too local and the stakes far too small to translate automatically to national or even state-level carbon pricing. The same will hold for California’s Pajaro Valley groundwater fee. Indeed, California water districts are wrestling today with the hard work of fulfilling a state mandate requiring every part of the state to devise a plan to conserve groundwater.
Happily, Davenport notes that PVWMA officials and even some growers are advising their statewide counterparts to emulate their approach, including “local control” rather than state or even county governance. Less happily, she reports that the Westlands Water District, which serves the state’s giant Central Valley breadbasket, is pushing a plan “that would allow growers to pay for credits to use groundwater above a certain allocation.” The growers “could buy and sell the credits, starting at about $200 a credit,” Davenport notes. While this scheme certainly improves on the status quo of charging little or nothing for groundwater use, it’s complicated and drenched in market ideology, much as carbon cap-and-trade systems needlessly encumber what could and should be straightforward carbon pricing.
Let’s not end on that dour note, however. These instances of resource charging — whether to stretch a limited resource or to internalize pollution or other externality costs — make it easier to build support for enacting new ones. Davenport’s story — here’s the link again — is both brilliant reporting and cause for optimism.
We close with a snap of the story opening and photo as they appeared on the front page of today’s (Jan. 4, 2024) Times, above the fold. Below it are calculations in which we derived figures in the first part of this post.
Calculation #1: Glasses of water in an acre-foot.
- One acre = 43,560 ft^2, so one acre-foot = 43,560 ft^3.
- One ft^3 (cubic foot) contains 957.5 fluid oz. (per inchcalculator.com; that figure jibes with the 62.4 lb weight of one cubic foot of water).
- A tall water glass contains 14 fluid oz. Thus, one ft^3 of water can fill 957.5/14 = 68.4 tall glasses.
- One acre-foot then contains enough water to fill 43,560 x 68.4 = 2.98 million tall glasses, which we round to 3 million.
Calculation #2: Groundwater-use price-elasticity inferred from empirical finding that a 21 percent price increase evokes a 22 percent decrease in usage.
- It is tempting to reduce this roughly 1-to-1 relationship to a (negative) 1.0 price-elasticity. However, that would ignore the law of diminishing returns and, mathematically, the convex relationship between changes in price and changes in usage.
- The price-elasticity is derived by solving for e in the equation, (1 + 0.21)^e = (1 minus 0.22).
- Using base-10 logarithms, we have: e times log 1.21 = log 0.78, which (omitting one or two steps) leads to e = negative 1.3.
The global electric vehicle (EV) market is gaining speed again. A sharp rise in oil prices, triggered by the recent U.S.–Iran conflict in early 2026, has changed how consumers think about fuel and mobility. What looked like a slow market just months ago is now showing strong signs of recovery.
According to SNE Research’s latest report, this sudden shift in energy markets is pushing EV adoption faster than expected. Rising gasoline costs and uncertainty about future oil supply are driving buyers toward electric cars. As a result, the EV transition is no longer gradual—it is accelerating.
Oil Price Shock Changes Consumer Behavior
The conflict in the Middle East sent oil markets into turmoil. Gasoline prices jumped quickly, rising from around 1,600–1,700 KRW per liter to as high as 2,200 KRW. This sudden spike acted as a wake-up call for many drivers.
Consumers who once hesitated to switch to EVs are now rethinking their choices. High and unstable fuel prices have made traditional gasoline vehicles less attractive. At the same time, EVs now look more cost-effective and reliable over the long term.
SNE Research noted that even if oil prices stabilize later, the fear of future spikes will remain. This uncertainty is a key driver behind early EV adoption. People no longer want to depend on volatile fuel markets.
EV Growth Forecasts Get a Major Boost
SNE Research has revised its global EV outlook. The firm now expects faster adoption across the decade.
- EV market penetration is projected to reach 29% in 2026, up from an earlier estimate of 27%.
- By 2027, the share could jump to 35%, instead of the previously expected 30%.
- Most importantly, EVs are now expected to cross 50% of new car sales by 2030, earlier than prior forecasts.
The research firm also highlighted a clear timeline shift. EV demand has moved forward by half a year in 2026. By 2027, this lead increases to one full year. From 2028 onward, adoption is expected to accelerate by more than two years. This shows that the global EV transition is happening much faster than industry players had originally planned.
Higher Fuel Costs Improve EV Economics
One of the biggest drivers behind this shift is simple: EVs are becoming cheaper to own compared to gasoline cars.
SNE Research compared two popular models—the gasoline-powered Kia Sportage 1.6T and the electric Kia EV5. The results highlight how rising fuel prices change the equation.
At a gasoline price of 1,600 KRW per liter, it takes about two years to recover the higher upfront cost of an EV. However, when fuel prices rise to 2,000 KRW per liter, the payback period drops to just one year and two months.
So, over a longer period, the savings are even clearer:
- Total 10-year cost of a gasoline car: 59–65 million KRW
- Total 10-year cost of an EV: around 44 million KRW
This large gap makes EVs a smarter financial choice, especially when fuel prices remain high.
Battery Shake-Up: Market Struggles While CATL Surges Ahead
In the first two months of 2026, global EV battery usage reached 134.9 GWh, a modest increase of 4.4% year-over-year. However, not all companies are benefiting equally.
South Korean battery makers—LG Energy Solution, SK On, and Samsung SDI—saw their combined market share fall to 15%, down by 2.2 percentage points. Each company reported declining growth:
- LG Energy Solution: down 2.7%
- SK On: down 12.9%
- Samsung SDI: down 21.9%
This drop was mainly due to weaker EV sales in the U.S. market earlier in the year.
- In contrast, Chinese battery giant CATL continued to expand its lead. Its market share grew from 38.7% to 42.1%, strengthening its global dominance.
SNE Research explained that future competition will depend less on overall EV growth and more on supply chain strategy. Companies that diversify across customers and regions will be in a stronger position.
Automakers Feel the Impact Across Markets
Battery demand also reflects trends in automaker performance. Samsung SDI, for example, supplies batteries to brands like BMW, Audi, and Rivian. However, slower EV sales across these companies reduced overall battery demand.
Some key factors include:
- Lower sales of BMW’s electric lineup, including models like the i4 and iX
- Weak demand for Audi EVs despite new launches
- Declining sales from North America-focused brands like Rivian and Jeep
In some cases, new models even reduced demand for older ones. For instance, Audi’s Q6 e-tron impacted sales of the Q8 e-tron, lowering overall battery usage.
A Structural Shift in the EV Market
Despite short-term fluctuations, SNE Research believes the EV market is entering a new phase. The current surge is not just a reaction to oil prices—it reflects a deeper shift in consumer mindset.
People now see EVs as a safer and more stable option. Energy security, cost savings, and environmental concerns are all playing a role.
As SNE Research’s Vice President Ik-hwan James Oh explained, even if oil prices fall, the memory of sudden spikes will remain. This lasting concern will continue to push EV adoption.
In conclusion, the events of early 2026 have shown how quickly market dynamics can change. A single geopolitical shock has reshaped the global auto industry outlook.
For automakers, the message is clear: EV demand can rise faster than expected. For battery companies, the focus must shift to global expansion and supply chain resilience. For consumers, the decision is becoming easier as EVs offer both savings and stability.
The global EV market is no longer just growing—it is accelerating. And if current trends continue, the shift to electric mobility could arrive much sooner than anyone expected.
The post Global EV Sales Set to Hit 50% by 2030 Amid Oil Shock While CATL Leads Batteries appeared first on Carbon Credits.
Carbon Footprint
AI Data Centers Power Crisis: Massive Energy Demand Threatens Emissions Targets and Latest Delays Signal Market Shift
The rapid growth of artificial intelligence (AI) is creating a new challenge for global energy systems. AI data centers now require far more electricity than traditional computing facilities. This surge in demand is putting pressure on power grids and raising concerns about whether climate targets can still be met.
Large AI data centers typically need 100 to 300 megawatts (MW) of continuous power. In contrast, conventional data centers use around 10-50 MW. This makes AI facilities up to 10x more energy-intensive, depending on the scale and workload.
AI Data Centers Are Driving a Sharp Rise in Power Demand
The increase is happening quickly. The International Energy Agency estimates that global data center electricity use reached about 415 terawatt-hours (TWh) in 2024. That number could rise to more than 1,000 TWh by 2026, largely driven by AI applications such as machine learning, cloud computing, and generative models. 
At that level, data centers would consume as much electricity as an entire mid-sized country like Japan.
In the United States, the impact is also growing. Data centers could account for 6% to 8% of total electricity demand by 2030, based on utility projections and grid operator estimates. AI is expected to drive most of that increase as companies continue to scale infrastructure to support new applications.
Training large AI models is especially energy-intensive. Some estimates say an advanced model can use millions of kilowatt-hours (kWh) just for training. For instance, training GPT-3 needs roughly 1.287 million kWh, and Google’s PaLM at about 3.4 million kWh. Analytical estimates suggest training newer models like GPT-4 may require between 50 million and over 100 million kWh.
That is equal to the annual electricity use of hundreds of households. When combined with ongoing usage, known as inference, total energy consumption rises even further.
This rapid growth is creating a gap between electricity demand and available supply. It is also raising questions about how the technology sector can expand while staying aligned with global climate goals.
The Grid Bottleneck: Why Data Centers Are Waiting Years for Power
Power demand from AI is rising faster than grid infrastructure can support. Utilities in key regions are now facing a surge in interconnection requests from technology companies building new data centers.
This has led to delays in several major projects. In many cases, developers must wait years before they can secure enough electricity to operate. These delays are becoming more common in established tech hubs where grid capacity is already stretched.
The main constraints include:
- Limited transmission capacity in high-demand areas,
- Slow grid upgrades and long permitting timelines, and
- Regulatory systems not designed for AI-scale demand.
Grid stability is another concern. AI data centers require constant and uninterrupted power. Even short disruptions can affect performance and reliability. This makes it more difficult for utilities to balance supply and demand, especially during peak periods.
In some regions, utilities are struggling to manage the size and concentration of new loads. A single large data center can use as much electricity as a small city. When several projects are planned in the same area, the pressure on local infrastructure increases significantly.
As a result, some companies are rethinking their expansion strategies. Projects may be delayed, scaled down, or moved to new locations where energy is more accessible. These shifts could slow the pace of AI deployment, at least in the short term.
Renewable Energy Growth Faces a Reality Check
Technology companies have made strong commitments to clean energy. Many aim to power their operations with 100% renewable electricity. This is part of their larger environmental, social, and governance (ESG) goals.
For example, Microsoft plans to become carbon negative by 2030, meaning it will remove more carbon than it emits. Google is targeting 24/7 carbon-free energy by 2030, which goes beyond annual matching to ensure clean power is used at all times. Amazon has committed to reaching net-zero carbon emissions by 2040 under its Climate Pledge.
Despite these targets, AI data centers present a difficult challenge. They need reliable electricity around the clock, while renewable energy sources such as wind and solar are not always available. Output can vary depending on weather conditions and time of day.
To maintain stable operations, many facilities rely on a mix of energy sources. This often includes grid electricity, which may still be partly generated from fossil fuels. In some cases, natural gas backup systems are used more frequently than planned.
Battery storage can help balance supply and demand. However, long-duration storage remains expensive and is not yet widely deployed at the scale needed for large AI facilities. This creates both technical and financial barriers.
Thus, there is a growing gap between corporate clean energy goals and real-world energy use. Closing that gap will require faster deployment of renewable energy, improved storage solutions, and more flexible grid systems.
Carbon Credits Use Surge as Tech Tries to Close the Emissions Gap
The mismatch between AI growth and clean energy supply is also affecting carbon markets. Many technology companies are increasing their use of carbon credits to offset emissions linked to data center operations.
According to the World Bank’s State and Trends of Carbon Pricing 2025, carbon pricing now covers over 28% of global emissions. But carbon prices vary widely—from under $10 per ton in some systems to over $100 per ton in stricter markets. This gap is pushing companies toward voluntary carbon markets.
The Ecosystem Marketplace report shows rising demand for high-quality credits, especially carbon removal rather than avoidance credits. But supply is still limited.
Costs are especially high for engineered removals. The IEA estimates that direct air capture (DAC) costs today range from about $600 to over $1,000 per ton of CO₂. It may fall to $100–$300 per ton in the future, but supply is still very small.
Companies are focusing on credits that:
- Deliver verified emissions reductions,
- Support long-term carbon removal, and
- Align with ESG and net-zero commitments.
At the same time, many firms are taking a more active role in energy development. Instead of relying only on offsets, they are investing directly in renewable energy projects. This includes funding new solar and wind farms, as well as entering long-term power purchase agreements.
These investments help secure a dedicated clean energy supply. They also reduce long-term exposure to carbon markets, which can be volatile and subject to changing standards.
Companies Are Adapting Their Energy Strategies: The New AI Energy Playbook
AI companies are changing how they design and operate data centers to manage rising energy demand. Here are some of the key strategies:
- Energy efficiency improvements (new hardware and cooling systems) that reduce data center power use.
- More efficient AI chips, specialized processors, that drive performance gains.
- Advanced cooling systems that cut energy waste and can help cut total power use per workload by 20% to 40%.
- Data center location strategy is shifting, where facilities are built in regions with stronger renewable energy access.
- Infrastructure is becoming more distributed, where firms deploy smaller data centers across multiple locations to balance demand and improve resilience.
- Long-term renewable energy contracts are expanding, which helps companies secure power at stable prices.
A Turning Point for Energy and Climate Goals
The rise of AI is creating both risks and opportunities for the global energy transition. In the short term, increased electricity demand could lead to higher emissions if fossil fuels are used to fill supply gaps.
At the same time, AI is driving major investment in clean energy and infrastructure. The long-term outcome will depend on how quickly clean energy systems can scale.
If renewable supply, storage, and grid capacity keep pace with AI growth, the technology sector could help accelerate the shift to a low-carbon economy. If progress is too slow, however, AI could become a major new source of emissions.
Either way, AI is now a central force shaping global energy demand, infrastructure investment, and the future of carbon markets.
The post AI Data Centers Power Crisis: Massive Energy Demand Threatens Emissions Targets and Latest Delays Signal Market Shift appeared first on Carbon Credits.
Japan has taken a major step in clean shipping. A consortium led by Japan Engine Corporation and Kawasaki Heavy Industries has successfully tested the world’s first hydrogen-fueled main engine for a large commercial vessel.
This engine is designed for deep-sea cargo ships, not just small vessels. That makes it a key milestone. Most earlier hydrogen ship projects focused on ferries or short routes.
The 3% Problem: Shipping’s Emissions Challenge
The engine is a low-speed, two-stroke design. This is the standard for large ocean-going ships. It can run mainly on hydrogen fuel. In tests, it achieved about 95% hydrogen use at full load, showing stable performance.
The engine will be installed on a 17,500-deadweight-ton multipurpose vessel. The ship is expected to be delivered in 2027. It will then undergo a three-year demonstration period starting in 2028.
Shipping is a major source of global emissions. The sector produces about 2–3% of global greenhouse gas emissions, based on data from the International Maritime Organization (IMO).
Most ships today use heavy fuel oil or marine diesel. These fuels produce high emissions. As global trade grows, shipping emissions could increase without new solutions.
Hydrogen is one option. When used as a fuel, it produces no carbon dioxide at the point of use. This makes it attractive for long-term decarbonization.
However, scaling hydrogen for large ships has been difficult. Key challenges include fuel storage, engine design, and safety. Japan’s latest engine test shows that progress is being made.
How Hydrogen Engines Work in Large Vessels
Hydrogen-powered ships can use fuel cells or combustion engines. Japan’s new system uses combustion. This means hydrogen burns inside the engine, similar to diesel. This approach allows easier integration with existing ship systems. It also reduces the need for full redesigns of vessels.
The engine uses liquid hydrogen fuel and advanced injection systems. Engineers have focused on stable combustion and material strength. Hydrogen burns faster than traditional fuels, so precision is critical.
The project includes partners such as Mitsui O.S.K. Lines (MOL), Onomichi Dockyard, and ClassNK. These groups support design, safety checks, and future operations.
The move is part of Japan’s Green Innovation Fund. The Ministry of Economy, Trade, and Industry has funded the program with about 2 trillion yen to help the country reach carbon neutrality by 2050.
Japan’s Net Zero Strategy and Hydrogen Push
This hydrogen engine project fits into Japan’s broader climate strategy. The country has pledged to reach net-zero greenhouse gas emissions by 2050. This goal was announced by former Prime Minister Yoshihide Suga in 2020.
Japan sees hydrogen as a key part of its energy transition. Under its Basic Hydrogen Strategy, the government aims to expand hydrogen use across power, transport, and industry.
Japan plans to increase its hydrogen supply to 20 million tonnes per year by 2050, up from much lower current levels. The country is also investing in hydrogen imports, storage, and infrastructure.
Shipping plays a major role in this plan. Japan depends heavily on imports of energy and raw materials. Decarbonizing shipping is important for both climate and energy security.
- RELATED: Maritime Decarbonization: Japanese Shipping Giant NYK Partners with 1PointFive for DAC Credits
Projects like the hydrogen engine help link domestic policy with global action. They support Japan’s goal to build a full hydrogen value chain, from production to transport and end use.
Current Hydrogen Ferries in Operation
Japan has already started using hydrogen-powered ferries on real routes. One example is the Hanaria. This hybrid ship uses hydrogen fuel cells, lithium-ion batteries, and biodiesel. It began service in Kitakyushu in April 2024.
The ship can cut carbon dioxide emissions by 53% to 100% compared to regular vessels. It was built for a unit of Mitsui O.S.K. Lines and uses fuel cell technology developed with parts from Toyota.
Another example is the Mahoroba, built by Iwatani Corporation. This is a zero-emission hydrogen catamaran that can carry up to 150 passengers. It started commercial service in April 2025, transporting visitors to the Osaka-Kansai Expo.
In October 2025, the Tokyo Metropolitan Government agreed to bring the vessel to Tokyo Bay. It is expected to start operating there in fiscal year 2026. It will support environmental education and international events.
Japan has also invested in hydrogen transport systems. One example is the Suiso Frontier, which was launched to carry liquefied hydrogen across long distances. These efforts show that Japan is not only testing technology but also building the systems needed to scale hydrogen use globally.
From Ferries to Freighters: Scaling Hydrogen at Sea
Japan is part of a wider global shift. Many countries are testing hydrogen and other clean fuels for shipping.
For example, Norway launched the MF Hydra in 2023. Belgium introduced the Hydrotug 1 in 2024.
However, most of these vessels are small or operate on short routes. Japan’s project targets large cargo ships, which are more complex and more impactful for emissions.
Governments are also exploring hydrogen shipping corridors. These are planned routes where hydrogen-powered vessels can operate with proper fueling infrastructure. This global activity shows that hydrogen is moving from early testing to larger applications.
A $300B Hydrogen Market Meets Maritime Demand
The hydrogen economy is expanding quickly. Global demand is rising as industries look for low-carbon solutions.
Industry estimates suggest the global hydrogen market could exceed US$300 billion by 2030. Growth is driven by energy, transport, and industrial use.
In shipping, hydrogen competes with other fuels like ammonia and methanol. Each has strengths and challenges. Hydrogen stands out for its zero carbon emissions at the point of use.
Cost, Storage, and Infrastructure Barriers
Still, hydrogen has limits. Several barriers remain before hydrogen ships become common:
- High costs compared to traditional fuels,
- Limited supply of green hydrogen,
- Lack of port infrastructure, and
- Strict safety requirements.
Despite these issues, investment is growing. Governments and companies are funding research, pilot projects, and infrastructure.
Japan’s demonstration project will help address those gaps. The planned three-year trial will provide real-world data on performance, safety, and costs. If successful, hydrogen engines could become a practical option for large vessels. This would help reduce emissions from global shipping.
Can Hydrogen Power the Future of Global Trade?
Japan’s hydrogen engine test marks a key moment for the shipping industry. It shows that hydrogen can power not only small vessels but also large commercial ships.
The link to Japan’s net-zero strategy makes this development even more important. It connects national policy with global climate goals.
The coming years will shape how fast hydrogen shipping grows. With strong policy support and continued innovation, hydrogen could play a major role in building a low-carbon maritime sector.
The post Japan Unveils First Hydrogen Engine for Large Ships appeared first on Carbon Credits.
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