Italy simplifies geothermal energy permitting

By Reuters


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Italy has simplified permitting procedures for development of geothermal energy projects as it aims to produce a quarter of energy from renewable sources in 2020, the Economic Development Ministry said.

Geothermal energy, which uses the earth's inner heat for heating and also turns it into electricity by using special power plants, accounts for 10 percent of all renewable energy sources in Italy and its potential may be doubled, it said in a statement.

Italy's geothermal plants produce 5 billion kilowatt hours of power a year which is enough to meet needs of about 6 million people, the ministry said.

The ministry did not give details on a new decree to simplify geothermal projects' authorization. Italy is notorious for lengthy permitting procedures for industrial projects.

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New EPA power plant rules will put carbon capture to the test

CCUS in the U.S. Power Sector drives investments as DOE grants, 45Q tax credits, and EPA carbon rules spur carbon capture, geologic storage, and utilization, while debates persist over costs, transparency, reliability, and emissions safeguards.

 

Key Points

CCUS captures CO2 from power plants for storage or use, backed by 45Q tax credits, DOE funding, and EPA carbon rules.

✅ DOE grants and 45Q credits aim to de-risk project economics.

✅ EPA rules may require capture rates to meet emissions limits.

✅ Transparency and MRV guard against tax credit abuse.

 

New public and private funding, including DOE $110M for CCUS announced recently, and expected strong federal power plant emissions reduction standards have accelerated electricity sector investments in carbon capture, utilization and storage,’ or CCUS, projects but some worry it is good money thrown after bad.

CCUS separates carbon from a fossil fuel-burning power plant’s exhaust through carbon capture methods for geologic storage or use in industrial and other applications, according to the Department of Energy. Fossil fuel industry giants like Calpine and Chevron are looking to take advantage of new federal tax credits and grant funding for CCUS to manage potentially high costs in meeting power plant performance requirements, amid growing investor pressure for climate reporting, including new rules, expected from EPA soon, on reducing greenhouse gas emissions from existing power plants.

Power companies have “ambitious plans” to add CCUS to power plants, estimated to cause 25% of U.S. CO2 emissions. As a result, the power sector “needs CCUS in its toolkit,” said DOE Office of Fossil Energy and Carbon Management Assistant Secretary Brad Crabtree. Successful pilots and demonstrations “will add to investor confidence and lead to more deployment” to provide dispatchable clean energy, including emerging CO2-to-electricity approaches for power system reliability after 2030,| he added.

But environmentalists and others insist potentially cost-prohibitive CCUS infrastructure, including CO2 storage hub initiatives, must still prove itself effective under rigorous and transparent federal oversight.

“The vast majority of long-term U.S. power sector needs can be met without fossil generation, and better options are being deployed and in development,” Sierra Club Senior Advisor, Strategic Research and Development, Jeremy Fisher, said, pointing to carbon-free electricity investments gaining momentum in the market. CCUS “may be needed, but without better guardrails, power sector abuses of federal funding could lead to increased emissions and stranded fossil assets,” he added.

New DOE CCUS project grants, an increased $85 per metric ton, or tonne, federal 45Q tax credit, and the forthcoming EPA power plant carbon rules and the federal coal plan will do for CCUS what similar policies did for renewables, advocates and opponents agreed. But controversial past CCUS performance and tax credit abuses must be avoided with transparent reporting requirements for CO2 capture, opponents added.

 

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U.S. Electric Vehicle Market Share Dips in Q1 2024

U.S. EV Market Share Dip Q1 2024 reflects slower BEV adoption, rising PHEV demand, affordability concerns, charging infrastructure gaps, tax credit shifts, range anxiety, and automaker strategy adjustments across the electric vehicle market.

 

Key Points

Q1 2024 EV and hybrid share slipped as BEV sales lag, PHEVs rise, and affordability and charging concerns temper demand.

✅ BEV share fell to 7.0% as affordable models remain limited

✅ PHEV sales rose 50% YoY, easing range anxiety concerns

✅ Policy shifts and charging gaps weigh on consumer adoption

 

The U.S. electric vehicle (EV) market, once a beacon of unbridled growth, appears to be experiencing a course correction. Data from the U.S. Energy Information Administration (EIA) reveals that the combined market share of electric vehicles (battery electric vehicles, or BEVs) and hybrids dipped slightly in the first quarter of 2024, marking the first decline since the onset of the COVID-19 pandemic, even as EU EV share rose during lockdowns in 2020.

This news comes as a surprise to many analysts who predicted continued exponential growth for the EV market. While overall sales of electric vehicles surged into 2024 and did increase by 7% compared to Q1 2023, this growth wasn't enough to keep pace with the overall rise in vehicle sales. The result: a decline in market share from 18.8% in Q4 2023 to 18.0% in Q1 2024.

Several factors may be contributing to this shift. One potential culprit is a slowdown in battery electric vehicle sales. BEVs saw their share of the market dip from 8.1% to 7.0% in the same period. This could be attributed to a lack of readily available affordable options, with many popular EV models still commanding premium prices and concerns that EV supply may miss demand in the near term.

Another factor could be the rising interest in plug-in hybrid electric vehicles (PHEVs). PHEV sales witnessed a significant jump of 50% year-over-year, reflecting how gas-electric hybrids are getting a boost from major automakers, potentially indicating a consumer preference for vehicles that offer both electric and gasoline powertrain options, addressing concerns about range anxiety often associated with BEVs.

Industry experts offer mixed interpretations of this data. Some downplay the significance of the dip, attributing it to a temporary blip, even though EVs remain behind gas cars in total sales. They point to the ongoing commitment from major automakers to invest in EV production and the potential for new, more affordable models to hit the market soon.

Others express more concern, citing Europe's recent EV slump and suggesting this might be a sign of maturing consumer preferences. They argue that simply increasing the number of EVs on the market might not be enough. Automakers need to address issues like affordability, charging infrastructure, and range anxiety to maintain momentum.

The role of government incentives also remains a question mark. The federal tax credit for electric vehicles is currently set to phase out gradually, potentially impacting consumer purchasing decisions in the future. Continued government support, through incentives or infrastructure development, could be crucial in maintaining consumer interest.

The coming quarters will be crucial in determining the long-term trajectory of the U.S. EV market, especially after the global electric car market's rapid expansion in recent years. Whether this is a temporary setback or a more lasting trend remains to be seen. Addressing consumer concerns, ensuring a diverse range of affordable EV options, and continued government support will all be essential in ensuring the continued growth of this critical sector.

This development also presents an opportunity for traditional automakers. By capitalizing on the growing PHEV market and addressing consumer concerns about affordability and range anxiety, they can carve out a strong position in the evolving automotive landscape.

 

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Enel kicks off 90MW Spanish wind build

Enel Green Power España Aragon wind farms advance Spain's renewable energy transition, with 90MW under construction in Teruel, Endesa investment of €88 million, 25-50MW turbines, and 2017 auction-backed capacity enhancing grid integration and clean power.

 

Key Points

They are three Teruel wind projects totaling 90MW, part of Endesa's 2017-awarded plan expanding Spain's clean energy.

✅ 90MW across Sierra Costera I, Allueva, and Sierra Pelarda

✅ €88m invested; 14+7+4 turbines; Endesa-led build in Teruel

✅ Part of 2017 tender: 540MW wind, 339MW solar, nationwide

 

Enel Green Power Espana, part of Enel's wind projects worldwide, has started constructing three wind farms in Aragon, north-east Spain, which are due online by the end of the year.

The projects, all situated in the Teruel province, are worth a total investment of €88 million.

The biggest of the facilities, Sierra Costera I, will have a 50MW and will feature 14 turbines.

The wind farm is spread across the municipalities of Mezquita de Jarque, Fuentes Calientes, Canada Vellida and Rillo.

The Allueva wind facility will feature seven turbines and will exceed 25MW.

Sierra Pelarda, in Fonfria, will have four turbines and a capacity of 15MW, as advances in offshore wind turbine technology continue to push scale elsewhere.

The projects bring the total number of wind farms that Enel Green Power Espana has started building in the Teruel province to six, equal to an overall capacity of 218MW.

Endesa chief executive Jose Bogas said: “These plants mark the acceleration on a new wave of growth in the renewable energy space that Endesa is committed to pursue in the next years, driving the energy transition in Spain.”

The six wind farms under construction in Teruel are part of the 540MW that Enel Green Power Espana was awarded in the Spanish government's renewable energy tender held in May 2017.

In Aragon, the company will invest around €434 million euros, reflecting broader European wind power investment trends in recent years, to build 13 wind farms with a total installed capacity of more than 380MW.

The remaining 160MW of wind capacity will be located in Andalusia, Castile-Leon, Castile La Mancha and Galicia, even as some Spanish turbine factories closed during pandemic restrictions.

Enel Green Power Espana was also awarded 339MW of solar capacity in the Spanish government's auction held in July 2017, while other Spanish developers advance CSP projects abroad in markets like Chile.

Once all wind and solar under the 2017 tender are complete they will boost the company’s capacity by around 52%.

 

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Ontario to seek new wind, solar power to help ease coming electricity supply crunch

Ontario Clean Grid Plan outlines emissions-free electricity growth, renewable energy procurement, nuclear expansion at Bruce and Darlington, reduced natural gas, grid reliability, and net-zero alignment to meet IESO demand forecasts and EV manufacturing loads.

 

Key Points

A plan to expand emissions-free power via renewables and nuclear, cut natural gas use, and meet growing demand.

✅ Targets renewables, hydro, and nuclear capacity growth

✅ Aims to reduce reliance on gas for grid reliability

✅ Aligns with IESO demand forecasts and EV manufacturing loads

 

Ontario is working toward filling all of the province’s quickly growing electricity needs with emissions-free sources, including a plan to secure new renewable generation and clean power options, but isn’t quite ready to commit to a moratorium on natural gas.

Energy Minister Todd Smith announced Monday a plan to address growing energy needs for 2030 to 2050 — the Independent Electricity System Operator projects Ontario’s electricity demand could double by mid-century — and next steps involve looking for new wind, solar and hydroelectric power.

“While we may not need to start building today, government and those in the energy sector need to start planning immediately, so we have new clean, zero-emissions projects ready to go when we need them,” Smith said in Windsor, Ont.

The strategy also includes two nuclear projects announced last week — a new large-scale nuclear plant at Bruce Power on the shore of Lake Huron and three new small modular reactors at the site of the Darlington nuclear plant east of Toronto.

Those projects, enough to power six million homes, will help Ontario end its reliance on natural gas to generate electricity, said Smith, but committing to a natural gas moratorium in 2027 and eliminating natural gas by 2050 is contingent on the federal government helping to speed up the new nuclear facilities.

“Today’s report, the Powering Ontario’s Growth plan, commits us to working towards a 100 per cent clean grid,” Smith said in an interview.

“Hopefully the federal government can get on board with our intentions to build this clean generation as quickly as possible … That will put us in a much better position to use our natural gas facilities less in the future, if we can get those new projects online.”

The IESO has said that natural gas is required to ensure supply and stability in the short to medium term, as Ontario works on balancing demand and emissions across the grid, but that it will also increase greenhouse gas emissions from the electricity sector.

The province is expected to face increased demand for electricity from expanded electric vehicle use and manufacturing in the coming years, even as a $400-billion cost estimate for greening the grid is debated.

Keith Brooks, programs director for Environmental Defence, said the provincial plan could have been much more robust, containing firm timelines and commitments.

“This plan does not commit to getting emissions out of the system,” he said.

“It doesn’t commit to net zero, doesn’t set a timeline for a net zero goal or have any projection around emissions from Ontario’s electricity sector going forward. In fact, it’s not really a plan. It doesn’t set out any real goals and it doesn’t it doesn’t project what Ontario’s supply mix might look like.”

The Canadian Climate Institute applauded the plan’s focus on reducing reliance on gas-fired generation and emphasizing non-emitting generation, but also said there are still some question marks.

“The plan is silent on whether the province intends to construct new gas-fired generation facilities,” even as new gas plant expansions are proposed, senior research director Jason Dion wrote in a statement.

“The province should avoid building new gas plants since cost-effective alternatives are available, and such facilities are likely to end up as stranded assets. The province’s timeline for reaching net zero generation is also unclear. Canada and other G7 countries have set a target for 2035, something Ontario will need to address if it wants to remain competitive.”

 

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Brenmiller Energy and New York Power Authority Showcase Thermal Storage Success

bGen Thermal Energy Storage stores high-temperature heat in crushed rocks, enabling on-demand steam, hot water, or hot air; integrates renewables, shifts load with off-peak electricity, and decarbonizes campus heating at SUNY Purchase with NYPA.

 

Key Points

A rock-based TES system storing heat to deliver steam, hot water, or hot air using renewables or off-peak power.

✅ Uses crushed rocks to store high-temperature heat

✅ Cuts about 550 metric tons CO2 annually at SUNY Purchase

✅ Integrates renewables and off-peak electricity with NYPA

 

Brenmiller Energy Ltd. (NASDAQ: BNRG), in collaboration with the New York Power Authority (NYPA), a utility pursuing grid software modernization to improve reliability, has successfully deployed its first bGen™ thermal energy storage (TES) system in the United States at the State University of New York (SUNY) Purchase College. This milestone project, valued at $2.5 million, underscores the growing role of TES in advancing sustainable energy solutions.

Innovative TES Technology

The bGen™ system utilizes crushed rocks to store high-temperature heat, which can be harnessed to generate steam, hot air, or hot water on demand. This approach allows for the efficient use of excess renewable energy or off-peak electricity, and parallels microreactor storage advances that broaden thermal options, providing a reliable and cost-effective means of meeting heating needs. At SUNY Purchase College, the bGen™ system is designed to supply nearly 100% of the heating requirements for the Physical Education Building.

Environmental Impact

The implementation of the bGen™ system is expected to eliminate approximately 550 metric tons of greenhouse gas emissions annually. This reduction aligns with New York State's ambitious climate goals, including a 40% reduction in greenhouse gas emissions by 2030, even as transmission constraints can limit cross-border imports. The project also demonstrates the potential of TES to support the state's transition to a cleaner and more resilient energy system.

Collaborative Effort

The successful deployment of the bGen™ system at SUNY Purchase College is the result of a collaborative effort between Brenmiller Energy and NYPA. The project was partially funded by a grant from the Israel-U.S. Binational Industrial Research and Development (BIRD) Foundation. This partnership highlights the importance of international cooperation in advancing innovative energy technologies, as seen in OPG-TVA nuclear collaboration efforts across North America.

Future Prospects

The successful installation and operation of the bGen™ system at SUNY Purchase College serve as a model for broader adoption of TES technology in institutional settings, as OPG's SMR commitment signals parallel low-carbon investment across the region. Brenmiller Energy and NYPA plan to share the project's findings through a webinar hosted by the Renewable Thermal Collaborative on May 19, 2025. This initiative aims to promote the scalability and replicability of TES solutions across New York State and beyond.

As the demand for sustainable energy solutions continues to grow, the successful deployment of the bGen™ system at SUNY Purchase College marks a significant step forward in the integration of TES technology into the U.S. energy landscape, while projects like Pickering B refurbishment underscore parallel clean power investments. The project not only demonstrates the feasibility of TES but also sets a precedent for future initiatives aimed at reducing carbon emissions and enhancing energy efficiency.

Brenmiller Energy's commitment to innovation and sustainability positions the company as a key player in the evolving energy sector. With continued support from partners like NYPA and the BIRD Foundation, and as jurisdictions advance first SMR deployments in North America, Brenmiller Energy is poised to expand the reach of its TES solutions, contributing to a more sustainable and resilient energy future.

 

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The Haves and Have-Nots of Electricity in California

California Public Safety Power Shutoffs highlight wildfire prevention as PG&E outages disrupt schools, businesses, and rural communities, driving generator use, economic hardship, and emergency preparedness across Northern California during high-wind events.

 

Key Points

Utility outages to reduce wildfire risk during extreme winds, impacting homes and businesses in high-risk California.

✅ PG&E cuts power during high winds to prevent wildfires

✅ Costs rise for generators, fuel, batteries, and spoiled food

✅ Rural, low-income communities face greater economic losses

 

The intentional blackout by California’s largest utility this week put Forest Jones out of work and his son out of school. On Friday morning Mr. Jones, a handyman and single father, sat in his apartment above a tattoo parlor waiting for the power to come back on and for school to reopen.

“I’ll probably lose $400 or $500 dollars because of this,” said Mr. Jones, who lives in the town of Paradise, which was razed by fire last year and is slowly rebuilding. “Things have been really tough up here.”

Millions of people were affected by the blackout, which spanned the outskirts of Silicon Valley to the forests of Humboldt County near the Oregon border. But the outage, which the power company said was necessary to reduce wildfire risk across the region, also drew a line between those who were merely inconvenienced and those who faced a major financial hardship.

To have the lights on, the television running and kitchen appliances humming is often taken for granted in America, even as U.S. grid during coronavirus questions persisted. During California’s blackout it became an economic privilege.

The economic impacts of the shut-off were especially acute in rural, northern towns like Paradise, where incomes are a fraction of those in the San Francisco Bay Area.

Both wealthy and poorer areas were affected by the blackout but interviews across the state suggested that being forced off the grid disproportionately hurt the less affluent. One family in Humboldt County said they had spent $150 on batteries and water alone during the shutdown.

“To be prepared costs money,” Sue Warhaftig, a massage therapist who lives in Mill Valley, a wealthy suburb across the Golden Gate Bridge from San Francisco. Ms. Warhaftig spent around two days without electricity but said she had been spared from significant sacrifices during the blackout.

She invested in a generator to keep the refrigerator running and to provide some light. She cooked in the family’s Volkswagen camper van in her driveway. At night she watched Netflix on her phone, which she was able to charge with the generator. Her husband, a businessman, is in London on a work trip. Her two sons, both grown, live in Southern California and Seattle.

“We were inconvenienced but life wasn’t interrupted,” Ms. Warhaftig said. “But so many people’s lives were.

Pacific Gas & Electric restored power to large sections of Northern California on Friday, including Paradise, where the electricity came back on in the afternoon. But hundreds of thousands of people in other areas remained in the dark. The carcasses of burned cars still littered the landscape around Paradise, where 86 people died in the Camp Fire last year, some of them while trying to escape.

Officials at power company said that by Saturday they hoped to have restored power to 98 percent of the customers who were affected.

The same dangerous winds that spurred the shut-off in Northern California have put firefighters to work in the south. The authorities in Los Angeles County ordered the evacuation of nearly 100,000 people on Friday as the Saddleridge Fire burned nearly 5,000 acres and destroyed 25 structures. The Sandalwood Fire, which ignited Thursday in Riverside County, had spread to more than 800 acres and destroyed 74 structures by Friday afternoon.

While this week’s outage was the first time many customers in Northern California experienced a deliberate power shut-off, residents in and around Paradise have had their power cut four times in recent months, residents say.

Many use a generator, but running one has become increasingly expensive with gasoline now at more than $4 a gallon in California.

On Friday, Dennis and Viola Timmer drove up the hill to their home in Magalia, a town adjacent to Paradise, loaded with $102 dollars of gasoline for their generators. It was their second gasoline run since the power went out Tuesday night.

The couple, retired and on a fixed income after Mr. Timmer’s time in the Navy and in construction, said the power outage had severely limited their ability to do essential tasks like cooking, or to leave the house.

“You know what it feels like? You’re in jail,” said Ms. Timmer, 72. “You can’t go anywhere with the generators running.”

Since the generators are not powerful enough to run heat or air conditioning, the couple slept in their den with an electric space heater.

“It’s really difficult because you don’t have a normal life,” Ms. Timmer said. “You’re trying to survive.”

To be sure, the shutdown has affected many people regardless of economic status, and similar disruptions abroad, like a London power outage that disrupted routines, show how widespread such challenges can be. The areas without power were as diverse as the wealthy suburbs of Silicon Valley, the old Gold Rush towns of the Sierra Nevada, the East Bay of San Francisco and the seaside city of Arcata.

Ms. Cahn’s cellphone ran out of power during the blackout and even when she managed to recharge it in her car cell service was spotty, as it was in many areas hit by the blackout.

Accustomed to staying warm at night with an electric blanket, Ms. Cahn slept under a stack of four blankets.

“I’m doing what I have to do which is not doing very much,” she said.

Further south in Marin City, Chanay Jackson stood surrounded by fumes from generators still powering parts of the city.

She said that food stamps were issued on the first of the month and that many residents who had to throw away food were out of luck.

“They’re not going to issue more food stamps just because the power went out,” Ms. Jackson said. “So they’re just screwed until next month.”

Strong winds have many times in the past caused power lines to come in contact with vegetation, igniting fires that are then propelled by the gusts, and hurricanes elsewhere have crippled infrastructure with Louisiana grid rebuild after Laura according to state officials. This was the case with the Camp Fire.

Since higher elevations had more extreme winds many of the neighborhoods where power was turned off this week were in hills and canyons, including in the Sierra Nevada.

The shut-off, which by one estimate affected a total of 2.5 million people, has come under strong criticism by residents and politicians, and warnings from Cal ISO about rolling blackouts as the power grid strained. The company’s website crashed just as customers sought information about the outage. Gov. Gavin Newsom called it unacceptable. But his comments were nuanced, criticizing the way the shut-off was handled, not the rationale for it. Mr. Newsom and others said the ravages of the Camp Fire demanded preventive action to prevent a reoccurrence.

Yet the calculus of trying to avoid deadly fires by shutting off power will continue to be debated as California enters its peak wildfire season, even as electricity reliability during COVID-19 was generally maintained for most consumers.

In the city of Grass Valley, Matthew Gottschalk said he and his wife realized that a generator was essential when they calculated that they had around $500 worth of food in their fridge.

“I don’t know what we would have done,” said Mr. Gottschalk, whose power went out Tuesday night.

His neighbors are filling coolers with ice. Everyone is hoping the power will come back on soon.

“Ice is going to run out and gas is going to run out,” he said.

 

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