EPA reveals 44 higher risk coal ash sites

By Associated Press


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The Environmental Protection Agency made public a list of 26 communities in 10 states where residents are potentially threatened by coal ash storage ponds similar to one that flooded a neighborhood in Tennessee last year.

North Carolina has the most sites on the list, a dozen. The largest concentration is near Cochise, Ariz., where there are seven storage ponds.

The agency said it will inspect each of the 44 coal ash sites located near communities to make certain they are structurally sound. The sites are being classified as potentially highly hazardous because they are near where people live and not because of any discovered defect.

"The high hazard potential means there will be probable loss of human life if there is a significant dam failure," said Matt Hale, director of EPA's office of research, conservation and recovery. "It is a measure of what would happen if the dam would fail. It is not a measure of the stability of the dam."

Sen. Barbara Boxer, D-Calif., whose Environment and Public Works Committee held hearings on the coal ash risks, hailed the EPA decision. She said making the most high-risk sites public is essential "so that people have the information they need to quickly press for action to make these sites safer." Boxer had called on the EPA to make the information available.

Burning coal produces ash, which is kept in liquid, known as slurry, in containment ponds or dams. The EPA lists more than 400 such impoundments across the country, but the 44 singled out represent those that are near populated areas, posing a higher danger.

Last year, two days before Christmas, a coal ash pond broke near Kingston, Tenn., sending 5 million cubic yards of ash and sludge across more than 300 acres, destroying or damaging 40 homes. The incident prompted a safety review of storage ponds that hold the waste byproduct near large coal-burning power plants.

The storage ponds hold fly ash, bottom ash, coal slag and flue gas residues that contain toxic metals such as arsenic, selenium, cadmium, lead and mercury, although generally at low concentrations.

Until now, the national coal ash site list has not been provided to the public. Earlier this month the Army Corps of Engineers said it didn't want the locations disclosed because of national security and that it could help terrorists target such facilities. Hale said that issue has been resolved.

The EPA has been to half the 44 sites and expects to issue reports soon, Hale said. The EPA inspections are continuing. The EPA also is reviewing state inspection reports at some of the sites.

The seven ponds near Cochise, Ariz., hold material from the Apache Station Combustion Waste Disposal Facility operated by Arizona Electric Power Cooperative.

The 10 states, the number of sites, and communities are:

• North Carolina, 12 (Belmont, Walnut Cove, Spencer, Eden, Mount Holy, Terrell and Arden).

• Arizona, 9 (Cochise, Joseph City).

• Kentucky, 7 (Louisa, Harrodsburg, Ghent and Louisville).

• Ohio, 6 (Waterford, Brilliant and Cheshire).

• West Virginia, 4 (Willow Island, St. Albans, Moundsville, New Haven).

• Illiniois, 2 (Havana, Alton).

• Indiana, 1 (Lawrenceburg).

• Pennsylvania, 1 (Shippingport).

• Georgia, 1 (Milledgeville).

• Montana, 1 (Colstrip).

Two electric utilities — Columbus, Ohio-based America Electric Power and Charlotte-N.C.-based Duke Energy Corp. — operate nearly half of the coal ash sites on the list. Spokesmen for both companies said the sites are routinely inspected and are safe.

"We go above and beyond to make sure our (coal ash) dams are safe," said AEP spokesman Pat Hemlepp, whose utility has 11 of the ponds on the list. He said the sites are inspected annually by the corporation and more frequently by the individual power plant officials.

Jason Wells, spokesman for Duke Energy, which has 10 sites on the list, said, "We are absolutely confident from our monitoring, maintenance and inspections that the dams have the structural integrity to protect the public and the environment."

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Failed PG&E power line blamed for Drum fire off Hwy 246 last June

PG&E Drum Fire Cause identified as a power line failure in Santa Barbara County, with arcing electricity igniting vegetation near Buellton on Drum Canyon Road; 696 acres burned as investigators and CPUC review PG&E safety.

 

Key Points

A failed PG&E power line sparked the 696-acre Drum Fire near Buellton; the utility is conducting its own probe.

✅ Power line failed between poles, arcing ignited vegetation.

✅ 696 acres burned; no structures damaged or injuries.

✅ PG&E filed CPUC incident report; ongoing investigation.

 

A downed Pacific Gas and Electric Co. power line was the cause of the Drum fire that broke out June 14 on Drum Canyon Road northwest of Buellton, a reminder that a transformer explosion can also spark multiple fires, the Santa Barbara County Fire Department announced Thursday.

The fire broke out about 12:50 p.m. north of Highway 246 and burned about 696 acres of wildland before firefighters brought it under control, although no structures were damaged or mass outages like the Los Angeles power outage occurred, according to an incident summary.

A team of investigators pinpointed the official cause as a power line that failed between two utility poles and fell to the ground, and as downed line safety tips emphasize, arcing electricity ignited the surrounding vegetation, said County Fire Department spokesman Capt. Daniel Bertucelli.

In response, a PG&E spokesman said the utility is conducting its own investigation and does not have access to whatever data investigators used, and, as the ATCO regulatory penalty illustrates, such matters can draw significant oversight, but he noted the company filed an electric incident report on the wire with the California Public Utilities Commission on June 14.

"We are grateful to the first responders who fought the 2020 Drum fire in Santa Barbara County and helped make sure that there were no injuries or fatalities, outcomes not always seen in copper theft incidents, and no reports of structures damaged or burned," PG&E spokesman Mark Mesesan said.

"While we are continuing to conduct our own investigation into the events that led to the Drum fire, and as the Site C watchdog inquiry shows, oversight bodies can seek more transparency, PG&E does not have access to the Santa Barbara County Fire Department's report."

He said PG&E remains focused on reducing wildfire risk across its service area while limiting the scope and duration of public safety power shutoffs, including strategies like line-burying decisions adopted by other utilities, and that the safety of customers and communities it serves are its most important responsibility.

 

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Louisiana power grid needs 'complete rebuild' after Hurricane Laura, restoration to take weeks

Louisiana Grid Rebuild After Hurricane Laura will overhaul transmission lines and distribution networks in Lake Charles, as Entergy restores power after catastrophic outages, replacing poles, transformers, and spans to stabilize critical electric infrastructure.

 

Key Points

Entergy's project replacing transmission and distribution in Lake Charles to restore power after the Cat 4 storm

✅ 1,000+ transmission structures and 6,637 poles damaged

✅ Entergy targets first energized line into Lake Charles in 2 weeks

✅ Full rebuild of Calcasieu and Cameron lines will take weeks

 

The main power utility for southwest Louisiana will need to "rebuild" the region's grid after Hurricane Laura blasted the region with 150 mph winds last week, top officials said.

The Category 4 hurricane made landfall last Thursday just south of Lake Charles near Cameron, damaging or destroying thousands of electric poles as well as leaving "catastrophic damages" to the transmission system for southwest Louisiana, similar to impacts seen during Typhoon Mangkhut outages in Hong Kong that left many without electricity.

“This is not a restoration," Entergy Louisiana president and CEO Phillip May said in a statement. "It’s almost a complete rebuild of our transmission and distribution system that serves Calcasieu and Cameron parishes.”

According to Entergy, all nine transmission lines that deliver power into the Lake Charles area are currently out service due to storm damage to multiple structures and spans of wire.

The transmission system is a critical component in the delivery of power to customers’ homes, and failures at substations can trigger large outages, as seen in Los Angeles station fire outage reported recently, according to the company.

Of those structures impacted, many were damaged "beyond repair" and require complete replacement.

Broken electrical poles are seen in Holly Beach, La., in the aftermath of Hurricane Laura, Saturday, Aug. 29, 2020. (AP Photo/Gerald Herbert)

Entergy said the damage in southwest Louisiana includes 1,000 transmission structures, 6,637 broken poles, 2,926 transformers and 338 miles of downed distribution wire, highlighting why proactive reliability investments in Hamilton are being pursued by other utilities.

Some 8,300 workers are now in the area working to rebuild the transmission lines, but Entergy said that it will be about two to three weeks before power is available to customers in the Lake Charles area, a timeline similar to Tennessee outages after severe storms reported recently in other states.

"Restoring power will take longer to customers in inaccessible areas of the region," the company said. "While not impacting the expected restoration of service to residential customers, initial estimates are it will take weeks to rebuild all transmission lines in Calcasieu and Cameron parishes."

Entergy Louisiana expects to energize the first of its transmission lines into Lake Charles in two weeks.

“We understand going without power for this extended period will be challenging, and this is not the news customers want to hear. But we have thousands of workers dedicated to rebuilding our grid as quickly as they safely can to return some normalcy to our customers’ lives,” May said.

According to power outage tracking website poweroutage.us, over 164,000 customers remain without service in Louisiana as of Thursday morning, while a Carolinas outage update shows hundreds of thousands affected there as well.

On Wednesday, the Edison Electric Institute, the association of investor-owned electric companies in the U.S., said in a statement to FOX Business that electricity has been restored to approximately 737,000 customers, or 75% of those impacted by the storm across Louisiana, eastern Texas, Mississippi, and Arkansas, even as utilities adapt to climate change to improve resilience.

At least 29,000 workers from 29 states, the District of Columbia and Canada are working to restore power in the region, according to the Electricity Subsector Coordinating Council (ESCC), which is coordinating efforts from government and power industry.

“The transmission loss in Louisiana is significant, with more than 1,000 transmission structures damaged or destroyed by the storm," Department of Energy (DOE) Deputy Secretary Mark Menezes said in a statement. Rebuilding the transmission system is essential to the overall restoration effort and will take weeks given the massive scale and complexity of the work. We will continue to coordinate closely to ensure the full capabilities of the industry and government are marshaled to rebuild this critical infrastructure as quickly as possible.” 

At least 17 deaths in Louisiana have been attributed to the storm; more than half of those killed by carbon monoxide poisoning from the unsafe operation of generators, and residents are urged to follow generator safety tips to reduce these risks. Two additional deaths were verified on Wednesday in Beauregard Parish, which health officials said were due to heat-related illness following the storm.

 

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Ireland and France will connect their electricity grids - here's how

Celtic Interconnector, a subsea electricity link between Ireland and France, connects EU grids via a high-voltage submarine cable, boosting security of supply, renewable integration, and cross-border trade with 700 MW capacity by 2026.

 

Key Points

A 700 MW subsea link between Ireland and France, boosting security, enabling trade, and supporting renewables.

✅ Approx. 600 km subsea cable from East Cork to Brittany

✅ 700 MW capacity; powers about 450,000 homes

✅ Financed by EIB, banks, CEF; Siemens Energy and Nexans

 

France and Ireland signed contracts on Friday to advance the Celtic Interconnector, a subsea electricity link to allow the exchange of electricity between the two EU countries. It will be the first interconnector between continental Europe and Ireland, as similar UK interconnector plans move forward in parallel. 

Representatives for Ireland’s electricity grid operator EirGrid and France’s grid operator RTE signed financial and technical agreements for the high-voltage submarine cable, mirroring developments like Maine’s approved transmission line in North America for cross-border power. The countries’ respective energy ministers witnessed the signing.

European commissioner for energy Kadri Simson said:

In the current energy market situation, marked by electricity price volatility, and the need to move away from imports of Russian fossil fuels, European energy infrastructure has become more important than ever.

The Celtic Interconnector is of paramount importance as it will end Ireland’s isolation from the Union’s power system, with parallels to Cyprus joining the electricity highway in the region, and ensure a reliable high-capacity link improving the security of electricity supply and supporting the development of renewables in both Ireland and France.

EirGrid and RTE signed €800 million ($827 million) worth of financing agreements with Barclays, BNP Paribas, Danske Bank, and the European Investment Bank, similar to the Lake Erie Connector investment that blends public and private capital.

In 2019, the project was awarded a Connecting Europe Facility (CEF) grant worth €530.7 million to support construction works and align with a broader push for electrification in Europe under climate strategies. The CEF program also provided €8.3 million for the Celtic Interconnector’s feasibility study and initial design and pre-consultation.

Siemens Energy will build converter stations in both countries, and Paris-based global cable company Nexans will design and install a 575-km-long cable for the project.

The cable will run between East Cork, on Ireland’s southern coast, and northwestern France’s Brittany coast and will connect into substations at Knockraha in Ireland and La Martyre in France.

The Celtic Interconnector, which is expected to be operational by 2026, will be approximately 600 km (373 miles) long and have a capacity of 700 MW, similar to cross-border initiatives such as Quebec-to-New York power exports expected in 2025, which is enough to power 450,000 households.

 

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Quebec premier inaugurates La Romaine hydroelectric complex

La Romaine Hydroelectric Complex anchors Quebec's hydropower expansion, showcasing Hydro-Québec ingenuity, clean energy, electrification, and grid capacity gains along the North Shore's Romaine River to power industry and nearly 470,000 homes.

 

Key Points

A four-station, $7.4B hydro project on Quebec's Romaine River producing 8 TWh a year for electrification and industry.

✅ Generates 8 TWh yearly, powering about 470,000 homes

✅ Largest Quebec hydro build since James Bay project

✅ Key to clean energy, grid capacity, and electrification

 

Quebec Premier François Legault has inaugurated the la Romaine hydroelectric complex on the province's North Shore.

The newly inaugurated Romaine hydroelectric complex could serve as a model for future projects, such as the Carillon Generating Station investment now planned in the province, Legault said.

"It brings me a lot of pride. It is truly the symbol of Quebec ingenuity," he said as he opened the vast power plant.

Legault was accompanied at today's event by Jean Charest, who was Quebec premier when construction began in 2009, as well as Hydro-Québec president and CEO Michael Sabia. 

La Romaine is comprised of four power stations and is the largest hydro project constructed in the province since the Robert Bourassa generation facility, which was commissioned in 1979. It is the biggest hydro installation since the James Bay project, bolstering Hydro-Québec's hydropower capacity across the grid today.

The construction work for Romaine-4 was supposed to finish in 2020, but it was delayed the COVID-19 pandemic, the death of four workers due to security flaws and soil decomposition problems. 

The $7.4-billion la Romaine complex can produce eight terawatt hours of electricity per year, enough to power nearly 470,000 homes.

It generates its power from the Romaine River, located north of Havre-St-Pierre, Que., near the Labrador border, where long-standing Newfoundland and Labrador tensions over Quebec's projects sometimes resurface today.

Legault said that Quebec still doesn't have enough electricity to meet demand from industry, including recent allocations of electricity for industrial projects across the province, and Quebecers need to consider more ways to boost the province's ability to power future projects. The premier has said previously that demand is expected to surge by an additional 100 terawatt-hours by 2050 — half the current annual output of the provincially owned utility.

Legault's environmental plan of reducing greenhouse gases and achieving carbon neutrality by 2050 hinges on increased electrification and a strategy to wean off fossil fuels provincewide, so the electricity needs for transport and industry will be massive.

An updated strategic plan from Hydro-Quebec will be presented in November outlining those needs, president and CEO Michael Sabia told reporters on Thursday, after recent deals with NB Power underscored interprovincial demand.

Legault said the report will trigger a broader debate on energy transition and how the province can be a leader in the green economy. He said he wasn't ruling out any potential power sources — except for a return to nuclear power at this stage.

 

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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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Is a Resurgence of Nuclear Energy Possible in Germany?

Germany Nuclear Phase-Out reflects a decisive energy policy shift, retiring reactors as firms shun new builds amid high costs, radioactive waste challenges, climate goals, insurance gaps, and debate over small modular reactors and subsidies.

 

Key Points

Germany's policy to end nuclear plants and block new builds, emphasizing safety, waste, climate goals, and viability.

✅ Driven by safety risks, waste storage limits, and insurance gaps

✅ High capital costs and subsidies make new reactors uneconomic

✅ Political debate persists; SMRs raise cost and proliferation concerns

 

A year has passed since Germany deactivated its last three nuclear power plants, marking a significant shift in its energy policy.

Nuclear fission once heralded as the future of energy in Germany during the 1960s, was initially embraced with minimal concern for the potential risks of nuclear accidents. As Heinz Smital from Greenpeace recalls, the early optimism was partly driven by national interest in nuclear weapon technology rather than energy companies' initiatives.

Jochen Flasbarth, State Secretary in the Ministry of Development, reflects on that era, noting Germany's strong, almost naive, belief in technology. Germany, particularly the Ruhr region, grappled with smog-filled skies at that time due to heavy industrialization and coal-fired power plants. Nuclear energy presented a "clean" alternative at the time.

This sentiment was also prevalent in East Germany, where the first commercial nuclear power plant came online in 1961. In total, 37 nuclear reactors were activated across Germany, reflecting a widespread confidence in nuclear technology.

However, the 1970s saw a shift in attitudes. Environmental activists protested the construction of new power plants, symbolizing a generational rift. The 1979 Three Mile Island incident in the US, followed by the catastrophic Chornobyl disaster in 1986, further eroded public trust in nuclear energy.

The Chornobyl accident, in particular, significantly dampened Germany's nuclear ambitions, according to Smital. Post-Chernobyl, plans for additional nuclear power plants in Germany, once numbering 60, drastically declined.

The emergence of the Green Party in 1980, rooted in anti-nuclear sentiment, and its subsequent rise to political prominence further influenced Germany's energy policy. The Greens, joining forces with the Social Democrats in 1998, initiated a move away from nuclear energy, facing opposition from the Christian Democrats (CDU) and Christian Social Union (CSU).

However, the Fukushima disaster in 2011 prompted a policy reversal from CDU and CSU under Chancellor Angela Merkel, leading to Germany's eventual nuclear phase-out in March 2023, after briefly extending nuclear power amid the energy crisis.

Recently, the CDU and CSU have revised their stance once more, signaling a potential U-turn on the nuclear phaseout, advocating for new nuclear reactors and the reactivation of the last shut-down plants, citing climate protection and rising fossil fuel costs. CDU leader Friedrich Merz has lamented the shutdown as a "black day for Germany." However, these suggestions have garnered little enthusiasm from German energy companies.

Steffi Lemke, the Federal Environment Minister, isn't surprised by the companies' reluctance, noting their longstanding opposition to nuclear power, which she argues would do little to solve the gas issue in Germany, due to its high-risk nature and the long-term challenge of radioactive waste management.

Globally, 412 reactors are operational across 32 countries, even as Europe is losing nuclear power during an energy crunch, with the total number remaining relatively stable over the years. While countries like China, France, and the UK plan new constructions, there's a growing interest in small, modern reactors, which Smital of Greenpeace views with skepticism, noting their potential military applications.

In Germany, the unresolved issue of nuclear waste storage looms large. With temporary storage facilities near power plants proving inadequate for long-term needs, the search for permanent sites faces resistance from local communities and poses financial and logistical challenges.

Environment Minister Lemke underscores the economic impracticality of nuclear energy in Germany, citing prohibitive costs and the necessity of substantial subsidies and insurance exemptions.

As things stand, the resurgence of nuclear power in Germany appears unlikely, with economic factors playing a decisive role in its future.

 

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