Los Angeles mayor pitches solar power plan

By Los Angeles Times


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Mayor Antonio Villaraigosa proposed a plan to generate a tenth of Los Angeles' power through solar energy by 2020.

Villaraigosa, speaking at a solar panel manufacturing plant, said his plan would produce 1,280 megawatts of power — most from private generating plants in the Mojave Desert, but also from public facilities and smaller programs to encourage residents to install solar panels on their homes.

He touted the installation of 1,700 panels on the roof of the Staples Center this year as a step toward reducing consumption of fossil fuels.

"LA has everything it takes to make this work," Villaraigosa said. "We have the sun in abundancy. We have the space. We have the largest municipal utility in the country."

Los Angeles Department of Water and Power General Manager David Nahai said his agency will conduct a financial analysis of the plan and its effect on ratepayers over the next 90 days.

The mayor is also trying to use redevelopment funds to entice clean technology companies into the city and investing city pension money in environmentally responsible companies in a bid to make Los Angeles a player in the solar energy industry.

A DWP watchdog questioned the financial effects of the mayor's proposal.

"There is one huge assumption here — that they'll get these huge tax credits, volume discounts and economies of scale," said Jack Humphreville, a neighborhood council member who has been pressing the DWP to appoint a ratepayer advocate. "I have serious questions about whether that is pie-in-the-sky or not."

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Western Canada drought impacting hydropower production as reservoirs run low

Western Canada Hydropower Drought strains British Columbia and Manitoba as reservoirs hit historic lows, cutting hydroelectric output and prompting power imports, natural gas peaking, and grid resilience planning amid climate change risks this winter.

 

Key Points

Climate-driven reservoir lows cut hydro in B.C. and Manitoba, prompting imports and backup gas to maintain reliability.

✅ Reservoirs at multi-year lows cut hydro generation capacity

✅ BC Hydro and Manitoba Hydro import electricity for reliability

✅ Natural gas turbines used; climate change elevates drought risk

 

Severe drought conditions in Western Canada are compelling two hydroelectricity-dependent provinces, British Columbia and Manitoba, to import power from other regions. These provinces, known for their reliance on hydroelectric power, are facing reduced electricity production due to low water levels in reservoirs this autumn and winter as energy-intensive customers encounter temporary connection limits.

While there is no immediate threat of power outages in either province, experts indicate that climate change is leading to more frequent and severe droughts. This trend places increasing pressure on hydroelectric power producers in the future, spurring interest in upgrading existing dams as part of adaptation strategies.

In British Columbia, several regions are experiencing "extreme" drought conditions as classified by the federal government. BC Hydro spokesperson Kyle Donaldson referred to these conditions as "historic," and a first call for power highlights the strain, noting that the corporation's large reservoirs in the north and southeast are at their lowest levels in many years.

To mitigate this, BC Hydro has been conserving water by utilizing less affected reservoirs and importing additional power from Alberta and various western U.S. states. Donaldson confirmed that these measures would persist in the upcoming months.

Manitoba is also facing challenges with below-normal levels in reservoirs and rivers. Since October, Manitoba Hydro has occasionally relied on its natural gas turbines to supplement hydroelectric production as electrical demand could double over the next two decades, a measure usually reserved for peak winter demand.

Bruce Owen, a spokesperson for Manitoba Hydro, reassured that there is no imminent risk of a power shortage. The corporation can import electricity from other regions, similar to how it exports clean energy in high-water years.

However, the cost implications are significant. Manitoba Hydro anticipates a financial loss for the current fiscal year, with more red ink tied to emerging generation needs, the second in a decade, with the previous one in 2021. That year, drought conditions led to a significant reduction in the company's power production capabilities, resulting in a $248-million loss.

The 2021 drought also affected hydropower production in the United States. The U.S. Department of Energy reported a 16% reduction in overall generation, with notable decreases at major facilities like Nevada's Hoover Dam, where production dropped by 25%.

Drought has long been a major concern for hydroelectricity producers, and they plan their operations with this risk in mind. Manitoba's record drought in 1940-41, for example, is a benchmark for Manitoba Hydro's operational planning to ensure sufficient electricity supply even in extreme low-water conditions.

Climate change, however, is increasing the frequency of such rare events, highlighting the need for more robust backup systems such as new turbine investments to enhance reliability. Blake Shaffer, an associate professor of economics at the University of Calgary specializing in electricity markets, emphasized the importance of hydroelectric systems incorporating the worsening drought forecasts due to climate change into their energy production planning.

 

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Duke Energy Florida to build its largest battery storage projects yet

Duke Energy Florida battery storage will add 22 MW across Trenton, Cape San Blas and Jennings, improving grid reliability, outage resilience, enabling peak shaving and deferring distribution upgrades to increase efficiency and customer value.

 

Key Points

Three lithium battery projects totaling 22 MW to improve Florida grid reliability, outage resilience and efficiency.

✅ 22 MW across Trenton, Cape San Blas and Jennings sites

✅ Enhances outage resilience and grid reliability

✅ Defers costly distribution upgrades and improves efficiency

 

Duke Energy Florida (DEF) has announced three battery energy storage projects, totaling 22 megawatts, that will improve overall reliability and support critical services during power outages.

Duke Energy, the nation's largest electric utility, unveils its new logo. (PRNewsFoto/Duke Energy) (PRNewsfoto/Duke Energy)

Collectively, the storage facilities will enhance grid operations, increase efficiencies and improve overall reliability for surrounding communities, with virtual power plant programs offering a model for coordinating distributed resources.

They will also provide important backup generation during power outages, a service that is becoming increasingly important with the number and intensity of storms that have recently impacted the state.

As the grid manager and operator, DEF can maximize the versatility of battery energy storage systems (BESS) to include multiple customer and electric system benefits such as balancing energy demand, managing intermittent resources, increasing energy security and deferring traditional power grid upgrades.

These benefits help reduce costs for customers and increase operational efficiencies.

The 11-megawatt (MW) Trenton lithium-based battery facility will be located 30 miles west of Gainesville in Gilchrist County. The energy storage project will continue to improve power reliability using newer technologies.

The 5.5-MW Cape San Blas lithium-based battery facility will be located approximately 40 miles southeast of Panama City in Gulf County. The project will provide additional power capacity to meet our customers' rising energy demand in the area. This project is an economical alternative to replacing distribution equipment necessary to accommodate local load growth.

The 5.5-MW Jennings lithium-based battery facility will be located 1.5 miles south of the Florida-Georgia border in Hamilton County. The project will continue to improve power reliability through energy storage as an alternative solution to installing new and more costly distribution equipment.

Currently the company plans to complete all three projects by the end of 2020.

"These battery projects provide electric system benefits that will help improve local reliability for our customers and provide significant energy services to the power grid," said Catherine Stempien, Duke Energy Florida state president. "Duke Energy Florida will continue to identify opportunities in battery storage technology which will deliver efficiency improvements to our customers."

 

Additional renewables projects

As part of DEF's commitment to renewables, the company is investing an estimated $1 billion to construct or acquire a total of 700 MW of cost-effective solar power facilities and 50 MW of battery storage through 2022.

Duke Energy is leading the industry deployment of battery technology, with SDG&E's Emerald Storage project underscoring broader adoption across the sector today. Last fall, the company and University of South Florida St. Petersburg unveiled a Tesla battery storage system that is connected to a 100-kilowatt (kW) solar array – the first of its kind in Florida.

This solar-battery microgrid system manages the energy captured by the solar array, situated on top of the university's parking garage, and similar low-income housing microgrid financing efforts are expanding access. The solar array was constructed three years ago through a $1 million grant from Duke Energy. The microgrid provides a backup power source during a power outage for the parking garage elevator, lights and electric vehicle charging stations. Click here to learn more.

In addition to expanding its battery storage technology and solar investments, DEF is investing in transportation electrification to support the growing U.S. adoption of electric vehicles (EV), including EV charging infrastructure, 530 EV charging stations and a modernized power grid to deliver the diverse and reliable energy solutions customers want and need.

 

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Investing in a new energy economy for Montana

Montana New Energy Economy integrates grid modernization, renewable energy, storage, and demand response to cut costs, create jobs, enable electric transportation, and reduce emissions through utility-scale efficiency, real-time markets, and distributed resources.

 

Key Points

Plan to modernize Montana's grid with renewables, storage and efficiency to lower costs, cut emissions and add jobs.

✅ Grid modernization enables real-time markets and demand response

✅ Utility-scale renewables paired with storage deliver firm power

✅ Efficiency and DERs cut peaks, costs, and pollution

 

Over the next decade, Montana ratepayers will likely invest over a billion dollars into what is now being called the new energy economy.

Not since Edison electrified a New York City neighborhood in 1882 have we had such an opportunity to rethink the way we commercially produce and consume electric energy.

Looking ahead, the modernization of Edison’s grid will lower the consumer costs, creating many thousands of permanent, well-paying jobs. It will prepare the grid for significant new loads like America going electric in transportation, and in doing so it will reduce a major source of air pollution known to directly threaten the core health of Montana and the planet.

Energy innovation makes our choices almost unrecognizable from the 1980s, when Montana last built a large, central-station power plant. Our future power plants will be smaller and more modular, efficient and less polluting — with some technologies approaching zero operating emissions.

The 21st Century grid will optimize how the supply and demand of electricity is managed across larger interconnected service areas. Utilities will interact more directly with their consumers, with utility trends guiding a new focus on providing a portfolio of energy services versus simply spinning an electric meter. Investments in utility-scale energy efficiency — LED streetlights, internet-connected thermostats, and tightening of commercial building envelopes among many — will allow consumers to directly save on their monthly bills, to improve their quality of life, and to help utilities reduce expensive and excessive peaks in demand.

The New Energy Economy will be built not of one single technology, but of many — distributed over a modernized grid across the West that approaches a real-time energy market, as provinces pursue market overhauls to adapt — connecting consumers, increasing competition, reducing cost and improving reliability.

Boldly leading the charge is a new and proven class of commercial generation powered by wind and solar energy, the latter of which employs advanced solid-state electronics, free fuel and no emissions or moving parts. Montana is blessed with wind and solar energy resources, so this is a Made-in-Montana energy choice. Note that these plants are typically paired with utility-scale energy storage investments — also an essential building block of the 21st century grid — to deliver firm, on-demand electric service.

Once considered new age and trendy, these production technologies are today competent and shovel-ready. Their adoption will build domestic energy independence. And, they are aggressively cost-competitive. For example, this year the company ISO New England — operator of a six-state grid covering all of New England — released an all-source bid for new production capacity. Unexpectedly, 100% of the winning bids were large solar electric power and storage projects, as coal and nuclear disruptions continue to shape markets. For the first time, no applications for fossil-fueled generation cleared auction.

By avoiding the burning of traditional fuels, the new energy technologies promise to offset and eventually eliminate the current 1,500 million metric tons of damaging greenhouse gases — one-quarter of the nation’s total — that are annually injected into the atmosphere by our nation’s current electric generation plants. The first step to solving the toughest and most expensive environmental issues of our day — be they costly wildfires or the regional drought that threatens Montana agriculture and outdoor recreation — is a thoughtful state energy policy, built around the new energy economy, that avoids pitfalls like the Wyoming clean energy bill now proposed.

Important potential investments not currently ready for prime time are also on the horizon, including small and highly efficient nuclear innovation in power plants — called small modular reactors (SMR) — designed to produce around-the-clock electric power with zero toxic emissions.

The nation’s first demonstration SMR plant is scheduled to be built sometime late this decade. Fingers are crossed for a good outcome. But until then, experts agree that big questions on the future commercial viability of nuclear remain unanswered: What will be SMR’s cost of electricity? Will it compete? Where will we source the refined fuel (most uranium is imported), and what will be the plan for its safe, permanent disposal?

So, what is Montana’s path forward? The short answer is: Hopefully, all of the above.

Key to Montana’s future investment success will be a respectful state planning process that learns from Texas grid improvements to bolster reliability.

Montanans deserve a smart and civil and bipartisan conversation to shape our new energy economy. There will be no need, nor place, for parties that barnstorm the state about "radical agendas" and partisan name calling – that just poisons the conversation, eliminates creative exchange and pulls us off task.

The task is to identify and vet good choices. It’s about permanently lowering energy costs to consumers. It’s about being business smart and business friendly. It’s about honoring the transition needs of our legacy energy communities. And, it’s about stewarding our world-class environment in earnest. That’s the job ahead.

 

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The Need for Electricity During the COVID-19 Pandemic

US utilities COVID-19 resilience shows electric utilities maintaining demand stability, reaffirming earnings guidance, and accessing the bond market for low-cost financing, as Dominion, NextEra, and Con Edison manage recession risks.

 

Key Points

It is the sector's capacity to sustain demand, financing access, and guidance despite pandemic recession pressures.

✅ Bond market access locks in low-cost, long-term debt

✅ Stable residential load offsets industrial weakness

✅ Guidance largely reaffirmed by major utilities

 

Dominion Energy (D) expects "incremental residential load" gains, consistent with COVID-19 electricity demand patterns, as a result of COVID-19 fallout. Southern Company CEO Tom Fanning says his company is "nowhere near" a need to review earnings guidance because of a potential recession, in a region where efficiency and demand response can help level electricity demand for years.

Sempra Energy (SRE) has reaffirmed earnings per share guidance for 2020 and 2021, as well timing for the sale of assets in Chile and Peru, and peers such as Duke Energy's renewables plan have reaffirmed capital investments to deliver cleaner energy and economic growth. And Xcel Energy (XEL) says it still "hasn’t seen material impact on its business."

Several electric utilities have demonstrated ability to tap the bond market, in line with utility sector trends in recent years, to lock in low-cost financing, as America moves toward broader electrification, despite ongoing turmoil. Their ranks include Dominion Energy, renewable energy leader NextEra Energy (NEE) and Consolidated Edison (ED), which last week sold $1 billion of 30-year bonds at a coupon rate of just 3.95 percent.

It’s still early days for US COVID-19 fallout. And most electric companies have yet to issue guidance. That’s understandable, since so much is still unknown about the virus and the damage it will ultimately do to human health and the global economy. But so far, the US power industry is showing typical resilience in tough times, as it coordinates closely with federal partners to maintain reliability.

Will it last? We won’t know for certain until there’s a lot more data. NextEra is usually first to report its Q1 earnings reports and detailed guidance. But that’s not expected until April 23. And companies may delay financials further, should the virus and efforts to control it impede collection and analysis of data, and as they address electricity shut-off risks affecting customers.

 

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Cooperation agreement for Rosatom and Russian Academy

Rosatom-RAS Cooperation drives joint R&D in nuclear energy, nuclear medicine, fusion, particle accelerators, laser technologies, fuel cycle safety, radioactive waste management, and supercomputing, aligning strategic planning and standards to accelerate innovation across Russia's nuclear sector.

 

Key Points

A pact uniting Rosatom and RAS on nuclear R&D, fusion, and medicine to advance nuclear technologies across Russia.

✅ Joint R&D in fusion, accelerators, lasers, and new materials

✅ Focus on fuel cycle closure, safety, and waste management

✅ Shared strategic planning, standards, and expert evaluation

 

Russian state atomic energy corporation Rosatom and the Russian State Academy of Sciences are to cooperate on joint scientific, technical and innovative activities in areas including nuclear energy, nuclear medicine and other areas of the electricity sector under an agreement signed in Moscow on 7 February.

The cooperation agreement was signed by Rosatom Director General Alexei Likhachov and President of the Russian Academy of Sciences Alexander Sergeev during a joint meeting to mark Russian Science Day. Under its terms, the partners will cooperate in organising research and development activities aimed at providing technological advantages in various sectors of the domestic industry, as well as creating and developing interdisciplinary scientific and technological centres and organisations supporting energy sector training and innovation. They will also jointly develop strategic planning documents, improve the technical and scientific regulatory and legal framework, and carry out expert evaluations of scientific and technical projects and scientific consultations.

Rosatom said the main areas of cooperation in the agreement are: the development of laser technologies and particle accelerators; the creation of modern diagnostic equipment, nuclear medicine and radiation therapy; controlled thermonuclear fusion; nuclear energy of the future; new materials; the nuclear fuel cycle and its closure; safety of nuclear energy and power sector pandemic response preparedness; environmental aspects of radioactive waste management; modern supercomputers, databases, application packages, and import-substituting codes; and also X-ray astronomy and nuclear planetology.

Likhachov said joint activities between Rosatom and the Academy would strengthen the Russian nuclear industry's "leadership" in the world and allow the creation of new technologies that would shape the future image of the nuclear industry in Russia. "Within the framework of the Agreement, we intend to expand work on the entire spectrum of advanced scientific research. The most important direction of our cooperation will be the integration of fundamental, exploratory and applied scientific research, including in the interests of the development of the nuclear industry. We will work together to form the nuclear energy industry of the future, and enhance grid resilience, to create new materials, new radiation technologies,” he said.

Sergeyev noted the "rich history" of cooperation between the Academy of Sciences and the nuclear industry, including modern safety practices such as arc flash training that support operations. “All major projects in the field of military and peaceful nuclear energy were carried out jointly by scientists and specialists of our organisations, which largely ensured their timeliness and success," he said.

 

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California Halts Energy Rebate Program Amid Trump Freeze

California energy rebate freeze disrupts heat pump incentives, HVAC upgrades, and climate funding, as federal uncertainty stalls Inflation Reduction Act support, delaying home electrification, energy efficiency gains, and greenhouse gas emissions reductions statewide.

 

Key Points

A statewide pause on $290M incentives for heat pumps and HVAC upgrades due to federal climate funding uncertainty.

✅ $290M program paused amid federal funding freeze

✅ Heat pump, HVAC, electrification upgrades delayed

✅ Previously approved rebates honored; new apps halted

 

California’s push for a more energy-efficient future has hit a significant roadblock as the state pauses a $290 million rebate program aimed at helping homeowners replace inefficient heating and cooling systems with more energy-efficient alternatives. The California Energy Commission announced the suspension of the program, citing uncertainty stemming from President Donald Trump’s decision to freeze funding for various climate-related initiatives.

The Halted Program

The energy rebate program, which utilizes federal funding to encourage the use of energy-efficient appliances such as heat pumps, was a crucial part of California’s efforts to reduce energy consumption and greenhouse gas emissions. By providing financial incentives for homeowners to upgrade to more efficient heating and cooling systems, the program aimed to make green energy solutions more accessible and affordable to residents. The rebate program had been popular, with many homeowners eager to participate in the initiative to lower their energy costs and improve the sustainability of their homes.

However, due to the uncertainty surrounding federal funding, the California Energy Commission announced on Monday that it would no longer be accepting new applications for the program. The agency did clarify that it would continue to honor rebates for applications that had already been approved. The pause will remain in effect until the Trump administration provides more clarity regarding the program's future funding.

The Trump Administration’s Role

This move highlights a broader issue regarding access to federal funding for state-level energy programs. The Trump administration’s decision to freeze funding for climate-related initiatives has left many states in limbo, as previously approved federal money has not been distributed as expected. Despite federal court rulings directing the Trump administration to restore these funds, states like California are still struggling to navigate the uncertainty of climate-related financial support from the federal government.

California’s decision to pause the rebate program comes after similar actions by other states. Arizona paused a similar program just a week prior, and Rhode Island had already paused new applications earlier this year. These states are all recipients of funding from a larger $4.3 billion initiative under the Inflation Reduction Act, which is designed to help homeowners purchase energy-efficient appliances like heat pumps, water heaters, and electric cooktops.

Impact of the Freeze

The pause of California's rebate program has serious implications for both consumers and the state’s energy goals. For residents, the halt means delays in the ability to upgrade to more energy-efficient home systems, which could lead to higher energy costs in the short term, a concern amid soaring electricity prices across the state.

The $290 million program was a significant step in encouraging homeowners to invest in energy efficiency, and its suspension leaves a gap in the availability of resources for those who were hoping to make energy-saving upgrades. Many of these upgrades are not just beneficial to homeowners, but they also contribute to the state’s overall energy efficiency goals, helping to reduce reliance on non-renewable energy sources, even as California's dependence on fossil fuels persists, and decrease greenhouse gas emissions.

Federal and State Tensions

The freeze in funding is just one of many points of tension between the Trump administration and states like California, which have pursued aggressive environmental policies aimed at reducing emissions and combating climate change. California has often found itself at odds with the federal government on environmental issues, especially under the leadership of President Trump. The state’s ambitious environmental policies have sometimes clashed with the federal government's approach, including efforts to wind down its fossil fuel industry in line with climate goals.

In this case, the freeze on climate-related funding appears to be part of a broader strategy by the Trump administration to limit federal spending on environmental programs, and as regulators weigh whether the state may need more power plants, planning remains complex. While the freeze impacts states that are working to transition to clean energy, critics argue that such moves undermine efforts to tackle climate change and could slow down progress toward a greener future.

The Path Forward

For California, the next steps will depend heavily on the actions of the federal government. While the state can continue to push for climate funding in the courts, the lack of clarity around the release of federal funds creates uncertainty for state programs that rely on these resources. As California continues to navigate this funding freeze, it will need to explore alternative solutions to keep its energy efficiency programs on track, such as efforts to revamp electricity rates to clean the grid, even in the face of federal challenges.

In the meantime, California residents and homeowners who were hoping to take advantage of the rebate program may have to wait until further clarification from the federal government is provided, even as officials warn of a looming electricity shortage in coming years. Whether the program can be restored or expanded in the future remains to be seen, but for now, the pause serves as a reminder of the ongoing struggles that states face when dealing with shifting federal priorities.

As the issue unfolds, other states facing similar challenges may take cues from California’s actions, and with California exporting energy policies to Western states, broader conversations about how federal and state governments can collaborate to ensure that energy efficiency initiatives and climate goals are not sidelined due to political or budgetary differences.

California’s decision to pause its $290 million energy rebate program is a significant development in the ongoing struggle between state and federal governments over climate-related funding. The uncertainty created by the Trump administration’s freeze on energy efficiency programs has led to disruptions in state-level efforts to promote sustainability and reduce emissions. As the situation continues to evolve, both California and other states will need to consider how to move forward without relying on federal funding that may or may not be available in the future.

 

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