Southwest utility companies buying into solar

By Mother Earth News


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Utilities in or near the southwestern United States are planning to build or buy power from massive concentrating solar power (CSP) plants, while utilities throughout the nation are investing in solar photovoltaic (PV) power plants. Both initiatives are creating growing momentum for the utility deployment of solar power throughout the country.

In terms of CSP plants, Southern California Edison recently reached an agreement with BrightSource Energy for 1,300 megawatts (MW) of solar power, which qualifies as the world's largest solar power deal to date. The agreement calls for a series of seven projects, starting with a 100-MW CSP plant that could start operating near Ivanpah, Calif., in early 2013.

BrightSource Energy employs “power tower” technology, in which a field of thousands of flat mirrors, called heliostats, focuses sunlight onto a boiler mounted at the top of a tower. Steam produced in the boiler is piped to a turbine, which drives a generator to produce electricity. A commercial power tower was recently built in Spain, but only demonstration plants have been built in the United States. In addition, NRG Energy Inc. signed an agreement with eSolar to develop three solar projects totaling as much as 500 MW, also using solar power towers.

For PV power plants, California's Pacific Gas and Electric Company (PG&E) appears to be taking a leadership position, as the utility announced in late February that it plans to develop and own up to 250 MW of solar power facilities, while buying power from another 250 MW of solar power owned by independent developers. The California Public Utilities Commission has also approved two previous large contracts PG&E has signed with solar power developers, including a contract for 550 MW of thin-film solar PV from Topaz Solar Farms on the Carrizo Plain in San Luis Obispo County, as well as another contract with High Plains Solar Farms for 210 MW of silicon solar panels.

SunPower Inc. owns the latter project, and the former project was owned by OptiSolar Inc., but First Solar Inc. just bought out all of OptiSolar's projects, including the PG&E project. In the fourth quarter of 2008, First Solar managed to cut the manufacturing cost for its thin-film solar modules to 98 cents per watt, breaking the $1-per-watt cost barrier. The company's annual production capacity is expected to exceed 1,000 megawatts per year by the end of this year.

While California has a definite lead in solar power development, utilities in other states are now pursuing megawatt-scale solar PV projects. In New Jersey, the Public Service Electric and Gas Company has proposed to spend $773 million to support the development of 120 MW of solar PV power through many projects located throughout its service territory.

In New York, Governor David Paterson announced that the Long Island Power Authority is planning to support 50 MW of new solar power, including 13.1 MW of smaller projects developed by enXco and 36.9 MW to be installed by BP Solar in two large projects at the Department of EnergyÂ’s Brookhaven National Laboratory.

Down in the Sunshine State, Florida Power & Light has just broken ground on the DeSoto Next Generation Solar Energy Center, a 25-MW solar PV facility that should be completed by the end of the year.

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Ontario Breaks Ground on First Small Modular Nuclear Reactor

Ontario SMR BWRX-300 leads Canada in next-gen nuclear energy at Darlington, with GE Vernova and Hitachi, delivering clean, reliable power via modular design, passive safety, scalability, and lower costs for grid integration.

 

Key Points

Ontario SMR BWRX-300 is a 300 MW modular boiling water reactor at Darlington with passive safety and clean power.

✅ 300 MW BWR supplies power for about 300,000 homes

✅ Passive safety enables safe shutdown without external power

✅ Modular design reduces costs and speeds grid integration

 

Ontario has initiated the construction of Canada's first small modular nuclear reactor (SMR), supported by OPG's SMR commitment to deployment, marking a significant milestone in the province's energy strategy. This development positions Ontario at the forefront of next-generation nuclear technology within the G7 nations.

The project, known as the Darlington New Nuclear Project, is being led by Ontario Power Generation (OPG) in collaboration with GE Vernova and Hitachi Nuclear Energy, and through its OPG-TVA partnership on new nuclear technology development. The chosen design is the BWRX-300, a 300-megawatt boiling water reactor that is approximately one-tenth the size and complexity of traditional nuclear reactors. The first unit is expected to be operational by 2029, with plans for additional units to follow.

Each BWRX-300 reactor is projected to supply electricity to about 300,000 homes, contributing to Ontario's efforts, which include the decision to refurbish Pickering B for additional baseload capacity, to meet the anticipated 75% increase in electricity demand by 2050. The compact design of the SMR allows for easier integration into existing infrastructure, reducing the need for extensive new transmission lines.

The economic impact of the project is substantial. The construction of four such reactors is expected to create up to 18,000 jobs and contribute approximately $38.5 billion CAD to the Canadian economy, reflecting the economic benefits of nuclear projects over 65 years. The modular nature of SMRs also allows for scalability, with each additional unit potentially reducing costs through economies of scale.

Safety is a paramount consideration in the design of the BWRX-300. The reactor employs passive safety features, meaning it can safely shut down without the need for external power or operator intervention. This design enhances the reactor's resilience to potential emergencies, aligning with stringent regulatory standards.

Ontario's commitment to nuclear energy is further demonstrated by its plans for four SMRs at the Darlington site. This initiative reflects a broader strategy to diversify the province's energy mix, incorporating clean and reliable power sources to complement renewable energy efforts.

While the development of SMRs in Ontario is a significant step forward, it also aligns with the Canadian nuclear initiative positioning Canada as a leader in the global nuclear energy landscape. The successful implementation of the BWRX-300 could serve as a model for other nations exploring advanced nuclear technologies.

Ontario's groundbreaking work on small modular nuclear reactors represents a forward-thinking approach to energy generation. By embracing innovative technologies, the province is not only addressing future energy demands but also, through the Pickering NGS life extension, contributing to the global transition towards sustainable and secure energy solutions.

 

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Ontario to Rely on Battery Storage to Meet Rising Energy Demand

Ontario Battery Energy Storage anchors IESO strategy, easing peak demand and boosting grid reliability. Projects like Oneida BESS (250MW) and nearly 3GW procurements integrate renewables, wind and solar, enabling flexible, decarbonized power.

 

Key Points

Provincewide grid batteries help IESO manage peaks, integrate renewables, and strengthen reliability across Ontario.

✅ IESO forecasts 1,000MW peak growth by 2026

✅ Oneida BESS adds 250MW with 20-year contract

✅ Nearly 3GW storage procured via LT1 and other RFPs

 

Ontario’s electricity grid is facing increasing demand amid a looming supply crunch, prompting the province to invest heavily in battery energy storage systems (BESS) as a key solution. The Ontario Independent Electricity System Operator (IESO) has highlighted that these storage technologies will be crucial for managing peak demand in the coming years.

Ontario's energy demands have been on the rise, driven by factors such as population growth, electric vehicle manufacturing, data center expansions, and heavy industrial activity. The IESO's latest assessment, and its work on enabling storage, covering the period from April 2025 to September 2026, indicates that peak demand will increase by approximately 1,000MW between the summer of 2025 and 2026. This forecasted rise in energy use is attributed to the acceleration of various sectors within the province, underscoring the need for reliable, scalable energy solutions.

A significant portion of this solution will be met by large-scale energy storage projects. Among the most prominent is the Oneida BESS, a flagship project that will contribute 250MW of storage capacity. This project, developed by a consortium including Northland Power and NRStor, will be located on land owned by the Six Nations of the Grand River. Expected to be operational soon, it will play a pivotal role in ensuring grid stability during high-demand periods. The project benefits from a 20-year contract with the IESO, guaranteeing payments that will support its financial viability, alongside additional revenue from participating in the wholesale energy market.

In addition to Oneida, Ontario has committed to acquiring nearly 3GW of energy storage capacity through various procurement programs. The 2023 Expedited Long-Term 1 (LT1) request for proposals (RfP) alone secured 881MW of storage, with additional projects in the pipeline. A notable example is the Hagersville Battery Energy Storage Park, which, upon completion, will be the largest such project in Canada. The success of these procurement efforts highlights the growing importance of BESS in Ontario's energy strategy.

The IESO’s proactive approach to energy storage is not only a response to rising demand but also a step toward decarbonizing the province’s energy system. As Ontario transitions away from traditional fossil fuels, BESS will provide the necessary flexibility to accommodate increasing renewable energy generation, a clean energy solution widely recognized in jurisdictions like New York, particularly from intermittent sources like wind and solar. By storing excess energy during periods of low demand and dispatching it when needed, these systems will help maintain grid stability, and as many utilities see benefits even without mandates, reduce reliance on fossil fuel-based power plants.

Looking ahead, Ontario's energy storage capacity is expected to grow significantly, complemented by initiatives such as the Hydrogen Innovation Fund, with projects from the 2023 LT1 RfP expected to come online by 2027. As more storage resources are integrated into the grid, the province is positioning itself to meet its rising energy needs while also advancing its environmental goals.

Ontario’s increasing reliance on battery energy storage is a clear indication of the province’s commitment to a sustainable and resilient energy future, aligning with perspectives from Sudbury sustainability advocates on the grid's future. With substantial investments in storage technology, Ontario is not only addressing current energy challenges but also paving the way for a cleaner, more reliable energy system in the years to come.

 

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U.S. offshore wind power about to soar

US Offshore Wind Lease Sales signal soaring renewable energy growth, drawing oil and gas developers, requiring BOEM auctions, seismic surveying, transmission planning, with $70B investment, 8 GW milestones, and substantial job creation in coastal communities.

 

Key Points

BOEM-run auctions granting areas for offshore wind, spurring projects, investment, and jobs in federal waters.

✅ $70B investment needed by 2030 to meet current demand

✅ 8 GW early buildout could create 40,000 US jobs

✅ Requires BOEM auctions, seismic surveying, transmission corridors

 

Recent offshore lease sales demonstrate that not only has offshore wind arrived in the U.S., but it is clearly set to soar, as forecasts point to a $1 trillion global market in the coming decades. The level of participation today, especially from seasoned offshore oil and gas developers, exemplifies that the offshore industry is an advocate for the 'all of the above' energy portfolio.

Offshore wind could generate 160,000 direct, indirect and induced jobs, with 40,000 new U.S. jobs with the first 8 gigawatts of production, while broader forecasts see a quarter-million U.S. wind jobs within four years.

In fact, a recent report from the Special Initiative on Offshore Wind (SIOW), said that offshore wind investment in U.S. waters will require $70 billion by 2030 just based on current demand, and the UK's rapid scale-up offers a relevant benchmark.

Maintaining this tremendous level of interest from offshore wind developers requires a reliable inventory of regularly scheduled offshore wind sales and the ability to develop those resources. Coastal communities and extreme environmental groups opposing seismic surveying and the issuance of incidental harassment authorizations under the Marine Mammal Protection Act may literally take the wind out of these sales. Just as it is for offshore oil and gas development, seismic surveying is vital for offshore wind development, specifically in the siting of wind turbines and transmission corridors.

Unfortunately, a long-term pipeline of wind lease sales does not currently exist. In fact, with the exception of a sale proposed offshore New York offshore wind or potentially California in 2020, there aren't any future lease sales scheduled, leaving nothing upon which developers can plan future investments and prompting questions about when 1 GW will be on the grid nationwide.

NOIA is dedicated to working with the Bureau of Ocean Energy Management and coastal communities, consumers, energy producers and other stakeholders, drawing on U.K. wind lessons where applicable, in working through these challenges to make offshore wind a reality for millions of Americans.

 

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Ontario Provides Stable Electricity Pricing for Industrial and Commercial Companies

Ontario ICI Electricity Pricing Freeze helps Industrial Conservation Initiative (ICI) participants by stabilizing Global Adjustment charges, suspending peak hours curtailment, and reducing COVID-19-related electricity cost volatility to support large employers returning operations to full capacity.

 

Key Points

A two-year policy stabilizing GA costs and pausing peak-hour cuts to aid industrial and commercial recovery.

✅ GA cost share frozen for two years

✅ No peak-hour curtailment obligations

✅ Supports industrial and commercial restart

 

The Ontario government is helping large industrial and commercial companies return to full levels of operation without the fear of electricity costs spiking by providing more stable electricity pricing for two years. Effective immediately, companies that participate in the Industrial Conservation Initiative (ICI) will not be required to reduce their electricity usage during peak hours or shift some load to ultra-low overnight pricing where applicable, as their proportion of Global Adjustment (GA) charges for these companies will be frozen.

"Ontario's industrial and commercial electricity consumers continue to experience unprecedented economic challenges during COVID-19, with electricity relief for households and small businesses introduced to help," said Greg Rickford, Minister of Energy, Northern Development and Mines. "Today's announcement will allow large industrial employers to focus on getting their operations up and running and employees back to work, instead of adjusting operations in response to peak electricity demand hours."

Due to COVID-19, electricity consumption in Ontario has been below average as fall in demand as people stayed home across the province, and the province is forecast to have a reliable supply of electricity, supported by the system operator's staffing contingency plans during the pandemic, to accommodate increased usage. Peak hours generally occur during the summer when the weather is hot and electricity demand from cooling systems is high.

"Today's action will reduce the burden of anticipating and responding to peak hours for more than 1,300 ICI participants with 2,000 primarily industrial facilities in Ontario," said Bill Walker, Associate Minister of Energy. "Now these large employers can focus on getting their operations back up and running at full tilt and explore new energy-efficiency programs to manage costs."

The government previously announced it was providing temporary relief for industrial and commercial electricity consumers that do not participate in the Regulated Price Plan (RPP) by deferring a portion of GA charges for April, May and June 2020 and by extending off-peak rates for many customers, as well as a disconnect moratorium extension for residential electricity users.

 

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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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PG&E Wildfire Assistance Program Accepting Applications for Aid

PG&E Wildfire Assistance Program offers court-approved aid and emergency grants for Northern California wildfires and Camp Fire victims, covering unmet needs, housing, and essentials; apply online by November 15, 2019 under Chapter 11-funded eligibility.

 

Key Points

A $105M, court-approved aid fund offering unmet-needs payments and emergency support for 2017-2018 wildfire victims.

✅ $5,000 Basic Unmet Needs per household, self-certified

✅ Supplemental aid for extreme circumstances after basic grants

✅ Apply online; deadline November 15, 2019; identity required

 

Beginning today, August 15, 2019, those displaced by the 2017 Northern California wildfires and 2018 Camp fire can apply for aid through an independently administered Wildfire Assistance Program funded by Pacific Gas and Electric Company (PG&E). PG&E’s $105 million fund, approved by the judge in PG&E’s Chapter 11 cases and related bankruptcy plan, is intended to help those who are either uninsured or need assistance with alternative living expenses or other urgent needs. The court-approved independent administrator is set to file the eligibility criteria as required by the court and will open the application process.

“Our goal is to get the money to those who most need it as quickly as possible. We will prioritize wildfire victims who have urgent needs, including those who are currently without adequate shelter,” said Cathy Yanni, plan administrator. Yanni is partnering with local agencies and community organizations to administer the fund, and PG&E also supports local communities through property tax contributions to counties.

“We appreciate the diligent work of the fund administrator in quickly establishing a way to distribute these funds and ensuring the program supports those with the most immediate needs. PG&E is focused on helping those impacted by the devastating wildfires in recent years and strengthening our energy system to reduce wildfire risks and prevent utility-caused catastrophic fires. We feel strongly that helping these communities now is the right thing to do,” said Bill Johnson, CEO and President of PG&E Corporation.

Applicants can request a “Basic Unmet Needs” payment of $5,000 per household for victims who establish basic eligibility requirements and self-certify that they have at least $5,000 of unmet needs that have not been compensated by the Federal Emergency Management Agency (FEMA). Payments are to support needs such as water, food, prescriptions, medical supplies and equipment, infant formula and diapers, personal hygiene items, and transportation fuels beyond what FEMA covered in the days immediately following the declared disasters, aligning with broader health and safety actions the company has taken.

Those who receive basic payments may also qualify for a “Supplemental Unmet Needs” payment. These funds will be available only after “Basic Unmet Needs” payments have been issued. Supplemental payments will be available to individuals and families who currently face extreme or extraordinary circumstances as compared to others who were impacted by the 2017 and 2018 wildfires, including areas affected by power line-related fires across California.

To qualify for the payments, applicants’ primary residence must have been within the boundary of the 2017 Northern California wildfires or the 2018 Camp fire in Butte County. Applicants also must establish proof of identity and certify that they are not requesting payments for an expense already paid for by FEMA.

Applicants can find more information and apply for assistance at https://www.norcalwildfireassistanceprogram.com/. The deadline to file for aid is November 15, 2019.

The $105 million being provided by PG&E was made available from the company’s cash reserves. PG&E will not seek cost recovery from its customers, and its rates are set to stabilize in 2025 according to recent guidance.

 

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