Coal ash polluting water, says group

California Governor Gavin Newsom vetoed a bill aimed at expanding load flexibility in state grid planning, citing conflicts with California’s resource adequacy framework and concerns over grid reliability and energy planning uncertainty.

Why has Newsom vetoed the Bill to Codify Load Flexibility?

Governor Gavin Newsom’s veto blocks legislation that would have required the California Energy Commission to incorporate load flexibility into the state’s energy planning and policy framework, a move that has stirred debate across the clean energy sector.

✅ Argues the bill conflicts with California’s existing Resource Adequacy system

✅ Draws backlash from clean energy and grid modernization advocates

✅ Exposes ongoing tension over how to manage renewable integration and demand response

California Governor Gavin Newsom has vetoed Assembly Bill 44, which would have required the California Energy Commission to evaluate and incorporate load management mechanisms into the state’s energy planning process. The move drew criticism from clean energy advocates who say it undermines efforts to strengthen grid reliability and reduce costs.

The bill directed the commission to adopt “upfront technical requirements and load modification protocols” that would allow load-serving entities to adjust their electrical demand forecasts. Proponents viewed this as a way to modernize California’s grid management, and to explore a revamp of electricity rates to help clean the grid, making it more responsive to demand fluctuations and renewable energy variability.

In his veto statement, Newsom said the bill was incompatible with existing energy planning frameworks, even as a looming electricity shortage remains a concern. “While I support expanding electric load flexibility, this bill does not align with the California Public Utility Commission’s Resource Adequacy framework,” he said. “As a result, the requirements of this bill would not improve electric grid reliability planning and could create uncertainty around energy resource planning and procurement processes.”

Newsom’s decision comes shortly after he signed a broad package of energy legislation that set the stage for a regional Western electricity market and extended the state’s cap-and-trade program. However, that legislative package did not include continued funding for several key grid reliability programs — including what advocates have called the world’s largest virtual power plant, a distributed network of connected devices that can balance electricity demand in real time.

Clean energy supporters saw AB 44 as a crucial step toward integrating these distributed energy resources into long-term grid planning. “With Assembly Bill 44 being vetoed, the state has missed a huge opportunity to advance common-sense policy that would have lowered costs, strengthened the grid, and unlocked the full potential of advanced energy,” said Edson Perez, California lead at Advanced Energy United.

Perez added that the setback increases pressure on lawmakers to take stronger action in the next legislative session. “The pressure is on next session to ensure that California is using all tools in its policy toolbox to build critically needed infrastructure, strengthen the grid, and bring costs down,” he said.

California’s growing use of demand response programs and virtual power plants has been central to its strategy for managing grid stress during heat waves and wildfire seasons. These systems allow utilities and customers to temporarily reduce or shift energy use, helping to prevent blackouts and reduce the need for fossil-fuel peaker plants during peak demand.

A recent report by the Brattle Group found that California’s taxpayer-funded virtual power plant could save ratepayers $206 million between 2025 and 2028 while reducing reliance on gas generation. The study, commissioned by Sunrun and Tesla Energy, highlighted the potential for flexible load management to improve both grid reliability and reduce costs, even as regulators weigh whether the state needs more power plants to ensure reliability.

Despite these findings, Newsom’s veto signals continued tension between state policymakers and clean energy advocates over how best to modernize California’s power grid. While the governor has prioritized large-scale renewable development and regional market integration, critics argue that California’s climate policy choices risk exacerbating reliability challenges and that failing to codify load flexibility could slow progress toward a more adaptive, resilient, and affordable clean energy future.

Related Articles

• USA Electricity News

Community Solar for Low-Income Homes expands energy equity by delivering renewable energy access, predictable bill savings, and tax credit benefits to renters and energy-insecure households, accelerating distributed generation and storage adoption nationwide.

Key Points

A program model enabling renters and LMI households to subscribe to off-site solar and save on utility bills.

✅ Earn bill credits from shared solar generation.

✅ Expands access for renters and LMI subscribers.

✅ Often paired with storage and IRA tax credit adders.

On a square-foot basis, the issue of inequality is made worse by higher costs for energy usage in the nation. Efforts like community solar programs such as Maryland community solar are underway to boost low-income participation in the cost benefits of renewable energy.

The Energy Information Administration (EIA) shows that households that are considered energy insecure, or those that have the inability to adequately meet basic household energy costs, are paying more for electricity than their wealthier counterparts. 

On average in the United States in 2020, households were billed about $1.04 per square foot for all energy sources. For homes that did not report energy insecurity, that average was $0.98 per square foot, while homes with energy insecurity issues paid an average of $1.24 per square foot for energy. This means that U.S. residents that need the most support on their energy bills are stuck with costs 27% higher than their neighbors on square-foot-basis.

EIA said energy-insecure households have reduced or forgone basic necessities to pay energy bills, kept their houses at unsafe temperatures because of energy cost concerns, or been unable to repair heating or cooling equipment because of cost.

In 2020, households with income less than $10,000 a year were billed an average of $1.31 per square foot for energy, while households making $100,000 or more were billed an average of $0.96 per square foot, said EIA. Renters paid considerably more ($1.28 per square foot) than owners ($0.98 per square foot). There were also considerable differences between regions, with New England solar growth sparking grid upgrade debates, ethnic groups and races, and insulation levels, as seen below.

The energy transition toward renewables like solar has offered price stability, amid record solar and storage growth nationwide, but thus far energy-insecure communities have relatively been left behind. A recent Berkeley Lab report, Residential Solar-Adopter Income and Demographic Trends, indicates that even though the rate of solar adoption among low-income residents is increasing (from 5% in 2010 to 11% in 2021), that segment of energy consumers remains under-represented among solar adopters, relative to its share of the population.

Community solar efforts

As such, the United States is targeting communities most impacted by energy costs that have not benefitted from the transition, highlighting “Energy Communities” that are eligible for an additional 10% tax credit through funds made possible by the Inflation Reduction Act.

Additionally, a push for community solar development is taking place nationwide to extend access to affordable solar energy to renters and other residents that aren’t able to leverage finances to invest in predictable, low-cost residential solar systems. The Biden Administration set a goal this year to sign up 5 million community solar households, achieving $1 billion in bill savings by 2025. The community solar model only represents about 8% of the total distributed solar capacity in the nation. This target would entail a jump from 3 GW installed capacity to 20 GW by the target year. The Department of Energy estimates community solar subscribers save an average of 20% on their bills.

California this year passed AB 2316, the Community Renewable Energy Act takes aim at four acute problems in the state’s power market: reliability amid rising outage risks, rates, climate and equity. The law creates a community renewable energy program, including community solar-plus-storage, supported by cheaper batteries, to overcome access barriers for nearly half of Californians who rent or have low incomes. Community solar typically involves customers subscribing to an off-site solar facility, receiving a utility bill credit for the power it generates.

“Community renewable energy is a proven powerful tool to help close California’s clean energy gap, bringing much needed relief to millions struggling with high housing costs and utility debt,” said Alexis Sutterman, energy equity program manager at the California Environmental Justice Alliance.

The program has energy equity baked into its structure, working to make sure Californians of all income levels participate in the benefits of the energy transition. Not only does it open solar access to renters, the law ensures that at least 51% of subscribers are low-income customers, which is expected to make projects eligible for a 10% tax credit adder under the IRA.

“The money’s on the table now,” said Jeff Cramer, president and chief executive of the Coalition for Community Solar Access. “While there are groups pushing for solar access for all, and states with strong legislation, there are other pockets of interest in surprising places in the United States. For example, Louisiana has no policy for community solar or support for low-income residents going solar but the city of New Orleans has its own utility commission with a community solar program. In Nebraska, forward-looking co-operatives have created community solar projects.

Community solar markets are active in 22 states, with more expected to come online in the future as states pursue 100% clean energy targets across the country. However, the market is expected to require strong community outreach efforts to foster trust and gain subscribers.

“There is a distrust of community solar initially in LMI communities as many have been burned before by retail energy false promises,” said Eric LaMora, executive director, community solar, Nautilus Solar on a panel at the Solar Energy Industries Association Finance, Tax, and Buyers seminar. “People are suspicious but there really are no hooks with community solar.”

LMI residents are leery to provide tax records or much documents at all in order to sign up for community solar, LaMora said. “We were surprised to see less of a default rate with LMI residents. We attribute this to the fact that they see significant savings on their electric bill, making it easier to pay each month,” he said.

Related News

• Electricity Forum News

• Renewable Energy News

Trump Offshore Wind Pledge signals a push for deregulation over renewable energy, challenging climate policy, green jobs, and coastal development while citing marine ecosystems, navigation, and energy independence amid state-federal permitting and legal hurdles.

Key Points

Trump's vow to cancel offshore wind projects favors deregulation and fossil fuels, impacting climate policy and jobs.

✅ Day-one plan to scrap offshore wind leases and permits

✅ Risks to renewable targets, grid mix, and coastal supply chains

✅ Likely court fights and state-federal regulatory conflicts

During his tenure as President of the United States, Donald Trump made numerous promises and policy proposals, many of which sparked controversy and debate. One such pledge was his vow to scrap offshore wind projects on "day one" of his presidency. This bold statement, while appealing to certain interests, raised concerns about its potential impact on U.S. offshore wind growth and environmental conservation efforts.

Trump's opposition to offshore wind projects stemmed from various factors, including his skepticism towards renewable energy, even as forecasts point to a $1 trillion offshore wind market in coming years, concerns about aesthetics and property values, and his focus on promoting traditional energy sources like coal and oil. Throughout his presidency, Trump prioritized deregulation and sought to roll back environmental policies introduced by previous administrations, arguing that they stifled economic growth and hindered American energy independence.

The prospect of scrapping offshore wind projects drew mixed reactions from different stakeholders. Supporters of Trump's proposal pointed to potential benefits such as preserving scenic coastal landscapes, protecting marine ecosystems, and addressing concerns about navigational safety and national security. Critics, however, raised valid concerns about the implications of such a decision on the renewable energy sector, including progress toward getting 1 GW on the grid nationwide, climate change mitigation efforts, and job creation in the burgeoning green economy.

Offshore wind energy has emerged as a promising source of clean, renewable power with the potential to reduce greenhouse gas emissions and diversify the energy mix. Countries like Denmark, the United Kingdom, and Germany have made significant investments in offshore wind in Europe, demonstrating its viability as a sustainable energy solution. In the United States, offshore wind projects have gained traction in states like Massachusetts, New York, and New Jersey, where coastal conditions are conducive to wind energy generation.

Trump's pledge to scrap offshore wind projects on "day one" of his presidency raised questions about the feasibility and legality of such a move. While the president has authority over certain aspects of energy policy and regulatory oversight, the development of offshore wind projects often involves multiple stakeholders, including state governments, local communities, private developers, and federal agencies, and actions such as Interior's move on Vineyard Wind illustrate federal leverage in permitting. Any attempt to halt or reverse ongoing projects would likely face legal challenges and regulatory hurdles, potentially delaying or derailing implementation.

Moreover, Trump's stance on offshore wind projects reflected broader debates about the future of energy policy, environmental protection, and economic development. While some argued for prioritizing fossil fuel extraction and traditional energy infrastructure, others advocated for a transition towards clean, renewable energy sources, drawing on lessons from the U.K. about wind deployment, to mitigate climate change and promote sustainable development. The Biden administration, which succeeded the Trump presidency, has signaled a shift towards a more climate-conscious agenda, including support for renewable energy initiatives and commitments to rejoin international agreements like the Paris Climate Accord.

In hindsight, Trump's pledge to scrap offshore wind projects on "day one" of his presidency underscores the complexities of energy policy and the importance of balancing competing interests and priorities. While concerns about aesthetics, property values, and environmental impact are valid, addressing the urgent challenge of climate change requires bold action and innovation in the energy sector. Offshore wind energy presents an opportunity, as seen in the country's biggest offshore wind farm approved in New York, to harness the power of nature in a way that is both environmentally responsible and economically beneficial. As the United States navigates its energy future, finding common ground and forging partnerships will be essential to ensure a sustainable and prosperous tomorrow.

Related News

• Electricity Forum News

• Renewable Energy News

Great Northern Transmission Line delivers 250 MW of carbon-free hydropower from Manitoba Hydro, strengthening Midwest grid reliability, enabling wind storage balancing, and advancing Minnesota Power's EnergyForward strategy for cleaner, renewable energy across the region.

Key Points

A 500 kV cross-border line delivering 250 MW of carbon-free hydropower, strengthening reliability and enabling renewables.

✅ 500 kV, 224-mile line from Manitoba to Minnesota

✅ Delivers 250 MW hydropower via ALLETE-Minnesota Power

✅ Enables wind storage and grid balancing with Manitoba Hydro

Minnesota Power, a utility division of ALLETE Inc. (NYSE:ALE), has energized its Great Northern Transmission Line, bringing online an innovative delivery and storage system for renewable energy that spans two states and one Canadian province, similar to the Maritime Link project in Atlantic Canada.

The 500 kV line is now delivering 250 megawatts of carbon-free hydropower from Manitoba, Canada, to Minnesota Power customers.

Minnesota Power completed the Great Northern Transmission Line (GNTL) in February 2020, ahead of schedule and under budget. The 224-mile line runs from the Canadian border in Roseau County to a substation near Grand Rapids, Minnesota. It consists of 800 tower structures which were fabricated in the United States and used 10,000 tons of North American steel. About 2,200 miles of wire were required to install the line's conductors. The GNTL also is contributing significant property tax revenue to local communities along the route.

"This is such an incredible achievement for Minnesota Power, ALLETE, and our region, and is the culmination of a decade-long vision brought to life by our talented and dedicated employees," said ALLETE President and CEO Bethany Owen. "The GNTL will help Minnesota Power to provide our customers with 50 percent renewable energy less than a year from now. As part of our EnergyForward strategy, it also strengthens the grid across the Midwest and in Canada, enhancing reliability for all of our customers."

With the GNTL energized and connected to Manitoba Hydro's recently completed Manitoba-Minnesota Transmission Project at the border, the companies now have a unique "wind storage" mechanism that quickly balances energy supply and demand in Minnesota and Manitoba, and enables a larger role for renewables in the North American energy grid.

The GNTL and its delivery of carbon-free hydropower are important components of Minnesota Power's EnergyForward strategy to transition away from coal and add renewable power sources while maintaining reliable and affordable service for customers, echoing interties like the Maritime Link that facilitate regional power flows. It also is part of a broader ALLETE strategy to advance and invest in critical regional transmission and distribution infrastructure, such as the TransWest Express transmission project, to ensure grid integrity and enable cleaner energy to reduce carbon emissions.

"The seed for this renewable energy initiative was planted in 2008 when Minnesota Power proposed purchasing 250 megawatts of hydropower from Manitoba Hydro. Beyond the transmission line, it also included a creative asset swap to move wind power from North Dakota to Minnesota, innovative power purchase agreements, and a remarkable advocacy process to find an acceptable route for the GNTL," said ALLETE Executive Chairman Al Hodnik. "It marries wind and water in a unique connection that will help transform the energy landscape of North America and reduce carbon emissions related to the existential threat of climate change."

Minnesota Power and Manitoba Hydro, a provincial Crown Corporation, coordinated on the project from the beginning, navigating National Energy Board reviews along the way. It is based on the companies' shared values of integrity, environmental stewardship and community engagement.

"The completion of Minnesota Power's Great Northern Transmission Line and our Manitoba-Minnesota Transmission Project is a testament to the creativity, perseverance, cooperation and skills of hundreds of people over so many years on both sides of the border," said Jay Grewal, president and CEO of Manitoba Hydro. "Perhaps even more importantly, it is a testament to the wonderful, longstanding relationship between our two companies and two countries. It shows just how much we can accomplish when we all work together toward a common goal."

Minnesota Power engaged federal, state and local agencies; the sovereign Red Lake Nation and other tribes, reflecting First Nations involvement in major transmission planning; and landowners along the proposed routes beginning in 2012. Through 75 voluntary meetings and other outreach forums, a preferred route was selected with strong support from stakeholders that was approved by the Minnesota Public Utilities Commission in April 2016.

A four-year state and federal regulatory process culminated in late 2016 when the federal Department of Energy approved a Presidential Permit for the GNTL, similar to the New England Clean Power Link process, needed because of the international border crossing. Construction of the line began in early 2017.

"A robust stakeholder process is essential to the success of any project, but especially when building a project of this scope," Owen said. "We appreciated the early engagement and support from stakeholders, local communities and tribes, agencies and regulators through the many approval milestones to the completion of the GNTL."

Related News

• Electricity Forum News

• Grid Technologies News

Eastern U.S. Heatwave Electricity Demand surges to record peak load, straining the power grid, lifting wholesale prices, and prompting demand response, conservation measures, and load shedding to protect grid reliability during extreme temperatures.

Key Points

It is the record peak load from extreme heat, straining grids, lifting wholesale prices, and prompting demand response.

✅ Peak electricity use stresses regional power grid.

✅ Prices surge; conservation and demand response urged.

✅ Utilities monitor load, avoid outages via load shedding.

As temperatures soar to unprecedented highs across the Eastern United States, a blistering heatwave has triggered record-breaking electricity demand. This article delves into the causes behind the surge in energy consumption, its impact on the power grid, and measures taken to manage the strain during this extraordinary weather event.

Intensifying Heatwave Conditions

The Eastern U.S. is currently experiencing one of its hottest summers on record, with temperatures climbing well above seasonal norms. This prolonged heatwave has prompted millions of residents to rely heavily on air conditioning and cooling systems to escape the sweltering heat, with electricity struggles worsening in several communities, driving up electricity usage to peak levels.

Strain on Power Grid Infrastructure

The surge in electricity demand during the heatwave has placed significant strain on the region's power grid infrastructure, with supply-chain constraints complicating maintenance and equipment availability during peak periods.

Record-breaking Energy Consumption

The combination of high temperatures and increased cooling demands has led to record-breaking energy consumption levels across the Eastern U.S. States like New York, Pennsylvania, and Maryland have reported peak electricity demand exceeding previous summer highs, with blackout risks drawing heightened attention from operators, highlighting the extraordinary nature of this heatwave event.

Impact on Energy Costs and Supply

The spike in electricity demand during the heatwave has also affected energy costs and supply dynamics. Wholesale electricity prices have surged in response to heightened demand, contributing to sky-high energy bills for many households, reflecting the market's response to supply constraints and increased operational costs for power generators and distributors.

Management Strategies and Response

Utility companies and grid operators have implemented various strategies to manage electricity demand and maintain grid reliability during the heatwave. These include voluntary conservation requests, load-shedding measures, and real-time monitoring of grid conditions to prevent power outages while avoiding potential blackouts or disruptions.

Community Outreach and Public Awareness

Amidst the heatwave, community outreach efforts play a crucial role in raising public awareness about energy conservation and safety measures. Residents are encouraged to conserve energy during peak hours, adjust thermostat settings, and utilize energy-efficient appliances to alleviate strain on the power grid and reduce overall energy costs.

Climate Change and Resilience

The intensity and frequency of heatwaves are exacerbated by climate change, underscoring the importance of building resilience in energy infrastructure and adopting sustainable practices. Investing in renewable energy sources, improving energy efficiency and demand response programs that can reduce peak demand, and implementing climate adaptation strategies are essential steps towards mitigating the impacts of extreme weather events like heatwaves.

Looking Ahead

As the Eastern U.S. navigates through this heatwave, stakeholders are focused on implementing lessons learned from California's grid response to enhance preparedness and resilience for future climate-related challenges. Collaborative efforts between government agencies, utility providers, and communities will be crucial in developing comprehensive strategies to manage energy demand, promote sustainability, and safeguard public health and well-being during extreme weather events.

Conclusion

The current heatwave in the Eastern United States has underscored the critical importance of reliable and resilient energy infrastructure in meeting the challenges posed by extreme weather conditions. By prioritizing energy efficiency, adopting sustainable energy practices, and fostering community resilience, stakeholders can work together to mitigate the impacts of heatwaves and ensure a sustainable energy future for generations to come.

Related News

• Electricity Forum News

• Energy Policy News

India Coal Supply Rationing redirects shipments from high-inventory power plants to stations facing shortages as electricity demand surges, inventories fall, and outages persist; Coal India, NTPC imports, and smaller mines bolster domestic supply.

Key Points

A temporary policy redirecting coal from high-stock plants to shortage-hit plants amid rising demand

✅ Shipments halted 1 week to plants with >14 days coal stock

✅ Smaller mines asked to raise output; NTPC to import 270,000 tons

✅ Outages at Adani and Tata Mundra units pressure domestic supply

India will ration coal supplies to power plants with high inventories to direct more shipments to stations battling shortages, even as shortages ease in some regions, as surging demand outstrips production.

Supplies to plants with more than two weeks’ coal inventory will be halted for a week, a team headed by federal Coal Secretary Alok Kumar decided on Saturday, the Power Ministry said in a statement. The government has also requested smaller mines to raise output to supplement shipments from state miner Coal India Ltd., and is taking steps to get nuclear back on track to diversify the energy mix.

A jump in electricity consumption spurred by a reviving economy and an extended summer, after an earlier steep demand decline in India, is driving demand for coal, which helps produce about 70% of the nation’s electricity. The surge in demand complicates India’s clean-energy transition efforts amid solar supply headwinds that cloud near-term alternatives, and may bolster arguments favoring the country’s dependence on coal to fuel economic growth.

“There’s no doubt India will continue to need coal for stable power for years,” said Rupesh Sankhe, vice president at Elara Capital India Pvt. in Mumbai. “Plants that meet environmental standards and are able to produce power efficiently will see utilization rising, but I doubt we’re going to have many new coal plants.”  

Coal stockpiles at the country’s power plants had fallen to 14.7 million tons as of Aug. 24, tumbling 62% from a year earlier, according to the latest data from the Central Electricity Authority. More than 88 gigawatts of generation plants, about half the capacity monitored by the power ministry, had inventories of six days or less as of that date, the data show. Power demand jumped 10.5% in July from a year earlier, even as global electricity use dipped 15% during the pandemic, according to the government.
Outages at some large plants that run on imported coal have increased the burden on those that burn domestic supplies, aiding shortfalls.

Adani Power Ltd. had almost 2 gigawatts of capacity in outage at its Mundra plant in Gujarat at the start of the week, while Tata Power Co. Ltd. had shut 80% of its 4-gigawatt plant in the same town for maintenance, power ministry data show.

NTPC Ltd., the largest power generator, will import the 270,000 tons of coal it left out from contracts placed earlier to mitigate the fuel shortage, reflecting higher imported coal volumes this fiscal, the power ministry said in a separate statement.

Related News

• Electricity Forum News

• Power Generation News