California's Looming Green New Car Wreck


gavin newsom

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California Gas Car Ban 2035 signals a shift to electric vehicles, raising grid reliability concerns, charging demand, and renewable energy challenges across solar, wind, and storage, amid rolling blackouts and carbon-free power mandates.

 

Key Points

An order ending new gasoline car sales by 2035 in California, accelerating EV adoption and pressuring the power grid.

✅ 25% EV fleet could add 232.5 GWh/day charging demand by 2040

✅ Solar and wind intermittency strains nighttime home charging

✅ Grid upgrades, storage, and load management become critical

 

On September 23, California Gov. Gavin Newsom issued an executive order that will ban the sale of gasoline-powered cars in the Golden State by 2035. Ignoring the hard lessons of this past summer, when California’s solar- and wind-reliant electric grid underwent rolling blackouts, Newsom now adds a huge new burden to the grid in the form of electric vehicle charging, underscoring the need for a much bigger grid to meet demand. If California officials follow through and enforce Newsom’s order, the result will be a green new car version of a train wreck.

In parallel, the state is moving on fleet transitions, allowing electric school buses only from 2035, which further adds to charging demand.

Let’s run some numbers. According to Statista, there are more than 15 million vehicles registered in California. Per the U.S. Department of Energy, there are only 256,000 electric vehicles registered in the state—just 1.7 percent of all vehicles, a share that will challenge state power grids as adoption grows.

Using the Tesla Model3 mid-range model as a baseline for an electric car, you’ll need to use about 62 kilowatt-hours (KWh) of power to charge a standard range Model 3 battery to full capacity. It will take about eight hours to fully charge it at home using the standard Tesla NEMA 14-50 charger, a routine that has prompted questions about whether EVs could crash the grid by households statewide.

Now, let’s assume that by 2040, five years after the mandate takes effect, also assuming no major increase in the number of total vehicles, California manages to increase the number of electric vehicles to 25 percent of the total vehicles in the state. If each vehicle needs an average of 62 kilowatt-hours for a full charge, then the total charging power required daily would be 3,750,000 x 62 KWh, which equals 232,500,000 KWh, or 232.5 gigawatt-hours (GWh) daily.

Utility-scale California solar electric generation according to the energy.ca.gov puts utility-scale solar generation at about 30,000 GWh per year currently. Divide that by 365 days and we get 80 GWh/day, predicted to double, to 160 GWh /day. Even if we add homeowner rooftop solar, and falling prices for solar and home batteries in the wake of blackouts, about half the utility-scale, at 40 GWh/day we come up to 200 GW/h per day, still 32 GWh short of the charging demand for a 25% electric car fleet in California. Even if rooftop solar doubles by 2040, we are at break-even, with 240GWh of production during the day.

Bottom-line, under the most optimistic best-case scenario, where solar operates at 100% of rated capacity (it seldom does), it would take every single bit of the 2040 utility-scale solar and rooftop capacity just to charge the cars during the day. That leaves nothing left for air conditioning, appliances, lighting, etc. It would all go to charging the cars, and that’s during the day when solar production peaks.

But there’s a much bigger problem. Even a grade-schooler can figure out that solar energy doesn’t work at night, when most electric vehicles will be charging at homes, even as some officials look to EVs for grid stability through vehicle-to-grid strategies. So, where does Newsom think all this extra electric power is going to come from?

The wind? Wind power lags even further behind solar power. According to energy.gov, as of 2019, California had installed just 5.9 gigawatts of wind power generating capacity. This is because you need large amounts of land for wind farms, and not every place is suitable for high-return wind power.

In 2040, to keep the lights on with 25 percent of all vehicles in California being electric, while maintaining the state mandate requiring all the state’s electricity to come from carbon-free resources by 2045, California would have to blanket the entire state with solar and wind farms. It’s an impossible scenario. And the problem of intermittent power and rolling blackouts would become much worse.

And it isn’t just me saying this. The U.S. Environmental Protection Agency (EPA) agrees. In a letter sent by EPA Administrator Andrew Wheeler to Gavin Newsom on September 28, Wheeler wrote:

“[It] begs the question of how you expect to run an electric car fleet that will come with significant increases in electricity demand, when you can’t even keep the lights on today.

“The truth is that if the state were driving 100 percent electric vehicles today, the state would be dealing with even worse power shortages than the ones that have already caused a series of otherwise preventable environmental and public health consequences.”


California’s green new car wreck looms large on the horizon. Worse, can you imagine electric car owners’ nightmares when California power companies shut off the power for safety reasons during fire season? Try evacuating in your electric car when it has a dead battery.

Gavin Newsom’s “no more gasoline cars sold by 2035” edict isn’t practical, sustainable, or sensible, much like the 2035 EV mandate in Canada has been criticized by some observers. But isn’t that what we’ve come to expect with any and all of these Green New Deal-lite schemes?

 

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Canada unveils plan for regulating offshore wind

Canada Offshore Wind Amendments streamline offshore energy regulators in Nova Scotia and Newfoundland and Labrador, enabling green hydrogen, submerged land licences, regional assessments, MPAs standards, while raising fisheries compensation, navigation, and Indigenous consultation considerations.

 

Key Points

Reforms assign offshore wind to joint regulators, enable seabed licensing, and address fisheries and Indigenous issues.

✅ Assigns wind oversight to Canada-NS and Canada-NL offshore regulators

✅ Introduces single submerged land licence and regional assessments

✅ Addresses fisheries, navigation, MPAs, and Indigenous consultation

 

Canada's offshore accords with Nova Scotia and Newfoundland and Labrador are being updated to promote development of offshore wind farms, but it's not clear yet whether any compensation will be paid to fishermen displaced by wind farms.

Amendments introduced Tuesday in Ottawa by the federal government assign regulatory authority for wind power to jointly managed offshore boards — now renamed the Canada-Nova Scotia Offshore Energy Regulator and Canada-Newfoundland and Labrador Offshore Energy Regulator.

Previously the boards regulated only offshore oil and gas projects.

The industry association promoting offshore wind development, Marine Renewables Canada, called the changes a crucial step.

"The tabling of the accord act amendments marks the beginning of, really, a new industry, one that can play a significant role in our clean energy future," said  Lisen Bassett, a spokesperson for Marine Renewables Canada. 

Nova Scotia's lone member of the federal cabinet, Immigration Minister Sean Fraser, also talked up prospects at a news conference in Ottawa.


'We have lots of water'

"The potential that we have, particularly when it comes to offshore wind and hydrogen is extraordinary," said Fraser.

"There are real projects, like Vineyard Wind, with real investors talking about real jobs."

Sharing the stage with assembled Liberal MPs from Nova Scotia and Newfoundland and Labrador was Nova Scotia Environment Minister Tim Halman, representing a Progressive Conservative government in Halifax.

"If you've ever visited us or Newfoundland, you know we have lots of water, you know we have lots of wind, and we're gearing up to take advantage of those natural resources in a clean, sustainable way. We're paving the way for projects such as offshore wind, tidal energy in Nova Scotia, and green hydrogen production," said Halman.

Before a call for bids is issued, authorities will identify areas suitable for development, conservation or fishing.

The legislation does not outline compensation to fishermen excluded from offshore areas because of wind farm approvals.


Regional assessments

Federal officials said potential conflicts can be addressed in regional assessments underway in both provinces.

Minister of Natural Resources of Canada Jonathan Wilkinson said fisheries and navigation issues will have to be dealt with.

"Those are things that will have to be addressed in the context of each potential project. But the idea is obviously to ensure that those impacts are not significant," Wilkinson said.

Speaking after the event, Christine Bonnell-Eisnor, chair of what is still called the Canada Nova Scotia Offshore Petroleum Board, said what compensation — if any — will be paid to fishermen has yet to be determined.

"It is a question that we're asking as well. Governments are setting the policy and what terms and conditions would be associated with a sea bed licence. That is a question governments are working on and what compensation would look like for fishers."

Scott Tessier, who chairs  the Newfoundland Board, added "the experience has been the same next door in Nova Scotia, the petroleum sector and the fishing sector have an excellent history of cooperation and communication and I don't expect it look any different for offshore renewable energy projects."


Nova Scotia in a hurry to get going

The legislation says the offshore regulator would promote compensation schemes developed by industry and fishing groups linked to fishing gear.

Nova Scotia is in a hurry to get going.

The Houston government has set a target of issuing five gigawatts of licences for offshore wind by 2030, with leasing starting in 2025, reflecting momentum in the U.S. offshore wind market as well. It is intended largely for green hydrogen production. That's almost twice the province's peak electricity demand in winter, which is 2.2 gigawatts.

The amendments will streamline seabed approvals by creating a single "submerged land" licence, echoing B.C.'s streamlined process for clean energy projects, instead of the exploration, significant discovery and production licences used for petroleum development.

Federal and provincial ministers will issue calls for bids and approve licences, akin to BOEM lease requests seen in the U.S. market.

The amendments will ensure Marine Protected Area's  (MPAs) standards apply in all offshore areas governed by the regulations.


Marine protected areas

Wilkinson suggested, but declined, three times to explicitly state that offshore wind farms would be excluded from within Marine Protected Areas.

After this story was initially published on Tuesday, Natural Resources Canada sent CBC a statement indicating offshore wind farms may be permitted inside MPAs.

Spokesperson Barre Campbell noted that all MPAs established in Canada after April 25, 2019, will be subject to the Department of Fisheries and Oceans new standards that prohibit key industrial activities, including oil and gas exploration, development and production.

"Offshore renewable energy activities and infrastructure are not key industrial activities," Campbell said in a statement.

"Other activities may be prohibited, however, if they are not consistent with the conservation objectives that are established by the relevant department that has or that will establish a marine protected area."


Federal impact assessment process

The new federal impact assessment process will apply in offshore energy development, and recent legal rulings such as the Cornwall wind farm decision highlight how courts can influence project timelines.

For petroleum projects, future significant discovery licences will be limited to 25 years replacing the current indefinite term.

Existing significant discovery licences have been an ongoing exception and are not subject to the 25-year limit. Both offshore energy regulators will be given the authority to fulfil the Crown's duty to consult with Indigenous peoples

 

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Whooping cranes steer clear of wind turbines when selecting stopover sites

Whooping crane migration near wind turbines shows strong avoidance of stopover habitat within 5 km, reshaping Great Plains siting decisions, reducing collision risk, and altering routes across croplands, grasslands, and wetlands.

 

Key Points

It examines cranes avoiding stopovers within 5 km of turbines, reshaping habitat use and routing across the Great Plains.

✅ Cranes 20x likelier to rest >5 km from turbines.

✅ About 5% of high-quality stopover habitat is impacted.

✅ Findings guide wind farm siting across Great Plains wetlands.

 

As gatherings to observe whooping cranes join the ranks of online-only events this year, a new study offers insight into how the endangered bird is faring on a landscape increasingly dotted with wind turbines across regions. The paper, published this week in Ecological Applications, reports that whooping cranes migrating through the U.S. Great Plains avoid “rest stop” sites that are within 5 km of wind-energy infrastructure.

Avoidance of wind turbines can decrease collision mortality for birds, but can also make it more difficult and time-consuming for migrating flocks to find safe and suitable rest and refueling locations. The study’s insights into migratory behavior could improve future siting decisions as wind energy infrastructure continues to expand, despite pandemic-related investment risks for developers.

“In the past, federal agencies had thought of impacts related to wind energy primarily associated with collision risks,” said Aaron Pearse, the paper’s first author and a research wildlife biologist for the U.S. Geological Survey’s Northern Prairie Wildlife Research Center in Jamestown, N.D. “I think this research changes that paradigm to a greater focus on potential impacts to important migration habitats.”

Some policymakers have also rejected false health claims about wind turbines and cancer in public debate, underscoring the need for evidence-based decisions.

The study tracked whooping cranes migrating across the Great Plains, a region that encompasses a mosaic of croplands, grasslands and wetlands. The region has seen a rapid proliferation of wind energy infrastructure in recent years: in 2010, there were 2,215 wind towers within the whooping crane migration corridor that the study focused on; by 2016, when the study ended, there were 7,622 wind towers within the same area.

Pearse and his colleagues found that whooping cranes migrating across the study area in 2010 and 2016 were 20 times more likely to select “rest stop” locations at least 5 km away from wind turbines than those closer to turbines, a pattern with implications for developers as solar incentive changes reshape wind market dynamics according to industry analyses.

The authors estimated that 5% of high-quality stopover habitat in the study area was affected by presence of wind towers. Siting wind infrastructure outside of whooping cranes’ migration corridor would reduce the risk of further habitat loss not only for whooping cranes, but also for millions of other birds that use the same land for breeding, migration, and wintering habitat, and real-world siting controversies, such as an Alberta wind farm cancellation, illustrate how local factors shape outcomes for wildlife.

 

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Canada set to hit 5 GW milestone

Canada Solar Capacity Outlook 2022-2050 projects 500 MW new PV in 2022 and 35 GW by 2050, driven by renewables policy, grid parity, NREL analysis, IEA-PVPS data, and competitive utility-scale photovoltaic costs.

 

Key Points

An evidence-based forecast of Canadian PV additions to 35 GW by 2050, reflecting policy, costs, and grid parity trends.

✅ 500 MW PV expected in 2022; cumulative capacity near 5 GW

✅ NREL outlook sees 35 GW by 2050 on cost competitiveness

✅ Policy shifts, ITCs, coal retirements accelerate solar uptake

 

Canada is set to install 500 MW of new solar in 2022, bringing its total capacity to about 5 GW, according to data from Canmet Energy, even as the Netherlands outpaces Canada in solar power generation. The country is expected to hit 35 GW of total solar capacity by 2050.

Canada’s cumulative solar capacity is set to hit 5 GW by the end of this year, according to figures from the federal government’s Canmet Energy lab. The country is expected to add around 500 MW of new solar capacity, from 944 MW last year, according to the International Energy Agency Photovoltaic Power Systems Programme (IEA-PVPS), which recently published a report on PV applications in Canada, even as solar demand lags in Canada.

“If we look at the recent averages, Canada has installed around 500 MW annually. I expect in 2022 it will be at least 500 MW,” said Yves Poissant, research manager at Canmet Energy. “Last year it was 944 MW, mainly because of a 465 MW centralized PV power plant installed in Alberta, where the Prairie Provinces are expected to lead national renewable growth.”

The US National Renewable Energy Laboratory (NREL) studied renewables integration and concluded that Canada’s cumulative solar capacity will increase sevenfold to 35 GW by 2050, driven by cost competitiveness and that zero-emissions by 2035 is achievable according to complementary studies.

Canada now produces 80% of its electricity from power sources other than oil. Hydroelectricity leads the mix at 60%, followed by nuclear at 15%, wind at 7%, gas and coal at 7%, and PV at just 1%. While the government aims to increase the share of green electricity to 90% by 2030 and 100% by 2050, zero-emission electricity by 2035 is considered practical and profitable, yet it has not set any specific goals for PV. Each Canadian province and territory is left to determine its own targets.

“Without comprehensive pan-Canadian policy framework with annual capacity targets, PV installation in the coming years will likely continue to be highly variable across the provinces and territories, especially after Ontario scrapped a clean energy program, which scaled back growth projections. Further policies mechanisms are needed to allow PV to reach its full potential,” the IEA-PVPS said.

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Canada recently introduced investment tax credits for renewables to compete with the United States, but it is still far from being a solar powerhouse, with some experts calling it a solar laggard today. That said, the landscape has started to change in the past five years.

“Some laws have been put in place to retire coal plants by 2025. That led to new opportunities to install capacity,” said Poissant. “We expect the newly installed capacity will consist mostly of wind, but also solar.”

The cost of solar has become more competitive and the residential sector is now close to grid parity, according to Poissant. For utility-scale projects, old hydroelectric dams are still considerably cheaper than solar, but newly built installations are now more expensive than solar.

“Starting 2030, solar PV will be cost competitive compared to wind,” Poissant said.

 

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Enabling storage in Ontario's electricity system

OEB Energy Storage Integration advances DERs and battery storage through CDM guidelines, streamlined connection requirements, IESO-aligned billing, grid modernization incentives, and the Innovation Sandbox, providing regulatory clarity and consumer value across Ontario's electricity system.

 

Key Points

A suite of OEB initiatives enabling storage and DERs via modern rules, cost recovery, billing reforms, and pilots.

✅ Updated CDM guidelines recognize storage at all grid levels.

✅ Standardized connection rules for DERs effective Oct 1, 2022.

✅ Innovation Sandbox supports pilots and temporary regulatory relief.

 

The energy sector is in the midst of a significant transition, where energy storage is creating new opportunities to provide more cost-effective, reliable electricity service. The OEB recognizes it has a leadership role to play in providing certainty to the sector while delivering public value, and a responsibility to ensure that the wider impacts of any changes to the regulatory framework, including grid rule changes, are well understood. 

Accordingly, the OEB has led a host of initiatives to better enable the integration of storage resources, such as battery storage, where they provide value for consumers.

Energy storage integration – our journey 
We have supported the integration of energy storage by:

Incorporating energy storage in Conservation and Demand Management (CDM) Guidelines for electricity distributors. In December 2021, the OEB released updated CDM guidelines that, among other things, recognize storage – either behind-the-meter, at the distribution level or the transmission level – as a means of addressing specific system needs. They also provide options for distributor cost recovery, aligning with broader industrial electricity pricing discussions, where distributor CDM activities also earn revenues from the markets administered by the Independent Electricity System Operator (IESO).
 
Modernizing, standardizing and streamlining connection requirements, as well as procedures for storage and other DERs, to help address Ontario's emerging supply crunch while improving project timelines. This was done through amendments to the Distribution System Code that take effect October 1, 2022, as part of our ongoing DER Connections Review.
 
Facilitating the adoption of Distributed Energy Resources (DERs), which includes storage, to enhance value for consumers by considering lessons from BESS in New York efforts. In March 2021, we launched the Framework for Energy Innovation consultation to achieve that goal. A working group is reviewing issues related to DER adoption and integration. It is expected to deliver a report to the OEB by June 2022 with recommendations on how electricity distributors can assess the benefits and costs of DERs compared to traditional wires and poles, as well as incentives for distributors to adopt third-party DER solutions to meet system needs.
 
Examining the billing of energy storage facilities. A Generic Hearing on Uniform Transmission Rates is underway. In future phases, this proceeding is expected to examine the basis for billing energy storage facilities and thresholds for gross-load billing. Gross-load billing demand includes not just a customer’s net load, but typically any customer load served by behind-the-meter embedded generation/storage facilities larger than one megawatt (or two megawatts if the energy source is renewable).
 
Enabling electricity distributors to use storage to meet system needs. Through a Bulletin issued in August 2020, we gave assurance that behind-the-meter storage assets may be considered a distribution activity if the main purpose is to remediate comparatively poor reliability of service.
 
Offering regulatory guidance in support of technology integration, including for storage, through our OEB Innovation Sandbox, as utilities see benefits across pilot deployments. Launched in 2019, the Innovation Sandbox can also provide temporary relief from a regulatory requirement to enable pilot projects to proceed. In January 2022, we unveiled Innovation Sandbox 2.0, which improves clarity and transparency while providing opportunities for additional dialogue. 
Addressing the barriers to storage is a collective effort and we extend our thanks to the sector organizations that have participated with us as we advanced these initiatives. In that regard, we provided an update to the IESO on these initiatives for a report it submitted to the Ministry of Energy, which is also exploring a hydrogen economy to support decarbonization.

 

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Why a green recovery goes far deeper than wind energy

Scotland Green Recovery Strategy centers on renewable energy, onshore wind, energy efficiency, battery storage, hydrogen, and electric vehicles, alongside public transport and digital infrastructure, local manufacturing, and grid flexibility to decarbonize industry and communities.

 

Key Points

A plan to cut emissions by scaling renewables, efficiency, storage, and infrastructure for resilient, low-carbon growth.

✅ Prioritize energy efficiency retrofits in homes and workplaces

✅ Invest in battery storage, hydrogen, and EV charging networks

✅ Support local manufacturing and circular economy supply chains

 

THE “green recovery” joins the growing list of Covid-era political maxims, while green energy investment could drive recovery, suggesting a bright and environmentally sustainable post-pandemic future lies ahead.

The Prime Minister once again alluded to it recently when he expressed his ambition to see the UK become the “world leader in clean wind energy”. In his typically bombastic style, Boris Johnson declared that everything from our kettles to electric vehicles, with offshore wind energy central to that vision, will be powered by “breezes that blow around these islands” by the next decade.

These comments create a misleading impression about how we can achieve a green recovery, particularly as Covid-19 hit renewables and exposed systemic challenges. While wind turbines have a key role to play, they are just one part of a comprehensive solution requiring a far more in-depth focus on how and why we use energy. We must concentrate our efforts and resources on reducing our overall consumption and increasing energy capture.

This includes making significant energy efficiency improvements to the buildings where we live and work and grasping the lessons of lockdown, including proposals for a fossil fuel lockdown to accelerate climate action, to ensure we operate in a more effective and less environmentally-damaging fashion. Do we really want to return to a world where people commute daily half way across the country for work or fly to New York for a two-hour meeting?

Businesses will need to adapt to new ways of operating outwith the traditional nine-to-five working week to reduce congestion and pollution levels. To make this possible requires Government investment in critical areas such as public transport and digital infrastructure, alongside more pylons to strengthen the grid, across all parts of Scotland to decentralise the economy and enable more people to live and work outside the main cities.

A Government-supported green recovery must rest on making it financially viable for businesses to manufacture here to reduce our reliance on imported goods. This includes processing recycleable materials here rather than shipping them abroad. It also means using locally generated energy to support local jobs and industry. We miss a trick if Scotland simply becomes a power generator for the rest of the UK.

MOVING transport from fossil fuels to renewable fuels will require a step-change that also requires support across all levels. The increased use of electric vehicles and hydrogen fuel cells are all encouraging developments, but these will rely on investment in infrastructure throughout the country if we’re to achieve significant benefits to our environment and our economy.

This brings us to the role of onshore wind power; still the cheapest form of renewable energy, and a sector marked by wind growth despite Covid-19 around the world today. Repowering existing sites with newer and more efficient turbines will certainly increase capacity rapidly, but we must also invest into development projects that will further enhance the capacity and efficiency of existing equipment. This includes improving on the current practice of the National Grid paying operators to switch off wind turbines when excess electricity is produced and instead developing new and innovative means to capture this energy. Government-primed investment into battery storage could help ensure we achieve and further reduce our reliance on traditional, non-sustainable sources.

We need a level playing field so that all forms of energy are judged on their lifetime cost in terms of emissions as well as construction and decommissioning costs to ensure fiscal incentives are applied on a fairer basis.

Turning the maxim of a green recovery into reality will require more than extra wind turbines, and the UK's wind lessons underscore the importance of policy and scale. We need a significant investment and commitment from business and government to limit existing emissions and ensure we capture and use energy more efficiently.

Andy Drane is projects partner and head of renewables at law firm Davidson Chalmers Stewart.

 

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American wind power congratulates President-elect Biden on his victory.

American Wind Power Statement on Biden highlights collaboration on renewable energy policy, clean energy jobs, carbon-free power, climate action, and a modern grid to grow the economy while keeping electricity costs low.

 

Key Points

AWEA commits to work with Biden on renewable policy, clean energy jobs, and a carbon-free U.S. grid.

✅ AWEA cites over 120,000 U.S. wind jobs ready to scale

✅ Supports 100% carbon-free power target by mid-century

✅ Aims to keep electricity costs low with renewable policy

 

American wind power congratulates President-elect Biden on his victory. "We look forward to collaborating with his administration and Congress, after pledges to scrap offshore wind in recent years, as we work together to shape a cleaner and more prosperous energy future for America, where wind and solar surpass coal in generation across the country.

The President-elect and his team have laid out an ambitious, comprehensive approach to energy policy that recognizes renewable energy's ability to grow America's economy and create a cleaner environment, as market majority for clean energy becomes a realistic prospect, while keeping electricity costs low and combating the threat of climate change as wind power surges across many regions.

The U.S. wind sector and its growing workforce of over 120,000 Americans stand ready to help put that plan into action and support the Biden administration in delivering on the immense promise of renewable energy to add well-paying jobs to the U.S. economy, with quarter-million wind jobs forecast in coming years, and reach the President-elect's 100% target for a carbon-free America by the middle of this century, alongside a 100% clean electricity by 2035 goal that charts the near-term path." - Tom Kiernan, CEO of the American Wind Energy Association.

 

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