Electric vehicles can fight climate change, but they’re not a silver bullet: U of T study


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EV Adoption Limits highlight that electric vehicles alone cannot meet emissions targets; life cycle assessment, carbon budgets, clean grids, public transit, and battery materials constraints demand broader decarbonization strategies, city redesign, and active travel.

 

Key Points

EV Adoption Limits show EVs alone cannot hit climate targets; modal shift, clean grids, and travel demand are essential.

✅ 350M EVs by 2050 still miss 2 C goals without major mode shift

✅ Grid demand rises 41%, requiring clean power and smart charging

✅ Battery materials constraints need recycling, supply diversification

 

Today there are more than seven million electric vehicles (EVs) in operation around the world, compared with only about 20,000 a decade ago. It’s a massive change – but according to a group of researchers at the University of Toronto’s Faculty of Applied Science & Engineering, it won’t be nearly enough to address the global climate crisis. 

“A lot of people think that a large-scale shift to EVs will mostly solve our climate problems in the passenger vehicle sector,” says Alexandre Milovanoff, a PhD student and lead author of a new paper published in Nature Climate Change. 

“I think a better way to look at it is this: EVs are necessary, but on their own, they are not sufficient.” 

Around the world, many governments are already going all-in on EVs. In Norway, for example, where EVs already account for half of new vehicle sales, the government has said it plans to eliminate sales of new internal combustion vehicles by 2025. The Netherlands aims to follow suit by 2030, with France and Canada's EV goals aiming to follow by 2040. Just last week, California announced plans to ban sales of new internal combustion vehicles by 2035.

Milovanoff and his supervisors in the department of civil and mineral engineering – Assistant Professor Daniel Posen and Professor Heather MacLean – are experts in life cycle assessment, which involves modelling the impacts of technological changes across a range of environmental factors. 

They decided to run a detailed analysis of what a large-scale shift to EVs would mean in terms of emissions and related impacts. As a test market, they chose the United States, which is second only to China in terms of passenger vehicle sales. 

“We picked the U.S. because they have large, heavy vehicles, as well as high vehicle ownership per capita and high rate of travel per capita,” says Milovanoff. “There is also lots of high-quality data available, so we felt it would give us the clearest answers.” 

The team built computer models to estimate how many electric vehicles would be needed to keep the increase in global average temperatures to less than 2 C above pre-industrial levels by the year 2100, a target often cited by climate researchers. 

“We came up with a novel method to convert this target into a carbon budget for U.S. passenger vehicles, and then determined how many EVs would be needed to stay within that budget,” says Posen. “It turns out to be a lot.” 

Based on the scenarios modelled by the team, the U.S. would need to have about 350 million EVs on the road by 2050 in order to meet the target emissions reductions. That works out to about 90 per cent of the total vehicles estimated to be in operation at that time. 

“To put that in perspective, right now the total proportion of EVs on the road in the U.S. is about 0.3 per cent,” says Milovanoff. 

“It’s true that sales are growing fast, but even the most optimistic projections of an electric-car revolution suggest that by 2050, the U.S. fleet will only be at about 50 per cent EVs.” 

The team says that, in addition to the barriers of consumer preferences for EV deployment, there are technological barriers such as the strain that EVs would place on the country’s electricity infrastructure, though proper grid management can ease integration. 

According to the paper, a fleet of 350 million EVs would increase annual electricity demand by 1,730 terawatt hours, or about 41 per cent of current levels. This would require massive investment in infrastructure and new power plants, some of which would almost certainly run on fossil fuels in some regions. 

The shift could also impact what’s known as the demand curve – the way that demand for electricity rises and falls at different times of day – which would make managing the national electrical grid more complex, though vehicle-to-grid strategies could help smooth peaks. Finally, there are technical challenges stemming from the supply of critical materials for batteries, including lithium, cobalt and manganese. 

The team concludes that getting to 90 per cent EV ownership by 2050 is an unrealistic scenario. Instead, what they recommend is a mix of policies, rather than relying solely on a 2035 EV sales mandate as a singular lever, including many designed to shift people out of personal passenger vehicles in favour of other modes of transportation. 

These could include massive investment in public transit – subways, commuter trains, buses – as well as the redesign of cities to allow for more trips to be taken via active modes such as bicycles or on foot. They could also include strategies such as telecommuting, a shift already spotlighted by the COVID-19 pandemic. 

“EVs really do reduce emissions, which are linked to fewer asthma-related ER visits in local studies, but they don’t get us out of having to do the things we already know we need to do,” says MacLean. “We need to rethink our behaviours, the design of our cities, and even aspects of our culture. Everybody has to take responsibility for this.” 

The research received support from the Hatch Graduate Scholarship for Sustainable Energy Research and the Natural Sciences and Engineering Research Council of Canada.

 

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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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Major investments by Canada and Quebec in electric vehicle battery assembly

Lion Electric Battery Plant Quebec secures near $100M public investment for an automated battery-pack assembly in Saint-Jérôme, fueling EV manufacturing, R&D, local supply chains, and heavy-duty zero-emission vehicle competitiveness and jobs.

 

Key Points

Automated battery-pack plant in Saint-Jérôme boosting EV manufacturing and strengthening Quebec's supply chain.

✅ $100M joint federal-provincial investment announced

✅ 135 jobs in 2023; 150 more long-term positions

✅ R&D hub to enhance heavy-duty EV battery performance

 

Canadian Prime Minister of Canada, Justin Trudeau, and the Premier of Quebec, François Legault, have announced an equal investment totalling nearly $100 million to Lion Electric, as a B.C. battery plant announcement has done in another province, for the establishment of a highly automated battery-pack assembly plant in Saint–Jérôme, in the Laurentians. This project, valued at nearly $185 million, will create 135 jobs when construction of the plant is completed in 2023. It is also expected that 150 additional jobs will be created over the longer term.

For the announcement, Mr. Trudeau and Mr. Legault were accompanied by the Minister of Innovation, Science and Industry, François-Philippe Champagne, by Quebec's Minister of Economy and Innovation, Pierre Fitzgibbon, and by Marc Bédard, President and Founder of Lion Electric.

The battery packs assembled at the new plant will be used in Lion Electric vehicles. This strategic investment will allow the company to improve its cost structure, and better control the design and shape of its batteries, making it more competitive in the heavy-duty electric vehicle market, as EV assembly deals put Canada in the race. Ultimately, the company will be able to increase the volume of its vehicle production. Lion Electric will be the first Canadian manufacturer of medium and heavy-duty vehicles to have state-of-the-art, automated battery-pack manufacturing facilities.

The company will also establish a research and development innovation centre within its manufacturing plant, which will allow it to test and refine products for future use, including batteries for emergency vehicles such as ambulances. The company will test innovations from research and development, including energy storage capacity and battery performance. The results will make these products more competitive in the North American market, where a Niagara Region battery plant signals growing demand.

The company said it expects to employ 135 people at the plant when it is operational by 2023. It also plans to invest in a research and development facility that could create a number of spinoff jobs.

"When we talk about an economic recovery that's good for workers, for families and for the environment, this is exactly the kind of project we mean," Trudeau said at a news conference in Montreal.

Trudeau toured Lion Electric's factory in Saint-Jérôme, Que., last March, just before the pandemic. (Ryan Remiorz/The Canadian Press)
It was the prime minister's first trip to Montreal in more than a year. He said one of the reasons he decided to attend the announcement was to illustrate the importance of the green economy and how Canada can capitalize on the U.S. EV pivot for future job growth.

The project also aligns with the Legault government's desire to create a supply chain within Quebec that is able to feed the electric vehicle industry, where Canada-U.S. collaboration could accelerate progress.

At Monday's announcement, Economy Minister Pierre Fitzgibbon spoke at length about the province's deposits of lithium and nickel — key components in electric vehicle batteries — as well as its supply of low-emission hydroelectricity.

"If we play our cards right, we could become world leaders in this market of the future," Fitzgibbon said.

Currently, many of those strategic minerals found in Quebec are exported to Asia where they are turned into battery cells, and then imported back to Quebec by companies like Lion, said Mickaël Dollé, a chemistry professor at the Université de Montréal.

By opening a battery assembly plant in Quebec, Lion could help stimulate more cell-makers, such as the Northvolt project near Montreal, to set up shop in the province. Further localizing the supply chain, Dollé said, means better value and a greener product. 

But other countries have the same goal in mind, he said, and the window for the province to establish itself as an important player in the emerging electric vehicle battery industry is closing quickly, as major Ford Oakville deal commitments accelerate competition.

"The decision has to be taken now, or in the coming months, but if we wait too long we may miss our main goal which is to get our own supply chain in Canada," Dollé said.

What's in a name?
Monday's announcement was closely watched in Quebec for what it foretold about the political future as well as the economic one.

By coming to Montreal and touring a vaccination clinic before making the funding announcement, Trudeau fed speculation in the province that he is preparing to call an election soon.

Intrigue also surrounded the informal meeting Trudeau had with Legault on Monday. The Quebec premier and members of his government have repeatedly expressed frustration with Trudeau during the pandemic.

 

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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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How France aims to discourage buying of Chinese EVs

France EV Bonus Eligibility Rules prioritize lifecycle carbon footprint, manufacturing emissions, battery sourcing, and transport impacts, reshaping electric car incentives and excluding many China-made EVs while aiming for WTO-compliant, low-emission industrial policy.

 

Key Points

France's EV bonus rules score lifecycle emissions to favor low-carbon models and limit incentives for China-made EVs.

✅ Scores energy, assembly, transport, and battery criteria

✅ Likely excludes China-made EVs with coal-heavy production

✅ Aims to align incentives with WTO-compliant climate goals

 

France has published new eligibility rules for electric car incentives to exclude EVs made in China, even though carmakers in Europe do not have more affordable rival models on the French market.


WHY IS FRANCE REVISING ITS EV BONUS ELIGIBILITY RULES?
The French government currently offers buyers a cash incentive of between 5,000 and 7,000 euros in cash for eligible models to get more electric cars on the road, at a total cost of 1 billion euros ($1.07 billion) per year.

However, in the absence of cheap European-made EVs, a third of all incentives are going to consumers buying EVs made in China, a French finance ministry source said. The trend has helped spur a Chinese EV push into Europe and a growing competitive gap with domestic producers.

The scheme will be revamped from Dec. 15 to take into account the carbon emitted in a model's manufacturing process.

President Emmanuel Macron and government ministers have made little secret that they want to make sure French state cash is not benefiting Chinese carmakers.


WHAT DO THE NEW RULES DO?
Under the new rules, car models will be scored against government-set thresholds for the amount of energy used to make their materials, in their assembly and transport to market, as well as what type of battery the vehicle has.

Because Chinese industry generally relies heavily on coal-generated electricity, the criteria are likely to put the bonus out of Chinese carmakers' reach.

The government, which is to publish in December the names of models meeting the new standards, says that the criteria are compliant with WTO rules because exemptions are allowed for health and environmental reasons, and similar Canada EV sales regulations are advancing as well.


WILL IT DO ANYTHING?
With Chinese cars estimated to cost 20% less than European-made competitors, the bonus could make a difference for vehicles with a price tag of less than 25,000 euros, amid an accelerating global transition to EVs that is reshaping price expectations.

But French car buyers will have to wait because Stellantis' (STLAM.MI) Slovakia-made e-C3 city car and Renault's (RENA.PA) France-made R5 are not due to hit the market until 2024.

Nonetheless, many EVs made in China will remain competitive even without the cash incentive, reflecting projections that within a decade many drivers could be in EVs.

With a starting price of 30,000 euros, SAIC group's (600104.SS) MG4 will be less expensive than Renault's equivalent Megane compact car, which starts at 38,000 euros - or 33,000 euros with a 5,000-euro incentive.

Since its 46,000-euro starting price is just below the 47,000-euro price threshold for the bonus, Tesla's (TSLA.O) Y model - one of the best selling electric vehicles in France - could in theory also be impacted by the new rules for vehicles made in China.

S&P Global Mobility analyst Lorraine Morard said that even if most Chinese cars are ineligible for the bonus they would probably get 7-8% of France's electric car market next year, even as the EU's EV share continues to rise, instead of 10% otherwise.

 

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Will Electric Vehicles Crash The Grid?

EV Grid Readiness means utilities preparing the power grid for electric vehicles with smart charging, demand response, V2G, managed load, and renewable integration to maintain reliability, prevent outages, and optimize infrastructure investment.

 

Key Points

EV Grid Readiness is utilities' ability to support mass EV charging with smart load control, V2G, and grid upgrades.

✅ Managed charging shifts load off-peak to reduce stress and costs

✅ V2G enables EVs to supply power and balance renewables

✅ Utilities plan upgrades, rate design, and demand response

 

There's little doubt that the automobile industry is beginning the greatest transformation it has ever seen as the American EV boom gathers pace. The internal combustion engine, the heart of the automobile for over 100 years, is being phased out in favor of battery electric powered vehicles. 

Industry experts know that it's no longer a question of will electric vehicles take over, the only question remaining is how quickly will it happen. If electric vehicle adoption accelerates faster than many have predicted, can the power grid, and especially state power grids across the country, handle the additional load needed to "fuel" tens of millions of EVs?

There's been a lot of debate on this subject, with, not surprisingly, those opposed to EVs predicting doomsday scenarios including power outages, increased electricity rates, and frequent calls from utilities asking customers to stop charging their cars.

There have also been articles written that indicate the grid will be able to handle the increased power demand needed to fuel a fully electric transportation fleet. Some even explain how electric vehicles will actually help grid stability overall, not cause problems.

So we decided to go directly to the source to get answers. We reached out to two industry professionals that aren't just armchair experts. These are two of the many people in the country tasked with the assignment of making sure we don't have problems as more and more electric vehicles are added to the national fleet. 

"Let's be clear. No one is forcing anyone to stop charging their EV." - Eric Cahill, speaking about the recent request by a California utility to restrict unnecessary EV charging during peak demand hours when possible

Both Eric Cahill, who is the Strategic Business Planner for the Sacramento Municipal Utility District in California, and John Markowitz, the Senior Director and Head of eMobility for the New York Power Authority agreed to recorded interviews so we could ask them if the grid will be ready for millions of EVs.  

Both Cahill and Markowitz explained that, while there will be challenges, they are confident that their respective districts will be ready for the additional power demand that electric vehicles will require. It's also important to note that the states that they work in, California and New York, with California expected to need a much bigger grid to support the transition, have both banned the sale of combustion vehicles past 2035. 

That's important because those states have the most aggressive timelines to transition to an all-electric fleet, and internationally, whether the UK grid can cope is a parallel question, so if they can provide enough power to handle the increased demand, other states should be able to also. 

We spoke to both Cahill and Markowitz for about thirty minutes each, so the video is about an hour long. We've added chapters for those that want to skip around and watch select topics. 

We asked both guests to explain what they believe some of the biggest challenges are, including how energy storage and mobile chargers could help, if 2035 is too aggressive of a timeline to ban combustion vehicles, and a number of other EV charging and grid-related questions. 

Neither of our guests seemed to indicate that they were worried about the grid crashing, or that 2035 was too soon to ban combustion vehicles. In fact, they both indicated that, since they know this is coming, they have already begun the planning process, with proper management in place to ensure the lights stay on and there are no major electricity disruptions caused by people charging their cars. 

So check out the video and let us know your thoughts. This has been a hot topic of discussion for many years now. Now that we've heard from the people in charge of providing us the power to charge our EVs, can we finally put the concerns to rest now? As always, leave your comments below; we want to hear your opinions as well.

 

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Why the Texas grid causes the High Plains to turn off its wind turbines

Texas High Plains Wind Energy faces ERCOT transmission congestion, limiting turbines in the Panhandle from stabilizing the grid as gas prices surge, while battery storage and solar could enhance reliability and lower power bills statewide.

 

Key Points

A major Panhandle wind resource constrained by ERCOT transmission, impacting grid reliability and electricity rates.

✅ Over 11,000 turbines can power 9M homes in peak conditions

✅ Transmission congestion prevents flow to major load centers

✅ Storage and solar can bolster reliability and reduce bills

 

Texas’s High Plains region, which covers 41 counties in the Texas Panhandle and West Texas, is home to more than 11,000 wind turbines — the most in any area of the state.

The region could generate enough wind energy to power at least 9 million homes. Experts say the additional energy could help provide much-needed stability to the electric grid during high energy-demand summers like this one, and even lower the power bills of Texans in other parts of the state.

But a significant portion of the electricity produced in the High Plains stays there for a simple reason: It can’t be moved elsewhere. Despite the growing development of wind energy production in Texas, the state’s transmission network, reflecting broader grid integration challenges across the U.S., would need significant infrastructure upgrades to ship out the energy produced in the region.

“We’re at a moment when wind is at its peak production profile, but we see a lot of wind energy being curtailed or congested and not able to flow through to some of the higher-population areas,” said John Hensley, vice president for research and analytics at the American Clean Power Association. “Which is a loss for ratepayers and a loss for those energy consumers that now have to either face conserving energy or paying more for the energy they do use because they don’t have access to that lower-cost wind resource.”

And when the rest of the state is asked to conserve energy to help stabilize the grid, the High Plains has to turn off turbines to limit wind production it doesn’t need.

“Because there’s not enough transmission to move it where it’s needed, ERCOT has to throttle back the [wind] generators,” energy lawyer Michael Jewell said. “They actually tell the wind generators to stop generating electricity. It gets to the point where [wind farm operators] literally have to disengage the generators entirely and stop them from doing anything.”

Texans have already had a few energy scares this year amid scorching temperatures and high energy demand to keep homes cool. The Electric Reliability Council of Texas, which operates the state’s electrical grid, warned about drops in energy production twice last month and asked people across the state to lower their consumption to avoid an electricity emergency.

The energy supply issues have hit Texans’ wallets as well. Nearly half of Texas’ electricity is generated at power plants that run on the state’s most dominant energy source, natural gas, and its price has increased more than 200% since late February, causing elevated home utility bills.

Meanwhile, wind farms across the state account for nearly 21% of the state’s power generation. Combined with wind production near the Gulf of Mexico, Texas produced more than one-fourth of the nation’s wind-powered electric generation last year.

Wind energy is one of the lowest-priced energy sources because it is sold at fixed prices, turbines do not need fuel to run and the federal government provides subsidies. Texans who get their energy from wind farms in the High Plains region usually pay less for electricity than people in other areas of the state. But with the price of natural gas increasing from inflation, Jewell said areas where wind energy is not accessible have to depend on electricity that costs more.

“Other generation resources are more expensive than what [customers] would have gotten from the wind generators if they could move it,” Jewell said. “That is the definition of transmission congestion. Because you can’t move the cheaper electricity through the grid.”

A 2021 ERCOT report shows there have been increases in stability constraints for wind energy in recent years in both West and South Texas that have limited the long-distance transfer of power.

“The transmission constraints are such that energy can’t make it to the load centers. [High Plains wind power] might be able to make it to Lubbock, but it may not be able to make it to Dallas, Fort Worth, Houston or Austin,” Jewell said. “This is not an insignificant problem — it is costing Texans a lot of money.”

Some wind farms in the High Plains foresaw there would be a need for transmission. The Trent Wind Farm was one of the first in the region. Beginning operations in 2001, the wind farm is between Abilene and Sweetwater in West Texas and has about 100 wind turbines, which can supply power to 35,000 homes. Energy company American Electric Power built the site near a power transmission network and built a short transmission line, so the power generated there does go into the ERCOT system.

But Jewell said high energy demand and costs this summer show there’s a need to build additional transmission lines to move more wind energy produced in the High Plains to other areas of the state.

Jewell said the Public Utility Commission, which oversees the grid, is conducting tests to determine the economic benefits of adding transmission lines from the High Plains to the more than 52,000 miles of lines that already connect to the grid across the state. As of now, however, there is no official proposal to build new lines.

“It does take a lot of time to figure it out — you’re talking about a transmission line that’s going to be in service for 40 or 50 years, and it’s going to cost hundreds of millions of dollars,” Jewell said. “You want to be sure that the savings outweigh the costs, so it is a longer process. But we need more transmission in order to be able to move more energy. This state is growing by leaps and bounds.”

A report by the American Society of Civil Engineers released after the February 2021 winter storm stated that Texas has substantial and growing reliability and resilience problems with its electric system.

The report concluded that “the failures that caused overwhelming human and economic suffering during February will increase in frequency and duration due to legacy market design shortcomings, growing infrastructure interdependence, economic and population growth drivers, and aging equipment even if the frequency and severity of weather events remains unchanged.”

The report also stated that while transmission upgrades across the state have generally been made in a timely manner, it’s been challenging to add infrastructure where there has been rapid growth, like in the High Plains.

Despite some Texas lawmakers’ vocal opposition against wind and other forms of renewable energy, and policy shifts like a potential solar ITC extension can influence the wind market, the state has prime real estate for harnessing wind power because of its open plains, and farmers can put turbines on their land for financial relief.

This has led to a boom in wind farms, even with transmission issues, and nationwide renewable electricity surpassed coal in 2022 as deployment accelerated. Since 2010, wind energy generation in Texas has increased by 15%. This month, the Biden administration announced the Gulf of Mexico’s first offshore wind farms will be developed off the coasts of Texas and Louisiana and will produce enough energy to power around 3 million homes.

“Texas really does sort of stand head and shoulders above all other states when it comes to the actual amount of wind, solar and battery storage projects that are on the system,” Hensley said.

One of the issues often brought up with wind and solar farms is that they may not be able to produce as much energy as the state needs all of the time, though scientists are pursuing improvements to solar and wind to address variability. Earlier this month, when ERCOT asked consumers to conserve electricity, the agency listed low wind generation and cloud coverage in West Texas as factors contributing to a tight energy supply.

Hensley said this is where battery storage stations can help. According to the U.S. Energy Information Administration, utility-scale batteries tripled in capacity in 2021 and can now store up to 4.6 gigawatts of energy. Texas has been quickly developing storage projects, spurred by cheaper solar batteries, and in 2011, Texas had only 5 megawatts of battery storage capacity; by 2020, that had ballooned to 323.1 megawatts.

“Storage is the real game-changer because it can really help to mediate and control a lot of the intermittency issues that a lot of folks worry about when they think about wind and solar technology,” Hensley said. “So being able to capture a lot of that solar that comes right around noon to [1 p.m.] and move it to those evening periods when demand is at its highest, or even move strong wind resources from overnight to the early morning or afternoon hours.”

Storage technology can help, but Hensley said transmission is still the big factor to consider.

Solar is another resource that could help stabilize the grid. According to the Solar Energy Industries Association, Texas has about 13,947 megawatts of solar installed and more than 161,000 installations. That’s enough to power more than 1.6 million homes.

This month, the PUC formed a task force to develop a pilot program next year that would create a pathway for solar panels and batteries on small-scale systems, like homes and businesses, to add that energy to the grid, similar to a recent virtual power plant in Texas rollout. The program would make solar and batteries more accessible and affordable for customers, and it would pay customers to share their stored energy to the grid as well.

Hensley said Texas has the most clean-energy projects in the works that will likely continue to put the region above the rest when it comes to wind generation.

“So they’re already ahead, and it looks like they’re going to be even farther ahead six months or a year down the road,” he said.

 

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