TransAlta CEO transforms stodgy utility into 21st century player

By CanWest News Service


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In the nearly 13 years since taking over as president and chief executive of TransAlta Corp., Steve Snyder has not only made an impact on the company, but also on the city he now calls home.

In fact, he's made such an impression on people with his efforts, there isn't a bad word to be heard about the rangy redhead.

“I have a tremendous amount of respect for Steve. He's a visionary, and he's done a huge job on the homeless issue and I commend him for that,” said George Brookman, chief executive of West Canadian Industries Group and past- president and chairman of the Calgary Exhibition and Stampede.

“What I love about Steve is that he can talk to princes and paupers just the same. He talks to everyone so evenly and nicely and makes people feel great.”

Not that this should surprise anyone.

Before landing in Calgary in 1996, Snyder had been in charge of transforming Noma Industries - the Canadian company known for its lighting products - from being primarily focused on producing consumer products for the Canadian market to one with a North American focus on industrial products. Before that, the Queen's University engineer armed with an MBA from the University of Western Ontario had hung his hat at GE Canada for 14 years, toiling under the watchful eye of then-CEO Bill Blundell. There were many skeptics who greeted his arrival at TransAlta; what did someone coming from running a consumer-focused lighting company know about power generation?

Plenty, it turns out.

Since signing on at TransAlta, which marks its 100th birthday this year, Snyder has been instrumental in taking what was viewed as a stodgy utility to one that is leading the charge on what is set to be a step change in the world of power generation.

From moving into the U.S. through the purchase of the Centralia plant in Washington State, to being an early advocate of wind power and understanding the need to buy carbon offsets, Snyder has kept his focus firmly on the horizon, even though the market hasn't exactly rewarded his efforts. TransAlta's shares have had quite the round trip in the last decade - going from $21.13 in April 1999, rising as high as $37 but now trading in the $19 range.

These days, he is a passionate advocate for carbon capture and storage technology as being one of the key technological developments to lower carbon dioxide emissions, a key issue for Alberta oilsands producers.

Snyder chaired the joint federal and provincial task force looking into carbon capture and storage, which submitted its recommendations in February 2008. The Alberta government has since committed $2 billion to CCS initiatives in the province - moving ahead with funding the initiative despite the current economic slowdown. Even so, Snyder is the first to admit that CCS isn't the silver bullet many are hoping it to be. “It's part of the solution that will also include nuclear and other renewable options,” he said in his office, festooned with pictures of his family.

The issue, of course, is cost. Snyder points out that coal remains the fuel of choice for electricity generation because of its cost.

“We have moved from being a society where 15 years ago it was all about cheap electricity. Today the environmental concerns are moving the cost upwards,” he said.

But, Snyder points out, the capital requirements of CCS are still below what it would cost to build nuclear or large-scale renewable facilities and that's why he is a firm believer that this option needs to be pursued.

Asked about a move to shift coal-fired plants to natural gas, which has half the emissions of coal, Snyder quickly runs through the challenges.

“The issue comes back to cost and security of supply for natural gas, not to mention a time frame of between seven and eight years to break even. At $4 per thousand cubic feet, it works out to $50 per megawatt hour, but if the price rises to $10 per mcf, then you're looking at a cost of $120/MGW,” says Snyder.

The attractiveness of the CCS option, from his perspective, is that it has the potential to be cost-effectively applied on a global basis. Because power consumption goes up as GDP rises around the world, Synder says it is critical that the technology becomes accessible in the developing world as well as the developed world.

For its part, TransAlta is currently involved in what it calls Project Pioneer, where it is working on a chilled ammonia process to capture carbon dioxide from one of its Alberta-based plants.

The company is also waiting to see if it will be one of between three and five projects funded by the provincial government - although it did receive a portion of the $140 million recently doled out by the federal government for its Keephills plant outside Edmonton. The project will remove one megatonne per year of carbon dioxide.

If the elephant currently in the room is the environment, the one that just left was the failed proxy battle by a New York-based hedge fund Luminus LLC. Luminus bought shares in TransAlta when rumours were flying in 2007 that the company was going to be picked off by a private-equity fund.

Needless to say, that didn't happen, but the hedge fund was convinced TransAlta wasn't being managed as aggressively as it could have been and wanted to increase the debt on the balance sheet, buy back shares and jettison some assets.

In late 2007 Luminus embarked on a campaign that included a plan to add as much as $2 billion in debt to TransAlta's balance sheet, along with selling some assets. This was followed up with a letter sent to the board of directors in July 2008 saying it was prepared to offer $39 cash per share and move toward a ‘negotiated settlement.’ The so-called ‘offer’ was withdrawn in October with TransAlta successfully defying the investment-banking adage of ‘once in play, always in play.’

“He did a very good job stickhandling the Luminus situation, which was very awkward... he is a consensus builder and very good at resolving issues,'' said Michael Tims, chairman of investment counsel Peters & Co.

While Snyder isn't the kind of guy to gloat, there's no denying he's pleased that TransAlta's conservative approach has positioned the company to take advantage of opportunities - most likely in small-scale hydro or cogeneration - that are likely to arise in the current environment.

“Cash is king... we have always had that as a key objective and we have always made sure never to have a large amount of debt coming due,” he said.

One of the benefits from the Luminus episode, says Snyder, is that it put into play one of TransAlta's `stress test' scenarios in terms of the company's strategic plan and supporting assumptions.

“The stress test turned into the real world... we still think the model works and this is where we are today,” he said. It also forced TransAlta to do a better job at communicating.

“We have a better understanding of what to tell shareholders... we are giving them better information - and more succinctly - than we were two years ago,” he said. Inasmuch as the challenges with Luminus occupied a significant amount of time for the better part of 2008, it didn't mean Snyder dropped out of site in terms of his charitable endeavours in the community.

For Snyder, the notion of being active in one's community is not an option: no matter who you are, or how busy you are, you have an obligation to give back. And Snyder has done that in spades.

He says it started at GE Canada, which has a philosophy that all leaders should be engaged outside the corporation because it ``rounds people out.''

His journey to philanthropy began through the United Way in Toronto while working at GE, where he became involved in the industrial division of the campaign. He was also involved in the Council for Canadian Unity while in Toronto, an experience he calls an eye opener for the diversity of opinions, political stripes and skill sets that were gathered around the table, all working toward one goal: national unity.

The rest, as they say, is history. When he came to Calgary, Ruth Ramsden-Wood tapped him on the shoulder and in 2004, Snyder co-chaired the United Way Campaign, helping raise $37.8 million - up from $32.4 million in the prior year.

He has also served on the Stampede Board and currently chairs the Calgary Stampede Foundation, but Snyder arguably took on his biggest challenge in January 2007, when he agreed to chair the Calgary Committee to End Homelessness.

“He was able to bring together a very diverse group of business people from the Calgary business community and as a result of his great reputation and leadership skills we worked very well together as a diverse team and accomplished a lot in what was really a relatively short period of time. Steve's leadership capabilities... are a big part of why we made so much progress in such a short period of time,'' said Sam Kolias, chairman and chief executive of Boardwalk Equities REIT.

The committee, which tabled its report one year later, spawned the creation of the Alberta Secretariat for Action on Homelessness at the provincial level, which Snyder is now chairman.

Last November, Snyder was honoured by the Conference Board of Canada, on which he serves as a board member, as an Honorary Associate. This recognizes an individual “who has served Canada and their organization with distinction during an outstanding career.”

The sold-out awards dinner took place at the Hyatt Hotel, where attendees learned a bit more about Snyder through his remarks, and those of his children.

The audience discovered that the rangy redhead sporting a pair of fashion forward specs - who turns 60 on later this month but still doesn't look much past 45 - can be self-deprecating. “I hope I have added some value (to the Conference Board),” he says. The audience also discovered he is a big fan of the Swedish pop group, ABBA.

And with that, his one apparent shortcoming is revealed.

Still, all kidding aside, it's not often one finds a business leader in the community for whom there is not an ill word spoken. Snyder's ability to dive into the meat of contentious issues, his unfailing optimism and inability to say no when his time and advice are needed have indeed made a difference not just in Calgary, but across the country.

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We Energies refiles rate hike request driven by rising nuclear power costs

We Energies rate increase driven by nuclear energy costs at Point Beach, Wisconsin PSC filings, and rising utility rates, affecting electricity prices for residential, commercial, and industrial customers while supporting WEC carbon reduction goals.

 

Key Points

A 2021 utility rate hike to recover Point Beach nuclear costs, modestly raising Wisconsin electricity bills.

✅ Residential bills rise about $0.73 per month

✅ Driven by $55.82/MWh Point Beach contract price

✅ PSC review and consumer advocates assessing alternatives

 

Wisconsin's largest utility company is again asking regulators to raise rates to pay for the rising cost of nuclear energy.

We Energies says it needs to collect an additional $26.5 million next year, an increase of about 3.4%.

For residential customers, that would translate to about 73 cents more per month, or an increase of about 0.7%, while some nearby states face steeper winter rate hikes according to regulators. Commercial and industrial customers would see an increase of 1% to 1.5%, according to documents filed with the Public Service Commission.

If approved, it would be the second rate increase in as many years for about 1.1 million We Energies customers, who saw a roughly 0.7% increase in 2020 after four years of no change, while Manitoba Hydro rate increase has been scaled back for next year, highlighting regional contrasts.

We Energies' sister utility, Wisconsin Public Service Corp., has requested a 0.13% increase, which would add about 8 cents to the average monthly residential bill, which went up 1.6% this year.

We Energies said a rate increase is needed to cover the cost of electricity purchased from the Point Beach nuclear power plant, which according to filings with the Securities Exchange Commission will be $55.82 per megawatt-hour next year.

So far this year, the average wholesale price of electricity in the Midwestern market was a little more than $25.50 per megawatt-hour, and recent capacity market payouts on the largest U.S. grid have fallen sharply, reflecting broader market conditions.

Owned and operated by NextEra Energy Resources, the 1,200-megawatt Point Beach Nuclear Plant is Wisconsin's last operational reactor. We Energies sold the plant for $924 million in 2007 and entered into a contract to purchase its output for the next two decades.

Brendan Conway, a spokesman for WEC Energy Group, said customers have benefited from the sale of the plant, which will supply more than a third of We Energies' demand and is a key component in WEC's strategy to cut 80% of its carbon emissions by 2050, amid broader electrification trends nationwide.

"Without the Point Beach plant, carbon emissions in Wisconsin would be significantly higher," Conway said.

As part of negotiations on its last rate case, WEC agreed to work with consumer advocates and the PSC to review alternatives to the contracted price increases, which were structured to begin rising steeply in 2018.

Tom Content, executive director of the Citizens Utility Board, said the contract will be an issue for We Energies customers into the next decade

"It's a significant source (of energy) for the entire state," Content said. "But nuclear is not cheap."

WEC filed the rate requests Monday, one week after the withdrawing similar applications. Conway said the largely unchanged filings had "undergone additional review by senior management."

WEC last week raised its second quarter profit forecast to 67 to 69 cents per share, up from the previous range of 58 to 62 cents per share.

The company credited better than expected sales in April and May along with operational cost savings and higher authorized profit margin for American Transmission Company, of which WEC is the majority owner.

Wisconsin's other investor-owned utilities have reported lower than expected fuel costs for 2020 and 2021, even as emergency fuel stock programs in New England are expected to cost millions this year.

Alliant Energy has proposed using about $31 million in fuel savings to help freeze rates in 2021, aligning with its carbon-neutral electricity plans as it rolls out long-term strategy, while Xcel Energy is proposing to lower its rates by 0.8% next year and refund its customers about $9.7 million in fuel costs for this year.

Madison Gas and Electric is negotiating a two-year rate structure with consumer groups who are optimistic that fuel savings can help prevent or offset rate increases, though some utilities are exploring higher minimum charges for low-usage customers to recover fixed costs.

 

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Ontario hydro rates set to increase Nov. 1, Ontario Energy Board says

Ontario Electricity Rebate clarifies hydro rates as OEB aligns bills with inflation, shows true cost per kilowatt hour, and replaces Fair Hydro Plan; transparent on-bill credit offsets increases tied to nuclear refurbishment and supply costs.

 

Key Points

A line-item credit on Ontario hydro bills that offsets higher electricity costs and reflects OEB-set rates.

✅ Starts Nov. 1 with rates in line with inflation

✅ Shows true per-kWh cost plus separate rebate line

✅ Driven by nuclear refurbishment and supply costs

 

The Ontario Energy Board says electricity rate changes for households and small businesses will be going up starting next week.

The agency says rates are scheduled to increased by about $1.99 or nearly 2% for a typical residential customer who uses 700 kilowatt hours per month.

The provincial government said in March it would continue to subsidize hydro rates, through legislation to lower rates, and hold any increases to the rate of inflation.

The OEB says the new rates, which the board says are “in line” with inflation, will take effect Nov. 1 as changes for electricity consumers roll out and could be noticed on bills within a few weeks of that date.

Prices are increasing partly due to government legislation aimed at reflecting the actual cost of supply on bills, and partly due to the refurbishment of nuclear facilities, contributing to higher hydro bills for some consumers.

So, effective November 1, Ontario electricity bills will show the true cost of power, after a period of a fixed COVID-19 hydro rate, and will include the new Ontario Electricity Rebate.

Previously the electricity rebate was concealed within the price-per-kilowatt-hour line item on electricity statements, prompting Hydro One bill redesign discussions to improve clarity. This meant customers could not see how much the government rebate was reducing their monthly costs, and bills did not display the true cost of electricity used.

"People deserve facts and accountability, especially when it comes to hydro costs," said Energy Minister Rickford.

The new Ontario Electricity Rebate will appear as a transparent on-bill line item and will replace the former government's Fair Hydro Plan says a government news release. This change comes in response to the Auditor General's special report on the former government's Fair Hydro Plan which revealed that "the government created a needlessly complex accounting/financing structure for the electricity rate reduction in order to avoid showing a deficit or an increase in net debt."

"The Electricity Distributors Association commends the government's commitment to making Ontario's electricity bills more transparent," said Teresa Sarkesian, President of the Electricity Distributors Association. "As the part of our electricity system that is closest to customers, local hydro utilities appreciated the opportunity to work with the government on implementing this important initiative. We worked to ensure that customers who receive their electricity bill will have a clear understanding of the true cost of power and the amount of their on-bill rebate. Local hydro utilities are focused on making electricity more affordable, reducing red tape, and providing customers with a modern and reliable electricity system that works for them."

The average customer will see the electricity line on their bill rise, showing the real cost per kilowatt hour. The new Ontario Electricity Rebate will compensate for that rise, and will be displayed as a separate line item on hydro bills. The average residential bill will rise in line with the rate of inflation.

 

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Alberta Faces Challenges with Solar Energy Expansion

Alberta Solar Energy Expansion confronts high installation costs, grid integration and storage needs, and environmental impact, while incentives, infrastructure upgrades, and renewable targets aim to balance reliability, land use, and emissions reductions provincewide.

 

Key Points

Alberta Solar Energy Expansion is growth in solar tempered by costs, grid limits, environmental impact, and incentives.

✅ High capex and financing challenge utility-scale projects

✅ Grid integration needs storage, transmission, and flexibility

✅ Site selection must mitigate land and wildlife impacts

 

Alberta's push towards expanding solar power is encountering significant financial and environmental hurdles. The province's ambitious plans to boost solar power generation have been met with both enthusiasm and skepticism as stakeholders grapple with the complexities of integrating large-scale solar projects into the existing energy framework.

The Alberta government has been actively promoting solar energy as part of its strategy to diversify the energy mix in a province that is a powerhouse for both green energy and fossil fuels today and reduce greenhouse gas emissions. Recent developments have highlighted the potential of solar power to contribute to Alberta's clean energy goals. However, the path forward is fraught with challenges related to costs, environmental impact, and infrastructure needs.

One of the primary issues facing the solar energy sector in Alberta is the high cost of solar installations. Despite decreasing costs for solar technology in recent years, the upfront investment required for large-scale solar farms remains substantial, even as some facilities have been contracted at lower cost than natural gas in Alberta today. This financial barrier has led to concerns about the economic viability of solar projects and their ability to compete with other forms of energy, such as natural gas and oil, which have traditionally dominated Alberta's energy landscape.

Additionally, there are environmental concerns associated with the development of solar farms. While solar energy is considered a clean and renewable resource, the construction of large solar installations can have environmental implications. These include potential impacts on local wildlife habitats, land use changes, where approaches like agrivoltaics can co-locate farming and solar, and the ecological effects of large-scale land clearing. As solar projects expand, balancing the benefits of renewable energy with the need to protect natural ecosystems becomes increasingly important.

Another significant challenge is the integration of solar power into Alberta's existing energy grid. Solar energy production is variable and dependent on weather conditions, especially with Alberta's limited hydro capacity for flexibility, which can create difficulties in maintaining a stable and reliable energy supply. The need for infrastructure upgrades and energy storage solutions is crucial to address these challenges and ensure that solar power can be effectively utilized alongside other energy sources.

Despite these challenges, the Alberta government remains committed to advancing solar energy as a key component of its renewable energy strategy. Recent initiatives include financial incentives and support programs aimed at encouraging investment in solar projects and supporting a renewable energy surge that could power thousands of jobs across Alberta today. These measures are designed to help offset the high costs associated with solar installations and make the technology more accessible to businesses and homeowners alike.

Local communities and businesses are also playing a role in the growth of solar energy in Alberta. Many are exploring opportunities to invest in solar power as a means of reducing energy costs and supporting sustainability efforts and, increasingly, to sell renewable energy into the market as demand grows. These smaller-scale projects contribute to the overall expansion of solar energy and demonstrate the potential for widespread adoption across the province.

The Alberta government has also been working to address the environmental concerns associated with solar energy development. Efforts are underway to implement best practices for minimizing environmental impacts and ensuring that solar projects are developed in an environmentally responsible manner. This includes conducting environmental assessments and working with stakeholders to address potential issues before projects are approved and built.

In summary, while Alberta's solar energy initiatives hold promise for advancing the province's clean energy goals, they are also met with significant financial and environmental challenges. Addressing these issues will be crucial to the successful expansion of solar power in Alberta. The government's ongoing efforts to support solar projects through incentives and infrastructure improvements, coupled with responsible environmental practices, will play a key role in determining the future of solar energy in the province.

 

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Clean, affordable electricity should be an issue in the Ontario election

Ontario Electricity Supply Gap threatens growth as demand from EVs, heat pumps, industry, and greenhouses surges, pressuring the grid and IESO to add nuclear, renewables, storage, transmission, and imports while meeting net-zero goals.

 

Key Points

The mismatch as Ontario's electricity demand outpaces supply, driven by electrification, EVs, and industrial growth.

✅ Demand growth from EVs, heat pumps, and electrified industry

✅ Capacity loss from Pickering retirement and Darlington refurb

✅ Options: SMRs, renewables, storage, conservation, imports

 

Ontario electricity demand is forecast to soon outstrip supply as it confronts a shortage in the coming years, a problem that needs attention in the upcoming provincial election.

Forecasters say Ontario will need to double its power supply by 2050 as industries ramp up demand for low-emission clean power options and consumers switch to electric vehicles and space heating. But while the Ford government has made a flurry of recent energy announcements, including a hydrogen project at Niagara Falls and an interprovincial agreement on small nuclear reactors, it has not laid out how it intends to bulk up the province’s power supply.

“Ontario is entering a period of widening electricity shortfalls,” says the Ontario Chamber of Commerce. “Having a plan to address those shortfalls is essential to ensure businesses can continue investing and growing in Ontario with confidence.”

The supply and demand mismatch is coming because of brisk economic growth combined with increasing electrification to balance demand and emissions and meet Canada’s goal to reduce CO2 emissions by 40 per cent by 2030 and to net-zero by 2050.

Hamilton’s ArcelorMittal Dofasco and Algoma Steel in Sault Ste. Marie are leaders on this transformation. They plan to replace their blast furnaces and basic oxygen furnaces later this decade with electric arc furnaces (EAFs), reducing annual CO2 emissions by three million tonnes each.


Dofasco, which operates an EAF that is already the single largest electricity user in Ontario, plans to build a second EAF and a gas-fired ironmaking furnace, which can also be powered with zero-carbon hydrogen produced from electricity, once it becomes available.

Other new projects in the agriculture, mining and manufacturing sectors are also expected to be big power users, including the recently announced $5 billion Stellantis-LG electric vehicle battery plant in Windsor. Five new transmission lines will be built to service the plant and the burgeoning greenhouse industry in southwestern Ontario. The greenhouses alone will require enough additional electricity to power a city the size of Ottawa.

On top of these demands, growing numbers of Ontario drivers are expected to switch to electric vehicles and many homeowners and business owners are expected to convert from gas heating to heat pumps and electric heating.

Ontario is recognized as one of the cleanest electricity systems in the world, with over 90 per cent of its capacity from low-emission nuclear, hydro, wind and other renewable generation. Only nine per cent comes from CO2-emitting gas plants. But that’s about to get dirtier according to analysts.

Annual electricity demand is expected to grow from 140 terawatt hours (a terawatt hour is one trillion watts for one hour) currently to about 200 terawatt hours in 2042, according to the Independent Electricity System Operator, the agency that manages Ontario’s grid.

Demand is expected to outstrip currently contracted supply in 2026, reaching a growing supply gap of about 80 terawatt hours by 2042. A big part of this gap is due to the scheduled retirement of the Pickering nuclear station in 2025 and the current refurbishment of the Darlington nuclear station reactors. While the IESO doesn’t expect blackouts or brownouts, it forecasts the province will need to sharply increase expensive power imports and triple the amount of CO2-polluting gas-fired generation.

Without cleaner, lower-cost alternatives, this will mean “a vastly dirtier and more expensive electricity system,” York University researchers Mark Winfield and Collen Kaiser said in a recent commentary.

The party that wins the provincial election will have to make hard decisions on renewable energy, including new wind and solar projects, energy conservation, battery storage, new hydro plants, small nuclear reactors, gas generation and power imports from the U.S. and Quebec. In addition, the federal government is pressing the provinces to meet a new net-zero clean electricity standard by 2035. These decisions will have huge impact on Ontario’s future, with greening the grid costs highlighted in some reports as potentially very high.

With so much at stake, Ontario’s political parties need to tell voters during the upcoming campaign how they would address these enormous challenges.

 

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US Automakers Will Build 30,000 Electric Vehicle Chargers

Automaker EV Fast-Charging Network will deploy 30,000 DC fast chargers across US and Canada, supporting CCS and NACS, integrating Tesla compatibility, easing range anxiety, and expanding highway and urban charging infrastructure with amenities and uptime.

 

Key Points

A $1B joint venture by seven automakers to build 30,000 DC fast chargers with CCS and NACS across the US and Canada.

✅ 30,000 DC fast chargers by 2030 across US and Canada

✅ Supports CCS and NACS; Tesla compatibility planned

✅ Launching mid-2024; focus on highways, urban hubs, amenities

 

Seven major automakers announced a plan on Wednesday to nearly double the number of fast chargers in the United States in an effort to address one of the main reasons that people hesitate to buy electric cars, even as the age of electric cars accelerates.

The carmakers — BMW Group, General Motors, Honda, Hyundai, Kia, Mercedes-Benz Group and Stellantis — will initially invest at least $1 billion in a joint venture that will build 30,000 charging ports on major highways and other locations in the United States and Canada.

The United States and Canada have about 36,000 fast chargers — those that can replenish a drained battery in 30 minutes or less. In some sparsely populated areas, such chargers can be hundreds of miles apart. Surveys show that fear about not being able to find a charger during longer journeys is a major reason that some car buyers are reluctant to buy electric vehicles.

Sales of electric vehicles have risen quickly in the United States as the market hits an inflection point, but there are signs that demand is softening. As a result, Tesla, Ford and other carmakers have cut prices in recent months and are offering incentives. Popular models that had long waiting lists last year are now available in a few days or weeks.

Major carmakers are investing billions of dollars to manufacture electric vehicles and batteries and to establish supplier networks. Having staked their futures on the technology, they have a strong incentive to ensure that electric vehicles catch on with car buyers, even as gas-electric hybrids help bridge the transition.

The chargers installed by the joint venture will have plugs designed for the connections used by most carmakers other than Tesla, as well as the standard developed by Tesla, amid fights for control over charging, that Ford, G.M. and other companies have said they intend to switch to in 2025.

“The better experience people have, the faster E.V. adoption will grow,” Mary T. Barra, the chief executive of General Motors, said in a statement.

The seven automakers plan to formalize the joint venture and announce its name by the end of the year, Chris Martin, a Honda spokesman, said. The first chargers will begin operating around the middle of 2024, he said, with all 30,000 in place by the end of the decade.

The joint venture is open to adding other partners, he said. Among major automakers, Ford was a notable absence from the announcement on Wednesday. The company said in a statement on Wednesday that it would continue to iThe partnership also does not include Volkswagen. The company is a majority shareholder of Electrify America, one of the largest fast-charging providers.

Tesla accounts for more than half the fast chargers in the United States and has said it will open its networks to other car brands, though, so far, it has only made fewer than 100 ports available. Owners of Ford and G.M. vehicles, among others, will be able to connect to 12,000 Tesla fast chargers using an adapter beginning next year. In 2025, Ford and G.M. plan to make models designed to take the Tesla plug without an adapter.

The decision by the seven carmakers to form the joint venture is an indication that they do not intend to rely solely on Tesla, which dominates sales of electric vehicles, for charging.

The chargers being built by the joint venture will be concentrated in urban areas and along major highways, especially those used most heavily by vacationers and other travelers, the companies said in a joint statement. Charging stations will be close to restrooms, restaurants and other amenities. The partners said they would try to take advantage of federal and state funds available for charging infrastructure amid questions about whether the U.S. has the power to charge it at scale.

Most electric vehicle owners charge at home and rarely need to use public chargers. Home chargers typically replenish batteries overnight. Most public chargers, about 125,000 in the United States and Canada, also operate relatively slowly — taking four to 10 hours to do the job.nvest in its own network, which allows Ford owners to charge from a variety of providers with one mobile phone app.

 

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Hurricane Michael by the numbers: 32 dead, 1.6 million homes, businesses without power

Hurricane Michael, a historic Category 4 storm, struck the Florida Panhandle early Wednesday afternoon, unleashing heavy rain, high winds and a devastating storm surge.

 

Here is a look at the dangerous storm by the numbers:

155 mph: Wind speed -- nearly the highest possible for a Category 4 hurricane -- with which Michael made landfall near Mexico Beach and Panama City. A hurricane with 157 mph or higher is a Category 5, the strongest on the Saffir-Simpson hurricane wind scale.

129 mph: Peak wind gust reported Wednesday at Tyndall Air Force Base, which is about 12 miles southeast of Panama City, Florida.

32: Number of storm-related deaths attributed to Michael thus far, including an 11-year-old girl who local officials say was killed when part of a metal carport crashed into her family's mobile home in Lake Seminole, Georgia, and a 38-year-old man who was killed when a tree fell onto his moving car in Statesville, North Carolina.

 

Waves take over a house as Hurricane Michael comes ashore in Alligator Point, Fla., Oct. 10, 2018.

14 feet: Maximum height forecast for the storm surge when Michael's strong winds pushed the ocean water onto land. A storm surge just over 9 feet was reported Wednesday in Apalachicola, Florida.

12 inches: Isolated maximum amount of rain that Michael was expected to dump across the Florida Panhandle and the state's Big Bend region, as well as in southeast Alabama and parts of southwest and central Georgia.

9 inches: Maximum amount of rain that Michael could bring to isolated areas from Virginia to North Carolina.

1.6 million: Number of homes and businesses without power in Florida, Alabama, Georgia, South Carolina, North Carolina and Virginia as of Friday morning.

30,000: Number of workers mobilized from across the country to help restore power.

6: Number of states that had emergency declarations in anticipation of Michael: Florida, Alabama, Georgia, South Carolina, North Carolina and Virginia.

325,000: Estimated number of people in the storm's path who were told to evacuate by local authorities.

6,000: Approximate number of people who stayed in the roughly 80 shelters across Florida, Alabama, Georgia, South Carolina and North Carolina on Wednesday night.

3,000: Number of personnel the Federal Emergency Management Agency deployed ahead of landfall.

35: Number of counties in Florida, of the state's 67, where Gov. Rick Scott declared a state of emergency prior to landfall.

3,500: Number of Florida National Guard troops activated for pre-landfall coordination and planning, with an emphasis on high water and search-and-rescue operations.

600: Number of Florida state troopers assigned to the Panhandle and Big Bend region to assist with response and recovery efforts.

500: Number of disaster relief workers that the American Red Cross was sending to affected areas in the Sunshine State.

200: Approximate number of patients being evacuated from at least two hospitals in Florida due to damage from the hurricane. Bay Medical Center Sacred Heart in Panama City said in a statement Thursday that its facility was damaged during the storm and thus is transferring more than 200 patients, including 39 who are critically ill, to regional hospitals. Gulf Coast Regional Medical Center, also in Panama City, announced in a statement Thursday that it's evacuating its roughly approximately patients, starting with the most critically ill, "because of the infrastructure challenges in our community."

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