Farmers growing power along with their crops

By Associated Press


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Vern and Gianaclis Caldwell do a lot of the typical things that make a small farm self-sufficient.

Besides the 40-some dwarf Nigerian goats they milk to make artisanal cheeses, they also raise chickens for meat and eggs, a steer for beef, horses to ride and vegetables for the table.

Unlike most small farms, their heat and electricity is entirely home grown. They produce electricity from solar panels when the sun shines, and a micro-hydro turbine when winter rains put water in the creek. Oak and fir cut from the farm fire a boiler that heats the cement floors of the dairy and cheese making room, as well as the hot water to wash the goats and themselves.

"We thought we should be responsible for our own energy," said Vern Caldwell, a retired U.S. Marine Corps aircraft maintenance officer. "So that drove a lot of everything else that we did — where the buildings were placed, how they were placed, taking advantage of passive solar, how we were going to heat, how we were going to cool. All those issues then got driven by this one decision to be off the grid."

Pholia Farm is unusual in the degree to which it is energy self-sufficient.

But more farms are installing renewable energy, said Stephanie Page, renewable energy specialist for the Oregon Department of Agriculture. The motivation was sparked by the 2008 spike in fuel prices, and is being fanned by a range of grants and tax credits handed out by state, federal and private agencies.

"As they exhaust energy efficiency projects on their farms, then they are starting to look more at renewable energy," she said.

Just how many remains unclear, but the motivation seems to still be a desire to be green more than the bottom line, despite an increasing array of financial incentives.

No one really knows how many U.S. farms use renewable energy, such as solar photovoltaic panels, hydroelectric generators, and methane digesters. The 2007 Farm Census found 23,451 out of more than 2 million farms — about 1 percent — generated some kind of electricity or energy, but just what that means is unclear. The agency is doing a more detailed count this year.

But indications are that the numbers are rising.

Overall renewable energy production rose 5 percent from 2007 to 2008, according to the Energy Information Administration.

And there were $9 million worth of applications for just $2.4 million in grants authorized by the 2008 Farm Bill for farm energy audits, a precondition to applying for alternative energy grants, said Bill Hagy, special assistant for alternative energy policy for the secretary of Agriculture.

In fiscal year 2008, USDA Rural Development funded 197 renewable energy projects, and projections are for 385 projects in fiscal 2009, said spokesman Jay Fletcher.

At Persephone Farm in Lebanon, Jeff Falen and his wife, Elanor O'Brien, raise organic vegetables. They have been building up their solar array since 2004, and the latest installation should bring them up to 100 percent of their annual electricity use, which includes a plug-in electric tractor. A boost in the Oregon state tax credit from 30 percent to 50 percent, spread over five years, made the latest addition easier. A 30 percent federal tax credit is also available.

"We are basically harvesting the sun when we're farming," said Falen. "That's what our crops are doing. This is just another way of doing it."

Though increases in incentives have made alternative energy more affordable, it remains a philosophical decision rather than a bottom-line decision, Falen added.

"We try to look at the cost of electricity being substantially higher than getting it from the utility," Falen said. "There are a lot of deferred costs of adapting to future climate change, impacts to people's health. With respect to gasoline there is a lot of cost from fighting wars to maintain supply."

Solar contractor Ron Summers in Detroit, Ore., regularly advises farmers that they need to be showing a significant profit to take advantage of the tax credits that are a big part of making renewable energy pay.

"Everybody wants to be green," he said. "Not everybody can afford it."

Wintergreen Farm in Noti grows organic fruits, vegetables and grass-fed beef. It took awhile to make enough profit to make the tax credits work for installing solar panels, and a USDA energy grant covering about a quarter of the cost helped them decide to go forward, said partner Jack Gray.

Before adding to capacity that now covers about one-fifth of their energy needs, they plan to improve the energy efficiency of walk-in coolers and other equipment.

"You really have to be able to take advantage of the tax credits, the 50 percent from the state and 30 percent from the feds," Gray said.

Lucien Gunderman was hoping to produce all the electricity he needed to irrigate hay fields and beef pasture on his Crown Hill Farm in McMinnville when he tapped a network of irrigation reservoirs to run a hydroelectric turbine in 2001, but has been surprised by the costs and disappointed in the results.

"It's been a good investment as far as an enjoyable thing to put in and operate and see a project come together and work," he said. "The dollar return has not been the best."

Gunderman blames excessive projections of how much electricity the water available could produce, and figures his original estimate of 19 years to pay back the cost will double, due to having to add on to the system to hit 100 percent of his need.

"Everybody talks about how we need to go to renewable — renewable is great," he said "But you need to have money, which thankfully we had, to invest."

Vern Caldwell would never have gone completely off the grid, with the extra expense of batteries to store the power generated by his solar panels and turbine, if the farm had already been hooked up to power. The land had previously been a grass landing strip owned by Gianaclis' parents. Not hooking in to the grid saved them $10,000 to bring in power from the road.

"The thing to remember about most types of renewable energy is people keep trying to associate it with money," he said. "It's really just because it's something that needs to be done. We felt like it's something we should do. We didn't really calculate a payback. We just felt like it was necessary."

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France and Germany arm wrestle over EU electricity reform

EU Electricity Market Reform CFDs seek stable prices via contracts for difference, balancing renewables and nuclear, shielding consumers, and boosting competitiveness as France and Germany clash over scope, grid expansion, and hydrogen production.

 

Key Points

EU framework using contracts for difference to stabilize power prices, support renewables and nuclear, and protect users.

✅ Guarantees strike prices for new low-carbon generation

✅ Balances consumer protection with industrial competitiveness

✅ Disputed scope: nuclear inclusion, grids, hydrogen eligibility

 

Despite record temperatures this October, Europe is slowly shifting towards winter - its second since the Ukraine war started and prompted Russia to cut gas supplies to the continent amid an energy crisis that has reshaped policy.

After prices surged last winter, when gas and electricity bills “nearly doubled in all EU capitals”, the EU decided to take emergency measures to limit prices.

In March, the European Commission proposed a reform to revamp the electricity market “to boost renewables, better protect consumers and enhance industrial competitiveness”.

However, France and Germany are struggling to find a compromise as rolling back prices is tougher than it appears and the clock is ticking as European energy ministers prepare to meet on 17 October in Luxembourg.


The controversy around CFDs
At the heart of the issue are contracts for difference (CFDs).

By providing a guaranteed price for electricity, CFDs aim to support investment in renewable energy projects.

France - having 56 nuclear reactors - is lobbying for nuclear energy to be included in the CFDs, but this has caught the withering eye of Germany.

Berlin suspects Paris of wanting an exception that would give its industry a competitive advantage and plead that it should only apply to new investments.


France wants ‘to regain control of the price’
The disagreement is at the heart of the bilateral talks in Hamburg, which started on Monday, between the French and German governments.

French President Emmanuel Macron promised “to regain control of the price of electricity, at the French and European level” and outlined a new pricing scheme in a speech at the end of September.

As gas electricity is much more expensive than nuclear electricity, France might be tempted to switch to a national system rather than a European one after a deal with EDF on prices to be more competitive economically.

However, France is "confident" that it will reach an agreement with Germany on electricity market reforms, Macron said on Friday.

Siding with France are other pro-nuclear countries such as Hungary, the Czech Republic and Poland, while Germany can count on the support of Austria, Luxembourg, Belgium and Italy amid opposition from nine EU countries to treating market reforms as a price fix.

But even if a last-minute agreement is reached, the two countries’ struggles over energy are creeping into all current European negotiations on the subject.

Germany wants a massive extension of electricity grids on the continent so that it can import energy; France is banking on energy sovereignty and national production.

France wants to be able to use nuclear energy to produce clean hydrogen, while Germany is reluctant, and so on.

 

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Alberta sets new electricity usage record during deep freeze

Alberta Electricity Demand Record surges during a deep freeze, as AESO reports peak load in megawatts and ENMAX notes increased usage in Calgary and Edmonton, with thermostats up amid a cold snap straining power grid.

 

Key Points

It is the highest electricity peak load recorded by AESO, reflecting maximum grid usage during cold snaps.

✅ AESO reported 11,729 MW peak during the deep freeze

✅ ENMAX saw a 13 percent demand jump week over week

✅ Cold snap drove thermostats up in Calgary and Edmonton

 

Albertans are cranking up their thermostats and blasting heat into their homes at overwhelmingly high rates as the deep freeze continues across the region. 

It’s so cold that the province set a new all-time record Tuesday evening for electricity usage. 

According to the Alberta Electric System Operator (AESO), as electricity prices spike in Alberta during extreme demand, 11,729 MW of power was used around 7 p.m. Tuesday, passing the previous record set in January of last year by 31 MW.

Temperatures reached a low of -29 C in Calgary, where rising electricity bills have strained budgets, on Tuesday while Edmonton saw a low of -30 C, according to Environment Canada. Wind chill  made it feel closer to -40.

“That increase — 31 Megawatts — is sizeable and about the equivalent of a moderately sized generation facility,” said AESO communications director, Mike Deising. 

“We do see higher demand in winter because it’s cold and it’s dark and that’s really exactly what we’re seeing right now as demand goes up, people turn on their lights and turn up their furnaces,” and with the UCP scrapping the price cap earlier that’s really exactly what we’re seeing right now as demand goes up, people turn on their lights and turn up their furnaces.”

Deising adds Alberta’s electricity usage over the last year has actually been much lower than average, though experts urge Albertans to lock in rates amid expected volatility, despite more people staying home during the pandemic. 

That trend was continuing into 2021, but as Alberta's rising electricity prices draw attention, it’s expected that more records could be broken. 

“If the cold snap continues we may likely set another record (Wednesday) or (Thursday), depending on what happens with the temperatures,” he said. 

Meanwhile, ENMAX has reported an average real-time system demand of 1,400 MW for the city of Calgary. 

That amount is still a far cry from the current season record of 1,619 MW (Aug. 18, 2020), the all-time winter record of 1,653MW (Dec. 2, 2013), and the all-time summer record of 1,692 MW (Aug. 10, 2018). 

ENMAX says electricity demand has increased quite significantly over the past week — by about 13 per cent — since the cold snap set in. 

As a result, the energy company is once again rolling out its ‘Winter Wise’ campaign in an effort to encourage Calgarians to manage both electricity and natural gas use in the winter, even as a consumer price cap on power bills is enabled by new legislation.

 

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Ford deal to build electric cars in Oakville comes amid $500M government cash to upgrade plant

Ford Oakville EV investment secures government funding, Unifor deal, and plant retooling, channeling $500 million plus $1.98 billion for Canadian electric vehicle manufacturing, Windsor engine contracts, and 2025 production, strengthening Ontario's auto industry.

 

Key Points

Government and Ford will retool Oakville for EVs, creating jobs under a Unifor deal and Windsor engine work.

✅ $500M government funding for plant retooling

✅ Ford commits $1.98B; five new EVs by 2025

✅ Unifor deal adds Windsor engine work, jobs

 

The federal government and Ontario have pledged to spend up to $500 million to make the Ford plant in Oakville, Ont., able to build electric vehicles, aligning with efforts to capitalize on the U.S. EV pivot underway.

The future of the plant has been a key question for Canada's automotive industry, as moves like GM's Ontario EV deal point to broader changes, ever since the Unifor union started negotiating with the automaker for a new three-year pact to cover the company's Canadian workforce.

The two sides struck a deal a few hours after a midnight strike deadline on Tuesday morning, one that will see the company commit $1.98 billion to build five new electric vehicles and an engine contract that could yield new EV jobs in Windsor, Ont.

Ford has previously committed to spending $11 billion US to develop and manufacture electric vehicles, but so far all of that money was earmarked for Ford plants in Mexico and the company's home state of Michigan.

"With Oakville gaining such a substantial portion of Ford's planned investment, the assembly plant and its workers are better set for employment going forward," said Sam Fiorani, vice-president of global forecasting at AutoForecast Solutions.

Unifor's 'unique' Ford deal includes 5 new electric vehicles in Oakville, engine for Windsor plants
Currently, the plant builds the Ford Edge and Lincoln Nautilus, but concerns over the plant's future emerged earlier this year when a report suggested Ford was contemplating scrapping the Edge altogether. The new vehicles will come as welcome news for the plant, even as Fiorani says he worries that demand for the electric vehicles (EV) has so far not lived up to the hype.

"The EV market is coming, and Ford looks to be preparing for it. However, the demand is just not growing in line with the proposed investment from all vehicle manufacturers," he said.

Plant needs upgrade first
And the plant can't simply flip a switch and start building an entirely new type of vehicle. It will require a major retooling, and that will require time — and cash — to happen, which is where government cash comes in, as seen with a Niagara Region battery plant supporting the EV supply chain.

As first reported by the Toronto Star, the two branches of government have committed to spent up to $500 million combined to upgrade the plant so that it can build electric vehicles.

"The retooling will begin in 2024 with vehicles rolling off the line in 2025," Unifor president Jerry Dias said. "So we know this is a decades-long commitment."

It's not clear what portion of the cash will come from what branch of government, but CBC News has previously reported that Wednesday's throne speech is expected to contain a number of policies aimed at beefing up Canada's electric vehicle industry, as EV assembly deals are putting Canada in the race, both on the consumer side and for businesses that build them.

Ontario's minister of economic development and trade welcomed the news of a tentative deal on Tuesday and confirmed that Queen's Park legislators stand ready to do their part, as shown by Honda's Ontario battery investment moves in the province.

"Our government will always work with our federal colleagues, workers and the auto sector to ensure the right conditions are in place for the industry to remain stable today and seize the new opportunities of tomorrow," a spokesperson for Vic Fedeli told CBC News in an emailed statement Tuesday.

 

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Warren Buffett-linked company to build $200M wind power farm in Alberta

Rattlesnake Ridge Wind Project delivers 117.6 MW in southeast Alberta for BHE Canada, a Berkshire Hathaway Energy subsidiary, using 28 turbines near Medicine Hat under a long-term PPA, supplying renewable power to 79,000 homes.

 

Key Points

A 117.6 MW Alberta wind farm by BHE Canada supplying 79,000 homes via 28 turbines and a long-term PPA.

✅ 28 turbines near Medicine Hat, 117.6 MW capacity

✅ Long-term PPA with a major Canadian corporate buyer

✅ Developed with RES; no subsidies; competitive pricing

 

A company linked to U.S. investor Warren Buffett says it will break ground on a $200-million, 117.6-megawatt wind farm in southeastern Alberta next year.

In a release, Calgary-based BHE Canada, a subsidiary of Buffett's Berkshire Hathaway Energy, says its Rattlesnake Ridge Wind project will be located southwest of Medicine Hat and will produce enough energy to supply the equivalent of 79,000 homes.

"We felt that it was time to make an investment here in Alberta," said Bill Christensen, vice-president of corporate development for BHE Canada, in an interview with the Calgary Eyeopener.

"The structure of the markets here in Alberta, including frameworks for selling renewable energy, make it so that we can invest, and do it at a profit that works for us, and at a price that works for the off-taker," Christensen explained.

Berkshire Hathaway Energy also owns AltaLink, the regulated transmission company that supplies electricity to more than 85 per cent of the Alberta population.

BHE Canada says an unnamed large Canadian corporate partner has signed a long-term power purchase agreement, similar to RBC's solar purchase arrangements, for the majority of the energy output generated by the 28 turbines at Rattlesnake Ridge.

"If you look at just the raw power price that power is going for in Alberta right now, it's averaged around $55 a megawatt hour, or 5.5 cents a kilowatt hour. And we're selling the wind power to this customer at substantially less than that, reflecting wind power's competitiveness in the market, and there's been no subsidies," Christensen said.

 

Positive energy outlook

Christensen said he sees a good future for Alberta's renewable energy industry, not just in wind but also in solar power growth, particularly in the southeast of the province.

But he says BHE Canada is interested in making investments in traditional energy in Alberta, too, as the province is a powerhouse for both green energy and fossil fuels overall.

"It's not a choice of one or the other. I think there is still opportunity to make investments in oil and gas," he said.

"We're really excited about having this project and hope to be able to make other investments here in Alberta to help support the economy here, amid a broader renewable energy surge across the province."

The project is being developed by U.K.-based Renewable Energy Systems, part of a trend where more energy sources make better projects for developers, which is building two other Alberta wind projects totalling 134.6 MW this year and has 750 MW of renewable energy installed or currently under construction in Canada.

BHE Canada and RES are also looking for power purchase partners for the proposed Forty Mile Wind Farm in southeastern Alberta. They say that with generation capacity of 398.5 MW, it could end up being the largest wind power project in Canada.

 

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A new nuclear reactor in the U.S. starts up. It's the first in nearly seven years

Vogtle Unit 3 Initial Criticality marks the startup of a new U.S. nuclear reactor, initiating fission to produce heat, steam, and electricity, supporting clean energy goals, grid reliability, and carbon-free baseload power.

 

Key Points

Vogtle Unit 3 Initial Criticality is the first fission startup, launching power generation at a new U.S. reactor.

✅ First new U.S. reactor to reach criticality since 2016

✅ Generates carbon-free baseload power for the grid

✅ Faced cost overruns and delays during construction

 

For the first time in almost seven years, a new nuclear reactor has started up in the United States.

On Monday, Georgia Power announced that the Vogtle nuclear reactor Unit 3 has started a nuclear reaction inside the reactor as part of the first new reactors in decades now taking shape at the plant.

Technically, this is called “initial criticality.” It’s when the nuclear fission process starts splitting atoms and generating heat, Georgia Power said in a written announcement.

The heat generated in the nuclear reactor causes water to boil. The resulting steam spins a turbine that’s connected to a generator that creates electricity.

Vogtle’s Unit 3 reactor will be fully in service in May or June, Georgia Power said.

The last time a nuclear reactor reached the same milestone was almost seven years ago in May 2016 when the Tennessee Valley Authority started splitting atoms at the Watts Bar Unit 2 reactor in Tennessee, Scott Burnell, a spokesperson for the Nuclear Regulatory Commission, told CNBC.

“This is a truly exciting time as we prepare to bring online a new nuclear unit that will serve our state with clean and emission-free energy for the next 60 to 80 years,” Chris Womack, CEO of Georgia Power, said in a written statement. 

Including the newly turned-on Vogtle Unit 3 reactor, there are currently 93 nuclear reactors operating in the United States and, collectively, they generate 20% of the electricity in the country, although a South Carolina plant leak recently showed how outages can sideline a unit for weeks.

Nuclear reactors, which help combat global warming and support net-zero emissions goals, generate about half of the clean, carbon-free electricity generated in the U.S.

Most of the nuclear power reactors in the United States were constructed between 1970 and 1990, but construction slowed significantly after the accident at Three Mile Island near Middletown, Pennsylvania, on March 28, 1979, even as interest in next-gen nuclear power has grown in recent years. From 1979 through 1988, 67 nuclear reactor construction projects were canceled, according to the U.S. Energy Information Administration.

However, because nuclear energy is generated without releasing carbon dioxide emissions, which cause global warming, the increased sense of urgency in responding to climate change has given nuclear energy a chance at a renaissance as atomic energy heats up again globally.

The cost associated with building nuclear reactors is a major barrier to a potential resurgence in nuclear energy, however, even as nuclear generation costs have fallen to a ten-year low. And the new builds at Vogtle have become an epitome of that charge: The construction of the two Vogtle reactors has been plagued by cost overruns and delays.
 

 

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Opinion: With deregulated electricity, no need to subsidize nuclear power

Pennsylvania Electricity Market Deregulation has driven competitive pricing, leveraged low-cost natural gas, and spurred private investment, jobs, and efficient power plants, while nuclear subsidies threaten wholesale market signals and long-term consumer savings.

 

Key Points

Policy that opens generation to competition, leverages cheap gas, lowers rates, and resists subsidies for nuclear plants.

✅ Competitive wholesale pricing benefits consumers statewide

✅ Gas-driven plants add efficient, flexible capacity and jobs

✅ Nuclear subsidies distort market signals and raise costs

 

For decades, the government regulation of Pennsylvania's electricity markets dictated all aspects of power generation resources in the state, thus restricting market-driven prices for consumers and hindering new power plant development and investment.

Deregulation has enabled competitive markets to drive energy prices downward, as recent grid auction payouts fell 64% indicate, which has transformed Pennsylvania from a higher-electricity-cost state to one with prices below the national average.

Recently, the economic advantage of abundant low-cost natural gas has spurred an influx of billions of dollars of private capital investment and thousands of jobs to construct environmentally responsible natural gas power generation facilities throughout the commonwealth — including our three power generation facilities in operation and one presently under construction.

Calpine is an independent power provider with a national portfolio of 80 highly efficient power plants in operation or under construction with an electric generating capacity of approximately 26,000 megawatts. Collectively, these resources can provide sufficient power for more than 30 million residential homes. We are not a regulated utility receiving a guaranteed rate of return on investment. Rather, Calpine competes to sell wholesale power into the electric markets, and the economics of supply and demand are fundamental to the success of our business.

Pennsylvania's deregulated electricity market is working. Consumers are benefiting from low-cost natural gas, as broader evidence shows competition benefits consumers and the environment across markets, and companies such as Calpine are investing billions of dollars and creating thousands of jobs to build advanced, energy efficient, environmentally responsible and flexible power generating facilities.

There are presently seven electric generating projects under construction in the commonwealth, representing about a $7 billion capital investment that will produce about 7,000 megawatts of efficient electrical power, with additional facilities being planned.

Looking back 20 years following the enactment of the Pennsylvania Electricity Generation Customer Choice and Competition Act, Pennsylvania's regulators and policymakers must conclude that the results of a free and fair market-driven structure have delivered indisputable benefits to the consumer, even amid potential winter rate spikes for residents, and the Pennsylvania economy.

While consumers are now reaping the benefits of open and competitive electricity markets, we see challenges on the horizon that could threaten the foundation of those markets. Due to pressure from nuclear power generators, state policymakers throughout the nation have been increasing efforts to impact the generation mix in their respective states by offering ratepayer funded subsidies to existing nuclear generation resources or by considering a market structure overhaul in New England.

Subsidizing one power generation type over others is having a significant, negative impact on wholesale electric markets, competitive retails markets and ultimately the cost the consumer will have to pay, and can exacerbate disruptions in coal and nuclear industries that strain the economy and risk brownouts.

In Pennsylvania, these subsidies would follow nearly $9 billion already paid by ratepayers to help the commonwealth's nuclear industry transition from regulated to competitive energy markets.

The deregulation of Pennsylvania's electricity markets in the late 1990s allowed the nuclear industry to receive billions of dollars from ratepayers to recover "stranded costs" related to investments in the commonwealth's nuclear plants. These costs were negotiated amounts based on settlements with Pennsylvania's Public Utility Commission to allow the nuclear industry to prepare and transition to competitive electricity markets.

Enough is enough. Regulatory or governmental interference in well functioning markets does not lead to better outcomes. Pennsylvania's state Legislature should not pick winners and losers by enacting legislation that would create an uneven playing field that subsidizes nuclear generating resources in the commonwealth.

William Ferguson is regional vice president for Calpine Corp.

 

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