Shedding light on imperfect choices

By Globe and Mail


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When it comes to light bulbs and the environment, is the cure worse than the disease?

Nobody denies that the use of traditional incandescent lighting is bad for the environment. Incandescent lights heat a filament inside a tube to produce light; and more than 90 per cent of the energy is used to create heat, wasting electricity.

They are so inefficient that several governments plan to ban them in the next several years in an effort to reduce electricity consumption and therefore the greenhouse gas emissions that cause global warming.

For the moment, the main alternative to incandescent bulbs are the much more energy efficient compact fluorescent bulbs, but they come with their own problem: toxic mercury. But environmentalists see new technologies around the corner that would mean clean, energy efficient lighting.

Ontario is the first province in Canada and the first government in North America to ban inefficient lighting - it plans to ban the sale of incandescent bulbs by 2012. Australia had already committed to a ban on incandescent bulbs by 2010; the Canadian government announced a ban on the sale of incandescent light bulbs by 2012.

If all Ontarians stopped using incandescent lights, it would be the equivalent of taking 250,000 cars off the road, according to the provincial environment ministry. To put it another way, if the roughly 87 million incandescent bulbs in Ontario homes were replaced with compact fluorescent lighting (CFL), it could cut electricity demand by six million megawatt hours over the course of a year - enough to power 600,000 households.

The provincial ban will only make it illegal for retailers to sell the bulbs; homeowners and businesses won't be penalized for using them; the federal ban will let people use incandescent lights where energy-efficient alternatives are not available. Even so, the ban will see most consumers move to CFLs, which use 75 per cent less electricity than incandescent lights and also last up to 10 times longer.

Like fluorescent tubes in office complexes, CFLs use a small amount of electricity to excite gas in a tube and produce an invisible ultraviolet light that bounces off a fluorescent coating to produce light. Though CFLs don't illuminate as quickly as incandescent lights and produce less visible light from the same wattage, they produce less heat and save a lot of energy.

Unfortunately, CFLs also contain mercury - a toxic substance that can be hazardous if inhaled and is environmentally unfriendly. If a CFL bulb bursts in an area that is not well ventilated, individuals may inhale mercury. As well, the bulbs should not be tossed in garbage destined for landfills. Instead, they should be disposed of like batteries, says Peter Howard, director of climate change services with Zerofootprint Inc.

Still, having pointed out the down side, Mr. Howard says Zerofootprint is "not declaring them a hazardous substance" as there is "no evidence of them breaking more often than incandescent light bulbs."

As well, in a province such as Alberta, where the largest source of mercury emission emanates from coal-fired plants used to generate electricity, the use of CFLs will reduce overall mercury emissions, he says.

"They are a better solution, not a perfect solution," he says.

Friends of the Earth (FoE) Canada, a charitable, non-profit environmental organization, applauds the Canadian government's ban on incandescent light bulbs. But it wants the government to go even further, says Beatrice Olivastri, FoE's chief executive officer. It wants the government to encourage the development of technologies that are even more environmentally friendly than CFLs, then ban the use of CFLs in favour of new and improved technologies - such as LED lights, which currently do not shed enough light to illuminate rooms.

"Let's send a clear signal so people innovate and compete and bring in the next generation of lights to market," said Ms. Olivastri.

While LED lights, which generally adorn porches during the Christmas holidays, are not yet ready for prime time, they are getting better. For instance, LED clusters that fit conventional light sockets are currently being developed and should soon generate enough light to replace incandescent and CFL bulbs.

"They are the new and promising technology," says Mr. Howard. A high-intensity cluster of LEDs can shed proper light while producing virtually no heat. They last 20 years, have no mercury and can be used with dimmer switches, he adds.

Beyond energy-efficient artificial lighting, architects are starting to design homes and offices that maximize the use of available sunlight - reducing the overall need for artificial light. Some skylights are now being connected to light tunnels, or fibre optic tubes, that can direct light that comes in through the skylight to various rooms in a house - even a hallway or basement.

So while new light bulb technology will reduce overall energy consumption, new architectural design, coupled with technology, will reduce the need for artificial lighting, further reducing energy consumption, says Mr. Howard.

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Abengoa, Acciona to start work on 110MW Cerro Dominador CSP plant in Chile

Cerro Dominador CSP Plant delivers 110MW concentrated solar power in Chile's Atacama Desert, with 10,600 heliostats, 17.5-hour molten salt storage, and 24/7 dispatchable energy; built by Acciona and Abengoa within a 210MW complex.

 

Key Points

A 110MW CSP solar-thermal plant in Chile with heliostats and 17.5h molten salt storage, delivering 24/7 dispatchable clean power.

✅ 110MW CSP with 17.5h molten salt for 24/7 dispatch

✅ 10,600 heliostats; part of a 210MW hybrid CSP+PV complex

✅ Built by Acciona and Abengoa; first of its kind in LatAm

 

A consortium formed by Spanish groups Abengoa and Acciona, as Spain's renewable sector expands with Enel's 90MW wind build activity, has signed a contract to complete the construction of the 110MW Cerro Dominador concentrated solar power (CSP) plant in Chile.

The consortium received notice to proceed to build the solar-thermal plant, which is part of the 210MW Cerro Dominador solar complex.

Under the contract, Acciona, which has 51% stake in the consortium and recently launched a 280 MW Alberta wind farm, will be responsible for building the plant while Abengoa will act as the technological partner.

Expected to be the first of its kind in Latin America upon completion, the plant is owned by Cerro Dominador, which in turn is owned by funds managed by EIG Global Energy Partners.

The project will add to a Abengoa-built 100MW PV plant, comparable to California solar projects in scope, which was commissioned in February 2018, to form a 210MW combined CSP and PV complex.

Spread across an area of 146 hectares, the project will feature 10,600 heliostats and will have capacity to generate clean and dispatachable energy for 24 hours a day using its 17.5 hours of molten salt storage technology, a field complemented by battery storage advances.

Expected to prevent 640,000 tons of CO2 emission, the plant is located in the commune of María Elena, in the Atacama Desert, in the Antofagasta Region.

“In total, the complex will avoid 870,000 tons of carbon dioxide emissions into the atmosphere every year and, in parallel with Enel's 450 MW U.S. wind operations, will deliver clean energy through 15-year energy purchase agreements with distribution companies, signed in 2014.

“The construction of the solarthermal plant of Cerro Dominador will have an important impact on local development, with the creation of more than 1,000 jobs in the area during its construction peak, and that will be priority for the neighbors of the communes of the region,” Acciona said in a statement.

The Cerro Dominador plant represents Acciona’s fifth solar thermal plant being built outside of Spain. The firm has constructed 10 solarthermal plants with total installed capacity of 624MW.

Acciona has been operating in Chile since 1993. The company, through its Infrastructure division, executed various construction projects for highways, hospitals, hydroelectric plants and infrastructures for the mining sector.

 

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Renewable energy now cheapest option for new electricity in most of the world: Report

Renewable Energy Cost Trends highlight IRENA data showing solar and wind undercut coal, as utility-scale projects drive lower levelized electricity costs worldwide, with the Middle East and UAE advancing mega solar parks.

 

Key Points

They track how solar and wind undercut new fossil fuels as utility-scale costs drop and investment accelerates.

✅ IRENA reports renewables cheapest for new installations

✅ Solar and wind LCOE fell sharply since 2010

✅ Middle East and UAE scale mega utility projects

 

Renewable energy is now the cheapest option for new electricity installation in most of the world, a report from the International Renewable Energy Agency (IRENA) on Tuesday said.

Renewable power projects have undercut traditional coal fuel plants, with solar and wind power costs in particular falling as record-breaking growth continues worldwide.

“Installing new renewables increasingly costs less than the cheapest fossil fuels. With or without the health and economic crisis, dirty coal plants were overdue to be consigned to the past, said Francesco La Camera, director-general of IRENA said in the report.

In 2019, renewables accounted for around 72 percent of all new capacity added worldwide, IRENA said, following a 2016 record year that highlighted the momentum, with lowering costs and technological improvements in solar and wind power helping this dynamic. For solar energy, IRENA notes that the cost for electricity from utility-scale plants fell by 82 percent in the decade between 2010 and 2019, as China's solar PV growth underscored in 2016.

“More than half of the renewable capacity added in 2019 achieved lower electricity costs than new coal, while new solar and wind projects are also undercutting the cheapest and least sustainable of existing coal-fired plants,” Camera added.

Costs for solar and wind power also fell year-on-year by 13 and 9 percent, respectively, with offshore wind costs showing steep declines as well. In 2019, more than half of all newly commissioned utility-scale renewable power plants provided electricity cheaper than the lowest cost of a new fossil fuel plant.

The Middle East

In mid-May, a report by UK-based law firm Ashurst suggested the Middle East is the second most popular region for renewable energy investment after North America, at a time when clean energy investment is outpacing fossil fuels.

The region is home to some of the largest renewable energy bets in the world, with Saudi wind expansion gathering pace. The UAE, for instance, is currently developing the Mohammed Bin Rashid Solar Park, the world’s largest concentrated solar power project in the world.

Around 26 percent of Middle East respondents in Ashurst’s survey said that they were presently investing in energy transition, marking the region as the most popular for current investment in renewables, while 11 percent added that they were considering investing.

In North America, the most popular region, 28 percent said that they were currently investing, with 11 percent stating they are considering investing.

 

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Electricity retailer Griddy's unusual plea to Texas customers: Leave now before you get a big bill

Texas wholesale electricity price spike disrupts ERCOT markets as Griddy and other retail energy providers face surge pricing; customers confront spot market exposure, fixed-rate plan switching, demand response appeals, and deep-freeze grid constraints across Texas.

 

Key Points

An extreme ERCOT market surge sending real-time rates to caps, exposing Griddy users and driving provider-switch pleas.

✅ Wholesale index plans pass through $9,000/MWh scarcity pricing.

✅ Retailers urge switching; some halt enrollments amid volatility.

✅ Demand response incentives and conservation pleas reduce load.

 

Some retail power companies in Texas are making an unusual plea to their customers amid a winter storm that has sent electricity prices skyrocketing: Please, leave us.

Power supplier, Griddy, told all 29,000 of its customers that they should switch to another provider as spot electricity prices soared to as high as $9,000 a megawatt-hour. Griddy’s customers are fully exposed to the real-time swings in wholesale power markets, so those who don’t leave soon will face extraordinarily high electricity bills.

“We made the unprecedented decision to tell our customers — whom we worked really hard to get — that they are better off in the near term with another provider,” said Michael Fallquist, chief executive officer of Griddy. “We want what’s right by our consumers, so we are encouraging them to leave. We believe that transparency and that honesty will bring them back” once prices return to normal.

Texas is home to the most competitive electricity market in America. Homeowners and businesses shopping for electricity churn power providers there like credit cards. In the face of such cutthroat competition, retail power providers in the region have grown accustomed to offering new customers incredibly low rates, incentives and, at least in Griddy’s case, unusual plans that allow customers to pay wholesale power prices as opposed to fixed ones.

The ruthless nature of the business has power traders speculating over which firms might have been caught short this week in the most dramatic run-up in spot power prices they’ve ever seen, and even talk of a market bailout has surfaced.

Not all companies are asking customers to leave. Others are just pleading for them to cut back to reduce blackout risks during extreme weather.

Pulse Power, based in The Woodlands, Texas, is offering customers a chance to win a Tesla Model 3, or free electricity for up to a year if they reduce their power usage by 10% in the coming days. Austin-based Bulb is offering $2 per kilowatts-hour, up to $200, for any energy customers save.

Griddy, however, is in a different position. Its service is simple — and controversial. Members pay a $9.99 monthly fee and then pay the cost of spot power traded on Texas’s power grid based on the time of day they use it. Earlier this month, that meant customers were saving money — and at times even getting paid — to use electricity at night. But in recent days, the cost of their power has soared from about 5 to 6 cents a kilowatt-hour to $1 or more. That’s when Fallquist knew it was time to urge his customers to leave.

“I can tell you it was probably one of the hardest decisions we’ve ever made,” he said. “Nobody ever wants to see customers go.”

Griddy isn’t the only one out there actively encouraging its customers to leave. People were posting similar pleas on Twitter over the holiday weekend from other Texas utilities and retail power providers offering everything from $100 rebates to waived cancellation fees as incentives to switch.

Customers may not even be able to switch. Rizwan Nabi, president of energy consultancy Riz Energy in Houston, said several power providers in Texas have told him they aren’t accepting new customers due to this week’s volatile prices, while grid improvements are debated statewide.

Hector Torres, an energy trader in Texas, who is a Griddy customer himself, said he tried to switch services over the long weekend but couldn’t find a company willing to take him until Wednesday, when the weather is forecast to turn warmer.

 

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Its Electric Grid Under Strain, California Turns to Batteries

California Battery Storage is transforming grid reliability as distributed energy, solar-plus-storage, and demand response mitigate rolling blackouts, replace peaker plants, and supply flexible capacity during heat waves and evening peaks across utilities and homes.

 

Key Points

California Battery Storage uses distributed and utility batteries to stabilize power, shift solar, and curb blackouts.

✅ Supplies flexible capacity during peak demand and heat waves

✅ Enables demand response and replaces gas peaker plants

✅ Aggregated assets form virtual power plants for grid support

 

Last month as a heat wave slammed California, state regulators sent an email to a group of energy executives pleading for help to keep the lights on statewide. “Please consider this an urgent inquiry on behalf of the state,” the message said.

The manager of the state’s grid was struggling to increase the supply of electricity because power plants had unexpectedly shut down and demand was surging. The imbalance was forcing officials to order rolling blackouts across the state for the first time in nearly two decades.

What was unusual about the emails was whom they were sent to: people who managed thousands of batteries installed at utilities, businesses, government facilities and even homes. California officials were seeking the energy stored in those machines to help bail out a poorly managed grid and reduce the need for blackouts.

Many energy experts have predicted that batteries could turn homes and businesses into mini-power plants that are able to play a critical role in the electricity system. They could soak up excess power from solar panels and wind turbines and provide electricity in the evenings when the sun went down or after wildfires and hurricanes, which have grown more devastating because of climate change in recent years. Over the next decade, the argument went, large rows of batteries owned by utilities could start replacing power plants fueled by natural gas.

But that day appears to be closer than earlier thought, at least in California, which leads the country in energy storage. During the state’s recent electricity crisis, more than 30,000 batteries supplied as much power as a midsize natural gas plant. And experts say the machines, which range in size from large wall-mounted televisions to shipping containers, will become even more important because utilities, businesses and homeowners are investing billions of dollars in such devices.

“People are starting to realize energy storage isn’t just a project or two here or there, it’s a whole new approach to managing power,” said John Zahurancik, chief operating officer at Fluence, which makes large energy storage systems bought by utilities and large businesses. That’s a big difference from a few years ago, he said, when electricity storage was seen as a holy grail — “perfect, but unattainable.”

On Friday, Aug. 14, the first day California ordered rolling blackouts, Stem, an energy company based in the San Francisco Bay Area, delivered 50 megawatts — enough to power 20,000 homes — from batteries it had installed at businesses, local governments and other customers. Some of those devices were at the Orange County Sanitation District, which installed the batteries to reduce emissions by making it less reliant on natural gas when energy use peaks.

John Carrington, Stem’s chief executive, said his company would have provided even more electricity to the grid had it not been for state regulations that, among other things, prevent businesses from selling power from their batteries directly to other companies.

“We could have done two or three times more,” he said.

The California Independent System Operator, which manages about 80 percent of the state’s grid, has blamed the rolling blackouts on a confluence of unfortunate events, including extreme weather impacts on the grid that limited supply: A gas plant abruptly went offline, a lack of wind stilled thousands of turbines, and power plants in other states couldn’t export enough electricity. (On Thursday, the grid manager urged Californians to reduce electricity use over Labor Day weekend because temperatures are expected to be 10 to 20 degrees above normal.)

But in recent weeks it has become clear that California’s grid managers also made mistakes last month, highlighting the challenge of fixing California’s electric grid in real time, that were reminiscent of an energy crisis in 2000 and 2001 when millions of homes went dark and wholesale electricity prices soared.

Grid managers did not contact Gov. Gavin Newsom’s office until moments before it ordered a blackout on Aug. 14. Had it acted sooner, the governor could have called on homeowners and businesses to reduce electricity use, something he did two days later. He could have also called on the State Department of Water Resources to provide electricity from its hydroelectric plants.

Weather forecasters had warned about the heat wave for days. The agency could have developed a plan to harness the electricity in numerous batteries across the state that largely sat idle while grid managers and large utilities such as Pacific Gas & Electric scrounged around for more electricity.

That search culminated in frantic last-minute pleas from the California Public Utilities Commission to the California Solar and Storage Association. The commission asked the group to get its members to discharge batteries they managed for customers like the sanitation department into the grid. (Businesses and homeowners typically buy batteries with solar panels from companies like Stem and Sunrun, which manage the systems for their customers.)

“They were texting and emailing and calling us: ‘We need all of your battery customers giving us power,’” said Bernadette Del Chiaro, executive director of the solar and storage association. “It was in a very last-minute, herky-jerky way.”

At the time of blackouts on Aug. 14, battery power to the electric grid climbed to a peak of about 147 megawatts, illustrating how virtual power plants can rapidly scale, according to data from California I.S.O. After officials asked for more power the next day, that supply shot up to as much as 310 megawatts.

Had grid managers and regulators done a better job coordinating with battery managers, the devices could have supplied as much as 530 megawatts, Ms. Del Chiaro said. That supply would have exceeded the amount of electricity the grid lost when the natural gas plant, which grid managers have refused to identify, went offline.

Officials at California I.S.O. and the public utilities commission said they were working to determine the “root causes” of the crisis after the governor requested an investigation.

Grid managers and state officials have previously endorsed the use of batteries, using AI to adapt as they integrate them at scale. The utilities commission last week approved a proposal by Southern California Edison, which serves five million customers, to add 770 megawatts of energy storage in the second half of 2021, more than doubling its battery capacity.

And Mr. Zahurancik’s company, Fluence, is building a 400 megawatt-hour battery system at the site of an older natural gas power plant at the Alamitos Energy Center in Long Beach. Regulators this week also approved a plan to extend the life of the power plant, which was scheduled to close at the end of the year, to support the grid.

But regulations have been slow to catch up with the rapidly developing battery technology.

Regulators and utilities have not answered many of the legal and logistical questions that have limited how batteries owned by homeowners and businesses are used. How should battery owners be compensated for the electricity they provide to the grid? Can grid managers or utilities force batteries to discharge even if homeowners or businesses want to keep them charged up for their own use during blackouts?

During the recent blackouts, Ms. Del Chiaro said, commercial and industrial battery owners like Stem’s customers were compensated at the rates similar to those that are paid to businesses to not use power during periods of high electricity demand. But residential customers were not paid and acted “altruistically,” she said.

 

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Nine EU countries oppose electricity market reforms as fix for energy price spike

EU Electricity Market Reform Opposition highlights nine states resisting an overhaul of the wholesale power market amid gas price spikes, urging energy efficiency, interconnection targets, and EU caution rather than redesigns affecting renewables.

 

Key Points

Nine EU states reject overhauling wholesale power pricing, favoring efficiency and prudent policy over redesigns.

✅ Nine states oppose redesign of wholesale power market.

✅ Call for efficiency and 15% interconnection by 2030.

✅ Ministers to debate responses amid gas-driven price spikes.

 

Germany, Denmark, Ireland and six other European countries said on Monday they would not support a reform of the EU electricity market, ahead of an emergency meeting of energy ministers to discuss emergency measures and the recent price spike.

European gas and power prices soared to record high levels in autumn and have remained high, prompting countries including Spain and France to urge Brussels to redesign its electricity market rules.

Nine countries on Monday poured cold water on those proposals, in a joint statement that said they "cannot support any measure that conflicts with the internal gas and electricity market" such as an overhaul of the wholesale power market altogether.

"As the price spikes have global drivers, we should be very careful before interfering in the design of internal energy markets," the statement said.

"This will not be a remedy to mitigate the current rising energy prices linked to fossil fuels markets across Europe."

Austria, Germany, Denmark, Estonia, Finland, Ireland, Luxembourg, Latvia and the Netherlands signed the statement, which called instead for more measures to save energy and a target for a 15% interconnection of the EU electricity market by 2030.

European energy ministers meet tomorrow to discuss their response to the price spike, including gas price cap strategies under consideration. Most countries are using tax cuts, subsidies and other national measures to shield consumers against the impact higher gas prices are having on energy bills, but EU governments are struggling to agree on a longer term response.

Spain has led calls for a revamp of the wholesale power market in response to the price spike, amid tensions between France and Germany over reform, arguing that the system is not supporting the EU's green transition.

Under the current system, the wholesale electricity price is set by the last power plant needed to meet overall demand for power. Gas plants often set the price in this system, which Spain said was unfair as it results in cheap renewable energy being sold for the same price as costlier fossil fuel-based power.

The European Commission has said it will investigate whether the EU power market is functioning well, but that there is no evidence to suggest a different system would have better protected countries against the surge in energy costs, and that rolling back electricity prices is tougher than it appears during such spikes.

 

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Trump's Pledge to Scrap Offshore Wind Projects

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

 

Key Points

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

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

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

✅ Likely court fights and state-federal regulatory conflicts

 

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

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

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

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

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

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

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

 

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