CoalÂ’s hidden costs $345 billion: study

By Reuters


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The United States' reliance on coal to generate almost half of its electricity, costs the economy about $345 billion a year in hidden expenses not borne by miners or utilities, including health problems in mining communities and pollution around power plants, a study found.

Those costs would effectively triple the price of electricity produced by coal-fired plants, which are prevalent in part due to the their low cost of operation, the study led by a Harvard University researcher found.

"This is not borne by the coal industry, this is borne by us, in our taxes," said Paul Epstein, a Harvard Medical School instructor and the associate director of its Center for Health and the Global Environment, the study's lead author.

"The public cost is far greater than the cost of the coal itself. The impacts of this industry go way beyond just lighting our lights."

Coal-fired plants currently supply about 45 percent of the nation's electricity, according to U.S. Energy Department data. Accounting for all the ancillary costs associated with burning coal would add about 18 cents per kilowatt hour to the cost of electricity from coal-fired plants, shifting it from one of the cheapest sources of electricity to one of the most expensive.

In the year that ended in November, the average retail price of electricity in the United States was about 10 cents per kilowatt hour, according to the Energy Department.

Advocates of coal power have argued that it is among the cheapest of fuel sources available in the United States, allowing for lower-cost power than that provided by the developing wind and solar industries.

"The Epstein article ignores the substantial benefits of coal in maintaining lower energy prices for American families and businesses," said Lisa Camooso Miller, a spokeswoman for the American Coalition for Clean Coal Electricity, an industry group. "Lower energy prices are linked to a higher standard of living and better health."

The estimate of hidden costs takes into account a variety of side effects of coal production and use. Among them are the cost of treading elevated rates of cancer and other illnesses in coal-mining areas, environmental damage and lost tourism opportunities in coal regions where mountaintop removal is practiced and climate change resulting from elevated emissions of carbon dioxide from burning the coal.

Coal releases more carbon dioxide when burned than does natural gas or oil.

The $345 billion annual cost figure was the study's best estimate of the costs associated with burning coal. The study said the costs could be as low as $175 billion or as high as $523 billion.

"This is effectively a subsidy borne by asthmatic children and rain-polluted lakes and the climate is another way of looking at it," said Kert Davies, research director with the environmental activist group Greenpeace. "It's a tax by the industry on us that we are not seeing in our bills but we are bearing the costs."

The estimates came in the paper "Full cost accounting for the life cycle of coal," to be published in the Annals of the New York Academy of Sciences. Epstein discussed his findings on the Arctic Sunrise, a 164-foot-long 50 meter long icebreaker operated by Greenpeace, and moored in Boston Harbor.

Leading users of coal in the United States include utilities American Electric Power Co Inc and Duke Energy Corp. The top producers include miners Arch Coal Inc, Consol Energy Inc, Peabody Energy Corp and Alpha Natural Resources.

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Yet another Irish electricity provider is increasing its prices

Electric Ireland Electricity Price Increase stems from rising wholesale costs as energy suppliers adjust tariffs. Customers face higher electricity bills, while gas remains unchanged; switching provider could deliver savings during winter.

 

Key Points

A 4% increase in Electric Ireland electricity prices from 1 Feb 2018, driven by wholesale costs; gas unchanged.

✅ 4% electricity rise effective 1 Feb 2018

✅ Increase attributed to rising wholesale energy costs

✅ Switching supplier may reduce bills and boost savings

 

ELECTRIC IRELAND has announced that it will increase its household electricity prices by 4% from 1 February 2018.

This comes just a week after both Bord Gáis Energy and SSE Airtricity announced increases in their gas and electricity prices, while national efforts to secure electricity supplies continue in parallel.

Electric Ireland has said that the electricity price increase is unavoidable due to the rising wholesale cost of electricity, with EU electricity prices trending higher as well.

The electricity provider said it has no plans to increase residential gas prices at the moment.

Commenting on the latest announcement, Eoin Clarke, managing director of Switcher.ie, said: “This is the third largest energy supplier to announce a price increase in the last week, so the other suppliers are probably not far behind.

“The fact that the rise is not coming into effect until 1 February will be welcomed by Electric Ireland customers who are worried about the rising cost of energy as winter sets in,” he said.

However, any increase is still bad news, especially as a quarter of consumers (27%) say their energy bill already puts them under financial pressure, and EU energy inflation has disproportionately affected lower-income households.

According to Electric Ireland, this will amount to a €2.91 per month increase for an average electricity customer, amounting to €35 per year.

Meanwhile, SSE Airtricity’s change amounts to an increase of 90 cent per week or €46.80 per year for someone with average consumption on their 24hr SmartSaver standard tariff, far below the dramatic Spain electricity price surge seen recently.

Bord Gáis Energy said its announcement will increase a typical gas bill by €2.12 a month and a typical electricity bill by €4.77 a month, reflecting wider trends such as the Germany power price spike reported recently.

In a statement, Bord Gáis Energy said: “The changes, which will take effect from 1st November 2017, are due to significant increases in the wholesale cost of energy as well as higher costs associated with distributing energy on the gas and electricity networks.

“In percentage terms, the increase represents 3.4% in a typical customer’s gas bill and an increase of 5.9% in a typical customer’s electricity bill.”

Clark said that if customers haven’t switched electricity provider in over a year that they should review the deals available at the moment.

“The market is highly competitive so there are huge savings to be made by switching,” he said.

“All suppliers use the same cables to supply electricity to your home, so you don’t need to worry about any loss in service, and you could save up to 324 by switching from typical standard tariffs to the cheapest deals on the market.”

 

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The Netherlands Outpaces Canada in Solar Power Generation

Netherlands vs Canada Solar Power compares per capita capacity, renewable energy policies, photovoltaics adoption, rooftop installations, grid integration, and incentives like feed-in tariffs and BIPV, highlighting efficiency, costs, and public engagement.

 

Key Points

Concise comparison of per capita capacity, policies, technology, and engagement in Dutch and Canadian solar adoption.

✅ Dutch per capita PV capacity exceeds Canada's by wide margin.

✅ Strong incentives: net metering, feed-in tariffs, rooftop focus.

✅ Climate, grid density, and awareness drive higher yields.

 

When it comes to harnessing solar power, the Netherlands stands as a shining example of efficient and widespread adoption, far surpassing Canada in solar energy generation per capita. Despite Canada's vast landmass and abundance of sunlight, the Netherlands has managed to outpace its North American counterpart, which some experts call a solar power laggard in solar energy production. This article explores the factors behind the Netherlands' success in solar power generation and compares it to Canada's approach.

Solar Power Capacity and Policy Support

The Netherlands has rapidly expanded its solar power capacity in recent years, driven by a combination of favorable policies, technological advancements, and public support. According to recent data, the Netherlands boasts a significantly higher per capita solar power capacity compared to Canada, where demand for solar electricity lags relative to deployment in many regions, leveraging its smaller geographical size and dense population centers to maximize solar panel installations on rooftops and in urban areas.

In contrast, Canada's solar energy development has been slower, despite having vast areas of suitable land for solar farms. Challenges such as regulatory hurdles, varying provincial policies, and the high initial costs of solar installations have contributed to a more gradual adoption of solar power across the country. However, provinces like Ontario have seen significant growth in solar installations due to supportive government incentives and favorable feed-in tariff programs, though growth projections were scaled back after Ontario scrapped a key program.

Innovation and Technological Advancements

The Netherlands has also benefited from ongoing innovations in solar technology and efficiency improvements. Dutch companies and research institutions have been at the forefront of developing new solar panel technologies, improving efficiency rates, and exploring innovative applications such as building-integrated photovoltaics (BIPV). These advancements have helped drive down the cost of solar energy and increase its competitiveness with traditional fossil fuels.

In contrast, while Canada has made strides in solar technology research and development, commercialization and widespread adoption have been more restrained due to factors like market fragmentation and the country's reliance on other energy sources such as hydroelectricity.

Public Awareness and Community Engagement

Public awareness and community engagement play a crucial role in the Netherlands' success in solar power adoption. The Dutch government has actively promoted renewable energy through public campaigns, educational programs, and financial incentives for homeowners and businesses to install solar panels. This proactive approach has fostered a culture of energy conservation and sustainability among the Dutch population.

In Canada, while there is growing public support for renewable energy, varying levels of awareness and engagement across different provinces have impacted the pace of solar energy adoption. Provinces like British Columbia and Alberta have seen increasing interest in solar power, driven by environmental concerns, technological advancements, and economic benefits, as the country is set to hit 5 GW of installed capacity in the near term.

Climate and Geographic Considerations

Climate and geographic considerations also influence the disparity in solar power generation between the Netherlands and Canada. The Netherlands, despite its northern latitude, benefits from relatively mild winters and a higher average annual sunlight exposure compared to most regions of Canada. This favorable climate has facilitated higher solar energy yields and made solar power a more viable option for electricity generation.

In contrast, Canada's diverse climate and geography present unique challenges for solar energy deployment. Northern regions experience extended periods of darkness during winter months, limiting the effectiveness of solar panels in those areas. Despite these challenges, advancements in energy storage technologies and hybrid solar-diesel systems are making solar power increasingly feasible in remote and off-grid communities across Canada, even as Alberta faces expansion challenges related to grid integration and policy.

Future Prospects and Challenges

Looking ahead, both the Netherlands and Canada face opportunities and challenges in expanding their respective solar power capacities. In the Netherlands, continued investments in solar technology, grid infrastructure upgrades, and policy support will be crucial for maintaining momentum in renewable energy development.

In Canada, enhancing regulatory consistency, scaling up solar installations in urban and rural areas, and leveraging emerging technologies will be essential for narrowing the gap with global leaders in solar energy generation and for seizing opportunities in the global electricity market as the energy transition accelerates.

In conclusion, while the Netherlands currently generates more solar power per capita than Canada, with the Prairie Provinces poised to lead growth in the Canadian market, both countries have unique strengths and challenges in their pursuit of a sustainable energy future. By learning from each other's successes and leveraging technological advancements, both nations can further accelerate the adoption of solar power and contribute to global efforts to combat climate change.

 

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Hydro-Québec will refund a total of $535 million to customers who were account holders in 2018 or 2019

Hydro-Québec Bill 34 Refund issues $535M customer credits tied to electricity rates, consumption-based rebates, and variance accounts, averaging $60 per account and 2.49% of 2018-2019 usage, via bill credits or mailed cheques.

 

Key Points

A $535M credit refunding 2.49% of 2018-2019 usage to Hydro-Québec customers via bill credits or cheques.

✅ Applies to 2018-2019 consumption; average refund about $60.

✅ Current customers get bill credits; former customers receive cheques.

✅ Refund equals 2.49% of usage from variance accounts under prior rates.

 

Following the adoption of Bill 34 in December 2019, a total amount of $535 million will be refunded to customers who were Hydro-Québec account holders in 2018 or 2019. This amount was accumulated in variance accounts required under the previous rate system between January 1, 2018, and December 31, 2019.

If you are still a Hydro-Québec customer, a credit will be applied to your bill in the coming weeks, and improving billing layout clarity is a focus in some provinces as well. The amount will be indicated on your bill.

An average refund amount of $60. The refund amount is calculated based on the quantity of electricity that each customer consumed in 2018 and 2019. The refund will correspond to 2,49% of each customer's consumption between January 1, 2018, and December 31, 2019, for an average of approximately $60, while Ontario hydro rates are set to increase on Nov. 1.

The following chart provides an overview of the refund amount based on the type of home. Naturally, the number of occupants, electricity use habits and features of the home, such as insulation and energy efficiency, may have a significant impact on the amount of the refund, and in other provinces, oversight debates continue following a BC Hydro fund surplus revelation.

What if you were an account holder in 2018 or 2019 but you are no longer a Hydro-Québec customer?
People who were account holders in 2018 or 2019, but who are no longer Hydro-Québec customers will receive their credit by cheque, a lump sum credit approach seen elsewhere.

To receive their cheque, these people must get in touch to update their address in one of the following ways:  

If they have a Hydro-Québec Customer Space and remember their access code, they can update their profile.

Anyone without a Customer Space or who doesn't remember their access code can fill out the Request for a credit form at the following address: www.hydroquebec.com/credit in which they can indicate the address where they wish to receive their cheque, where applicable.

Those who cannot send us their address online can call 514 385-7252 or 1 888 385-7252 to give it to a customer services representative, as utilities like Hydro One have moved to reconnect customers in some cases. Note that the process will take longer on the phone, especially if the call volume is high.

UPDATE: Hydro-Québec will be returning an additional $35 million to customers under the adoption of Bill 34, amid overcharging allegations reported elsewhere.

Energy Minister Jonatan Julien announced on Tuesday that the public utility will be refunding a total of $535 million to customers between January and April.

The legislation, which was passed in December, allows the Quebec government to take control of the rates charged for electricity in the province, including decisions on whether to seek a rate hike next year under the new framework.

 

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COVID-19 crisis shows need to keep electricity options open, says Birol

Electricity Security and Firm Capacity underpin reliable supply, balancing variable renewables with grid flexibility via gas plants, nuclear power, hydropower, battery storage, and demand response, safeguarding telework, e-commerce, and critical healthcare operations.

 

Key Points

Ability to meet demand by combining firm generation and flexible resources, keeping grids stable as renewables grow.

✅ Balances variable renewables with dispatchable generation

✅ Rewards flexibility via capacity markets and ancillary services

✅ Enhances grid stability for critical loads during low demand

 

The huge disruption caused by the coronavirus crisis, and the low-carbon electricity lessons drawn from it, has highlighted how much modern societies rely on electricity and how firm capacity, such as that provided by nuclear power, is a crucial element in ensuring supply, International Energy Agency (IEA) Executive Director Fatih Birol said.

In a commentary posted on LinkedIn, Birol said: "The coronavirus crisis reminds us of electricity's indispensable role in our lives. It's also providing insights into how that role is set to expand and evolve in the years and decades ahead."

Reliable electricity supply is crucial for teleworking, e-commerce, operating ventilators and other medical equipment, among all its other uses, he said, adding that the hundreds of millions of people who live without any access to electricity are far more vulnerable to disease and other dangers.

"Although new forms of short-term flexibility such as battery storage are on the rise, and initiatives like UK home virtual power plants are emerging, most electricity systems rely on natural gas power plants - which can quickly ramp generation up or down at short notice - to provide flexibility, underlining the critical role of gas in clean energy transitions," Birol said.

"Today, most gas power plants lose money if they are used only from time to time to help the system adjust to shifts in demand. The lower levels of electricity demand during the current crisis are adding to these pressures. Hydropower, an often forgotten workhorse of electricity generation, remains an essential source of flexibility.

"Firm capacity, including nuclear power in countries that have chosen to retain it as an option, is a crucial element in ensuring a secure electricity supply even as soaring electricity and coal use complicate transitions. Policy makers need to design markets that reward different sources for their contributions to electricity security, which can enable them to establish viable business models."

In most economies that have taken strong confinement measures in response to the coronavirus - and for which the IEA has available data - electricity demand has declined by around 15%, largely as a result of factories and businesses halting operations, and in New York City load patterns were notably reshaped during lockdowns. If electricity demand falls quickly while weather conditions remain the same, the share of variable renewables like wind and solar can become higher than normal, and low-emissions sources are set to cover almost all near-term growth.

"With weaker electricity demand, power generation capacity is abundant. However, electricity system operators have to constantly balance demand and supply in real time. People typically think of power outages as happening when surging electricity demand overwhelms supply. But in fact, some of the most high-profile blackouts in recent times took place during periods of low demand," Birol said.

"When electricity from wind and solar is satisfying the majority of demand, and renewables poised to eclipse coal by 2025 are reshaping the mix, systems need to maintain flexibility in order to be able to ramp up other sources of generation quickly when the pattern of supply shifts, such as when the sun sets. A very high share of wind and solar in a given moment also makes the maintenance of grid stability more challenging."

 

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Electricity Prices Surge to Record as Europe Struggles to Keep Lights on

France Electricity Crisis drives record power prices as nuclear outages squeeze supply, forcing energy imports, fuel oil and coal generation, amid gas market shocks, weak wind output, and freezing weather straining the grid.

 

Key Points

A French power shortfall from nuclear outages, record prices, heavy imports, and oil-fired backup amid cold weather.

✅ EDF halted reactors; 10% capacity offline, 30% by January

✅ Imports surge; fuel oil and coal units dispatched

✅ Prices spike as gas reverses flow and wind output drops

 

Electricity prices surged to a fresh record as France scrambled to keep its lights on, sucking up supplies from the rest of Europe.

France, usually an exporter of power, is boosting electricity imports and even burning fuel oil, and has at times limited nuclear output due to high river temperatures during heatwaves. The crunch comes after Electricite de France SA said it would halt four reactors accounting for 10% of the nation’s nuclear capacity, straining power grids already facing cold weather. Six oil-fired units were turned on in France on Tuesday morning, according to a filing with Entsoe.

“It’s illustrating how severe it is when they’re actually starting to burn fuel oil and importing from all these countries,” said Fabian Ronningen, an analyst at Rystad Energy. The unexpected plant maintenance “is reflected in the market prices,” he said

Europe is facing an energy crisis, with utilities relying on coal and oil. Almost 30% of France’s nuclear capacity will be offline at the beginning of January, leaving the energy market at the mercy of the weather. To make matters worse, Germany is closing almost half of its nuclear capacity before the end of the year, as Europe loses nuclear power just when it really needs energy.

German power for delivery next year surged 10% to 278.50 euros a megawatt-hour, while the French contract for January added 9.5% to a record 700.60 euros. Prices also gained, under Europe’s marginal pricing system, as gas jumped after shipments from Russia via a key pipeline reversed direction, flowing eastward toward Poland instead.

Neighboring countries are boosting their exports to France this week to cover for lost nuclear output, with imports from Germany rising to highest level in at least four years. In the U.K., four coal power units were operating on Tuesday with as much as 1.5 gigawatts of hourly output being sent across the channel. 

The power crisis is so severe that the French government has asked EDF to restart some nuclear reactors earlier than planned amid outage risks for nuclear-powered France. Ecology Minister Barbara Pompili said last weekend that, in addition to the early reactor restarts and past river-temperature limits, the country had contracts with some companies in which they agreed to cut production during peak demand hours in exchange for payments from the government.

Higher energy prices threaten to derail Europe’s economic recovery just as the coronavirus omicron variety is spreading. Trafigura Group’s Nyrstar will pause production at its zinc smelter in France in the first week of January because of rising electricity prices. Norwegian fertilizer producer Yara International, which curbed output earlier this year, said it would continue to monitor the situation closely and curtail production where necessary.

Freezing weather this week is also sending short-term power prices surging as renewables can’t keep up, even though wind and solar overtook gas in the EU last year. German wind output plunged to a five-week low on Tuesday.

 

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Germany shuts down its last three nuclear power plants

Germany Nuclear Phase-Out ends power generation from reactors, prioritizing energy security, renewables, and emissions goals amid the Ukraine war, natural gas shortages, decommissioning plans, and climate change debates across Europe and the national power grid.

 

Key Points

Germany Nuclear Phase-Out ends reactors, shifting to renewables to balance energy security, emissions, climate goals.

✅ Three reactors closed: Emsland, Isar II, Neckarwestheim II

✅ Pivot to renewables, efficiency, and grid resilience

✅ Continued roles in fuel fabrication and decommissioning

 

Germany is no longer producing any electricity from nuclear power plants, a move widely seen as turning its back on nuclear for good.

Closures of the Emsland, Isar II, and Neckarwestheim II nuclear plants in Germany were expected. The country announced plans to phase out nuclear power in 2011. However, in the fall of 2022, with the Ukraine war constraining access to energy, especially in Europe, Germany decided to extend nuclear power operations for an additional few months to bolster supplies.

“This was a highly anticipated action. The German government extended the lifetimes of these plants for a few months but never planned beyond that,” David Victor, a professor of innovation and public policy at UC San Diego, said.

Responses to the closures ranged from aghast that Germany would shut down a clean source of energy production, especially as Europe is losing nuclear power just when it really needs energy. In contrast, the global response to anthropogenic climate change continues to be insufficient to celebratory that the country will avoid any nuclear accidents like those that have happened in other parts of the world.

A collection of esteemed scientists, including two Nobel laureates and professors from MIT and Columbia, made a last-minute plea in an open letter published on April 14 on the nuclear advocacy group’s website, RePlaneteers, to keep the reactors operating, reviving questions about a resurgence of nuclear energy in Germany today.

“Given the threat that climate change poses to life on our planet and the obvious energy crisis in which Germany and Europe find themselves due to the unavailability of Russian natural gas, we call on you to continue operating the last remaining German nuclear power plants,” the letter states.

The open letter states that the Emsland, Isar II, and Neckarwestheim II facilities provided more than 10 million German households with electricity, even as some officials argued that nuclear would do little to solve the gas issue then. That’s a quarter of the population.

“This is hugely disappointing, when a secure low carbon 24/7 source of energy such as nuclear was available and could have continued operation for another 40 years,” Henry Preston, spokesperson for the World Nuclear Association. “Germany’s nuclear industry has been world-class. All three reactors shut down at the weekend performed extremely well.”

Despite the shutdown, some segments of nuclear industrial processes will continue to operate. “Germany’s nuclear sector will continue to be first class in the wider nuclear supply chain in areas such as fuel fabrication and decommissioning,” Preston said.

While the open letter did not succeed in keeping the nuclear reactors open, it does underscore a crucial reason why nuclear power has been part of global energy conversations recently, with some arguing it is a needed option for climate policy after a generational lull in the construction of nuclear power plants: climate change.

Generating electricity with nuclear reactors does not create any greenhouse gases. And as global climate change response efforts continue to fall short of emission targets, atomic energy is getting renewed consideration, and Germany has even considered a U-turn on its phaseout amid renewed debate.

 

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