Renewables to be excluded from budget cuts

By Associated Press


Protective Relay Training - Basic

Our customized live online or in‑person group training can be delivered to your staff at your location.

  • Live Online
  • 12 hours Instructor-led
  • Group Training Available
Regular Price:
$699
Coupon Price:
$599
Reserve Your Seat Today
Colorado House Speaker Terrance Carroll likens lawmakers' work this session to sometimes-painful surgery.

"We're cutting past the bone. We're cutting bone marrow," Carroll, a Denver Democrat, said of the $1.5 billion gap in next fiscal year's $18 billion budget.

"Bone marrow is where the body gets immunity. You limit the body's ability to heal itself. But we have to go there."

As they begin their 120-day session, legislators will take a second look at the public schools budget, the state bureaucracy, and even tax credits that could help carry Colorado out of recession.

Gov. Bill Ritter has proposed a $260 million cut in funding for kindergarten through 12th-grade schools. He also wants to raise $312 million by charging sales tax on candy and soda and by eliminating or suspending a dozen tax breaks.

Senate President Brandon Shaffer, D-Longmont, said lawmakers could start by voting to rescind $110 million that they had set aside for schools. Lawmakers agreed last year to include the money for schools in the budget — but hold on to it to see how the economy, and state revenues fared after they adjourned.

Shaffer said he wants to find ways to increase jobs through retraining and requiring utilities to get more power from renewable energy. Right now, investor-owned utilities must obtain 20 percent of their power from renewable sources by 2020.

"The road out of this is an economic recovery and an economic recovery starts with a good job," he said.

Senate Minority Leader Josh Penry, R-Fruita, is introducing a bill to combine state agencies and offer financial incentives to school districts to cut costs. His bill would abolish the position of executive director of the Department of Local Affairs and give those responsibilities to the lieutenant governor, whose only real duty is overseeing Indian affairs.

"We cannot get our fiscal house in order without getting rid of the redundancy and excess in state government. This bill will do just that," Penry said.

Ritter told lawmakers he wants to eliminate 13 tax breaks and credits to balance this year's budget. Some lawmakers say there are 87 other tax breaks that can be considered, including conservation tax easements.

Under a plan Ritter submitted to legislators, some business-specific tax breaks would be eliminated or suspended, including a sales tax exemption on agricultural compounds and bull semen, worth $1.5 million a year.

Ritter's call to limit conservation easement credits for three years would raise $13 million annually.

House Minority Leader Mike May, R-Parker, said it makes no sense to offer tax breaks to farmers and ranchers not to build on their property because few people can afford to spend money on development in the current economy.

Environmentalists say the tax credit is one of the only meaningful tools available in Colorado to promote private land conservation and reduce the impact of population growth on habitat and species.

Ritter also plans to make promotion of renewable energy a key issue again this year. Environmentalists say that will help the economy.

"This session is about improving the lives of people across Colorado. Strengthening our renewable electricity standard is exactly what we need to create jobs in these tough economic times," said Pam Kiely of Environment Colorado.

Related News

Alberta's Path to Clean Electricity

Alberta Clean Electricity Regulations face federal mandates and provincial autonomy, balancing greenhouse gas cuts, net-zero 2050 goals, and renewable energy adoption across wind, solar, and hydro, while protecting jobs and economic stability in energy communities.

 

Key Points

Rules to cut power emissions, boost renewables, and align Alberta with federal net-zero goals under federal mandates.

✅ Phases out coal and curbs greenhouse gas emissions

✅ Expands wind, solar, and hydro to diversify the grid

✅ Balances provincial autonomy with national climate targets

 

In a recent development, Alberta finds itself at a crossroads between provincial autonomy and federal mandates concerning federal clean electricity regulations that shape long-term planning. The province, known for its significant oil and gas industry, faces increasing pressure to align its energy policies with federal climate goals set by Ottawa.

The federal government, under the leadership of Environment Minister Steven Guilbeault, has proposed regulations aimed at reducing greenhouse gas emissions and transitioning towards a cleaner energy future that prioritizes clean grids and batteries across provinces. These regulations are part of Canada's broader commitment to combat climate change and achieve net-zero emissions by 2050.

The Federal Perspective

From Ottawa's standpoint, stringent regulations on Alberta's electricity sector are necessary to meet national climate targets. This includes measures to phase out coal-fired power plants and increase reliance on renewable energy sources such as wind, solar, and hydroelectric power. Minister Guilbeault emphasizes the importance of these regulations in mitigating Canada's carbon footprint and fostering sustainable development.

Alberta's Response

In contrast, Alberta has historically championed provincial autonomy in energy policy, leveraging its vast fossil fuel resources to drive economic growth. The province remains cautious about federal interventions that could potentially disrupt its energy sector, a cornerstone of its economy, especially amid changes to how electricity is produced and paid for now under discussion.

Premier Jason Kenney has expressed concerns over federal overreach, and his influence over electricity policy has shaped proposals in the legislature. He emphasizes the province's efforts in adopting cleaner technologies while balancing economic stability and environmental sustainability.

The Balancing Act

The challenge lies in finding a middle ground between federal imperatives and provincial priorities, as interprovincial disputes like B.C.'s export-restriction challenge complicate coordination. Alberta acknowledges the need to diversify its energy portfolio and reduce emissions but insists on preserving its jurisdiction over energy policy. The province has already made strides in renewable energy development, including investing in wind and solar projects alongside traditional energy sources.

Economic Implications

For Alberta, the transition to cleaner electricity carries significant economic implications as the electricity market heads for a reshuffle in the coming years. It entails navigating the complexities of energy transition, ensuring job retention, and fostering innovation in sustainable technologies. Critics argue that abrupt federal regulations could exacerbate economic hardships, particularly in communities reliant on the fossil fuel industry.

Moving Forward

As discussions continue between Alberta and Ottawa, finding common ground, including consideration of recent market change proposals from the province, remains essential. Collaborative efforts are necessary to develop tailored solutions that accommodate both environmental responsibilities and economic realities. This includes exploring incentives for renewable energy investment, supporting energy sector workers in transitioning to new industries, and leveraging Alberta's expertise in energy innovation.

Conclusion

Alberta's journey towards clean electricity regulation exemplifies the delicate balance between regional autonomy and federal oversight in Canada's complex federal system. While tensions persist between provincial and federal priorities, both levels of government share a common commitment to addressing climate change and advancing sustainable energy solutions.

The outcome of these negotiations will not only shape Alberta's energy landscape but also influence Canada's overall progress towards a greener future. Finding equitable solutions that respect provincial autonomy while achieving national environmental goals remains paramount in navigating this evolving policy landscape.

 

Related News

View more

Hydropower Plants to Support Solar and Wind Energy

Solar-Wind-Water West Africa integrates hydropower with solar and wind to boost grid flexibility, clean electricity, and decarbonization, leveraging the West African Power Pool and climate data modeling reported in Nature Sustainability.

 

Key Points

A strategy using hydropower to balance solar and wind, enabling reliable, low-carbon electricity across West Africa.

✅ Hydropower dispatch covers solar and wind shortfalls.

✅ Regional interconnection via West African Power Pool.

✅ Cuts CO2 versus gas while limiting new dam projects.

 

Hydropower plants can support solar and wind power, rather unpredictable by nature, in a climate-friendly manner. A new study in the scientific journal Nature Sustainability has now mapped the potential for such "solar-wind-water" strategies for West Africa: an important region where the power sector is still under development, amid IEA investment needs for universal access, and where generation capacity and power grids will be greatly expanded in the coming years. "Countries in West Africa therefore now have the opportunity to plan this expansion according to strategies that rely on modern, climate-friendly energy generation," says Sebastian Sterl, energy and climate scientist at Vrije Universiteit Brussel and KU Leuven and lead author of the study. "A completely different situation from Europe, where power supply has been dependent on polluting power plants for many decades - which many countries now want to rid themselves of."

Solar and wind power generation is increasing worldwide and becoming cheaper and cheaper. This helps to keep climate targets in sight, but also poses challenges. For instance, critics often argue that these energy sources are too unpredictable and variable to be part of a reliable electricity mix on a large scale, though combining multiple resources can enhance project performance.

"Indeed, our electricity systems will have to become much more flexible if we are to feed large amounts of solar and wind power into the grid. Flexibility is currently mostly provided by gas power plants. Unfortunately, these cause a lot of CO2 emissions," says Sebastian Sterl, energy and climate expert at Vrije Universiteit Brussel (VUB) and KU Leuven. "But in many countries, hydropower plants can be a fossil fuel-free alternative to support solar and wind energy. After all, hydropower plants can be dispatched at times when insufficient solar and wind power is available."

The research team, composed of experts from VUB, KU Leuven, the International Renewable Energy Agency (IRENA), and Climate Analytics, designed a new computer model for their study, running on detailed water, weather and climate data. They used this model to investigate how renewable power sources in West Africa could be exploited as effectively as possible for a reliable power supply, even without large-scale storage, in line with World Bank support for wind in developing countries. All this without losing sight of the environmental impact of large hydropower plants.

"This is far from trivial to calculate," says Prof. Wim Thiery, climate scientist at the VUB, who was also involved in the study. "Hydroelectric power stations in West Africa depend on the monsoon; in the dry season they run on their reserves. Both sun and wind, as well as power requirements, have their own typical hourly, daily and seasonal patterns. Solar, wind and hydropower all vary from year to year and may be impacted by climate change, including projections that wind resources shift southward in coming years. In addition, their potential is spatially very unevenly distributed."

West African Power Pool

The study demonstrates that it will be particularly important to create a "West African Power Pool", a regional interconnection of national power grids to serve as a path to universal electricity access across the region. Countries with a tropical climate, such as Ghana and the Ivory Coast, typically have a lot of potential for hydropower and quite high solar radiation, but hardly any wind. The drier and more desert-like countries, such as Senegal and Niger, hardly have any opportunities for hydropower, but receive more sunlight and more wind. The potential for reliable, clean power generation based on solar and wind power, supported by flexibly dispatched hydropower, increases by more than 30% when countries can share their potential regionally, the researchers discovered.

All measures taken together would allow roughly 60% of the current electricity demand in West Africa to be met with complementary renewable sources, despite concerns about slow greening of Africa's electricity, of which roughly half would be solar and wind power and the other half hydropower - without the need for large-scale battery or other storage plants. According to the study, within a few years, the cost of solar and wind power generation in West Africa is also expected to drop to such an extent that the proposed solar-wind-water strategies will provide cheaper electricity than gas-fired power plants, which currently still account for more than half of all electricity supply in West Africa.

Better ecological footprint

Hydropower plants can have a considerable negative impact on local ecology. In many developing countries, piles of controversial plans for new hydropower plants have been proposed. The study can help to make future investments in hydropower more sustainable. "By using existing and planned hydropower plants as optimally as possible to massively support solar and wind energy, one can at the same time make certain new dams superfluous," says Sterl. "This way two birds can be caught with one stone. Simultaneously, one avoids CO2 emissions from gas-fired power stations and the environmental impact of hydropower overexploitation."

Global relevance

The methods developed for the study are easily transferable to other regions, and the research has worldwide relevance, as shown by a US 80% study on high variable renewable shares. Sterl: "Nearly all regions with a lot of hydropower, or hydropower potential, could use it to compensate shortfalls in solar and wind power." Various European countries, with Norway at the front, have shown increased interest in recent years to deploy their hydropower to support solar and wind power in EU countries. Exporting Norwegian hydropower during times when other countries undergo solar and wind power shortfalls, the European energy transition can be advanced.

 

Related News

View more

Renewable power developers discover more energy sources make better projects

Hybrid renewable energy projects integrate wind, solar, and battery storage to enhance grid reliability, reduce curtailment, and provide dispatchable power in markets like Alberta, leveraging photovoltaic tracking, overbuilt transformers, and improved storage economics.

 

Key Points

Hybrid renewable energy projects combine wind, solar, and storage to deliver reliable, dispatchable clean power.

✅ Combine wind, solar, and batteries for steady, dispatchable output

✅ Lower curtailment by using shared transformers and smart inverters

✅ Boost farm income via leases; diversify risk from oil and gas

 

Third-generation farmer James Praskach has been burned by the oil and gas sector and watched wicked weather pound his crops flat, but he is hoping a new kind of energy -- the renewable kind -- will pay dividends.

The 39-year-old is part of a landowner consortium that is hosting the sprawling 300-megawatt Blackspring Ridge wind power project in southeastern Alberta.

He receives regular lease payments from the $600-million project that came online in 2014, even though none of the 166 towering wind turbines that surround his land are actually on it.

His lease payments stand to rise, however, when and if the proposed 77-MW Vulcan Solar project, which won regulatory approval in 2016, is green-lighted by developer EDF Renewables Inc.

The panels would cover about 400 hectares of his family's land with nearly 300,000 photovoltaic solar panels in Alberta, installed on racks designed to follow the sun. It would stand in the way of traditional grain farming of the land, but that wouldn't have been a problem this year, Praskach says.

"This year we actually had a massive storm roll through. And we had 100 per cent hail damage on all of (the Vulcan Solar lands). We had canola, peas and barley on it this year," he said, adding the crop was covered by insurance.

Meanwhile, poor natural gas prices and a series of oilpatch financial failures mean rents aren't being paid for about half of the handful of gas wells on his land, showing how a province that is a powerhouse for both fossil and green energy can face volatility -- he's appealed to the Alberta surface Rights Board for compensation.

"(Solar power) would definitely add a level of security for our farming operations," said Praskach.

Hybrid power projects that combine energy sources are a growing trend as selling renewable energy gains traction across markets. Solar only works during the day and wind only when it is windy so combining the two -- potentially with battery storage or natural gas or biomass generation -- makes the power profile more reliable and predictable.

Globally, an oft-cited example is on El Hierro, the smallest of the Canary Islands, where wind power is used to pump water uphill to a reservoir in a volcanic crater so that it can be released to provide hydroelectric power when needed. At times, the project has provided 100 per cent of the tiny island's energy needs.

Improvements in technology such as improving solar and wind power and lower costs for storage mean it is being considered as a hybrid add-on for nearly all of its renewable power projects, said Dan Cunningham, manager of business development at Greengate Power Corp. of Calgary.

Grant Arnold, CEO of developer BluEarth Renewables, agreed.

"The barrier to date, I would say, has been cost of storage but that is changing rapidly," he said. "We feel that wind and storage or solar and storage will be a fundamental way we do business within five years. It's changing very, very rapidly and it's the product everybody wants."

Vulcan Solar was proposed after Blackspring Ridge came online, said David Warner, associate director of business development for EDF Renewables, which now co-owns the wind farm with Enbridge Inc.

"Blackspring actually had incremental capacity in the main power transformers," he said. "Essentially, it was capable of delivering more energy than Blackspring was producing. It was overbuilt."

Vulcan Solar has been sized to utilize the shortfall without producing so much energy that either will ever have to be constrained, he said. Much of the required environmental work has already been done for the wind farm.

Storage is being examined as a potential addition to the project but implementing it depends on the regulatory system. At present, Alberta's regulators are still working on how to permit and control what they call "dispatchable renewables and storage" systems.

EDF announced last spring it would proceed with the Arrow Canyon Solar Project in Nevada which is to combine 200 MW of solar with 75 MW of battery storage by 2022 -- the batteries are to soak up the sun's power in the morning and dispatch the electricity in the afternoon when Las Vegas casinos' air conditioning is most needed.

What is clear is that renewable energy will continue to grow, with Alberta renewable jobs expected to follow -- in a recent report, the International Energy Agency said global electricity capacity from renewables is set to rise by 50 per cent over the next five years, an increase equivalent to adding the current total power capacity of the United States.

The share of renewables is expected to rise from 26 per cent now to 30 per cent in 2024 but will remain well short of what is needed to meet long-term climate, air quality and energy access goals, it added.

 

Related News

View more

BC Hydro completes major milestone on Site C transmission line work

Site C 500 kV transmission lines strengthen the BC Hydro grid, linking the new substation and Peace Canyon via a 75 kilometre right-of-way to deliver clean energy, with 400 towers built and both circuits energized.

 

Key Points

High-voltage lines connecting Site C substation to the BC Hydro grid, delivering clean energy via Peace Canyon.

✅ Two 75 km circuits between Site C and Peace Canyon

✅ Connect new 500 kV substation to BC Hydro grid

✅ Over 400 towers built along existing right-of-way

 

The second and final 500 kilovolt, 75 kilometre transmission line on the Site C project, which has faced stability questions in recent years, has been completed and energized.

With this milestone, the work to connect the new Site C substation to the BC Hydro grid, amid treaty rights litigation that has at times shaped schedules, is complete. Once the Site C project begins generating electricity, much like when the Maritime Link first power flowed between Newfoundland and Nova Scotia, the transmission lines will help deliver clean energy to the rest of the province.

The two 75 kilometre transmission lines run along an existing right-of-way between Site C and the Peace Canyon generating station, a route that has seen community concerns from some northerners. The project’s first 500 kilovolt, 75 kilometre transmission line – along with the Site C substation – were both completed and energized in the fall of 2020.

BC Hydro awarded the Site C transmission line construction contract to Allteck Line Contractors Inc. (now Allteck Limited Partnership) in 2018. Since construction started on this part of the project in summer 2018, crews have built more than 400 towers and strung lines, even as other interties like the Manitoba-Minnesota line have faced scheduling uncertainty, over a total of 150 kilometres.

The two transmission lines are a major component of the Site C project, comparable to initiatives such as the New England Clean Power Link in scale, which also consists of the new 500 kilovolt substation and expanding the existing Peace Canyon 500 kilovolt gas-insulated switchgear to incorporate the two new 500 kilovolt transmission line terminals.

Work to complete three other 500 kilovolt transmission lines that will span one kilometre between the Site C generating station and Site C substation, similar to milestones on the Maritime Link project, is still underway. This work is expected to be complete in 2023.

 

Related News

View more

Nova Scotia Power delays start of controversial new charge for solar customers

Nova Scotia Power solar charge proposes an $8/kW monthly system access fee on net metering customers, citing grid costs. UARB review, carbon credits, rate hikes, and solar industry impacts fuel political and consumer backlash.

 

Key Points

A proposed $8/kW monthly grid access fee on net metered solar customers, delayed to Feb 1, 2023, pending UARB review.

✅ $8/kW monthly system access fee on net metering

✅ Delay to Feb 1, 2023 after industry and political pushback

✅ UARB review; debate over grid costs and carbon credits

 

Nova Scotia Power has pushed back by a year the start date of a proposed new charge for customers who generate electricity and sell it back to the grid, following days of concern from the solar industry and politicians worried that it will damage the sector.

The company applied to the Nova Scotia Utility and Review Board (UARB) last week for various changes, including a "system access charge" of $8 per kilowatt monthly on net metered installations, and the province cannot order the utility to lower rates under current law. The vast majority of the province's 4,100 net metering customers are residential customers with solar power, according to the application. 

The proposed charge would have come into effect Tuesday if approved, but Nova Scotia Power said in a news release Tuesday it will change the date in its filing from Feb. 1, 2022, to Feb. 1, 2023.

"We understand that the solar industry was taken off guard," utility CEO Peter Gregg said in an interview.

"There could have been an opportunity to have more conversations in advance."

Gregg said the utility will meet with members of the solar industry over the next year to work on finding solutions that support the sector's growth, while addressing what NSP sees as an inequity in the net metering system.

NSP recognized that customers who choose solar invest a significant amount and pay for the electricity they use, but they don't pay for costs associated with accessing the electrical grid when they need energy, such as on cold winter evenings when the sun is not shining.

"I know that's hit a nerve, but it doesn't take away the fact that it is an issue," Gregg said.

He said this is an issue utilities are navigating around North America, where seasonal rate designs have sparked consumer backlash in New Brunswick, and NSP is open to hearing ideas for other models of charges or fees.

The utility's suggested system access charge closely resembles one proposed in California, which has also raised major concerns from the solar industry and been criticized by the likes of Elon Musk, and has parallels to Massachusetts solar demand charges as well.

Although the "solar profile" of Nova Scotia and California is very different, with far more solar customers in that state, and in other provinces such as Saskatchewan, NDP criticism of 8% hikes has intensified affordability debates, Gregg said the fundamental issues are the same.

For those with a typical 10-kilowatt solar system, which generates around $1,800 of electricity a year, the new charge would mean those customers would be required to pay $960 back to NSP. That would roughly double the length of time it takes for those customers to pay off their investment for the panels.

David Brushett, chair of Solar Nova Scotia, said he relayed concerns from solar installers and others in the industry to Gregg on Monday. 

Brushett said the year delay is a positive first step, but he is still calling on the province to take a strong stance against the application, which has led to customers cancelling their panel installations and companies considering layoffs.

"There's still an urgency to this situation that hasn't been addressed, and we need to kind of protect the industry," he said Tuesday.

NSP's original application proposed exempting net metering customers who enrolled before Feb. 1, 2022, from the charge for 25 years after they sign up. But any benefit would be lost if those customers sold their home, and the exemption wouldn't extend to the new buyers, said Brushett.


Carbon offsets missing from equation: industry
Brushett said NSP "completely ignored" the fact that it's getting free carbon offset credits from homeowners who use solar energy under the provincial cap and trade program.

If the net metering system continues as is, NSP has said non-solar customers would pay about $55 million between now and 2030. That number assumes about 2,000 people sign up for net metering each year over the next nine years.

When asked whether those carbon emission credits were factored into the calculations for the proposed charge, Gregg said, "I don't believe in the current structure it is, but it's something that certainly we'd be open to hearing about."

Brushett said his group is finalizing a legal response to NSP's proposal and has already filed an official complaint against the company with the UARB.


Base charge on actual electrical output: customer
At least one shareholder in NSP parent company Emera is considering selling his shares in response to the application.

Joe Hood, a shareholder from Middle Sackville, said the proposed charge won't apply to his existing 11.16-kilowatt solar system, but if it did, it would cost him $1,071 a year.

"I am offended that a company I would invest in would do this to the solar industry in Nova Scotia," he said.

According to his meter, Hood said he pushed 9,600 kilowatt hours of solar electricity to the grid last year— some only for a brief period, and all of which was used by his home by the end of the year.

Under the proposed charge, someone with one solar panel who goes away on vacation in the summer would push all their electricity to the grid, and be charged far less than someone with 10 panels who has used all their own power and hasn't pushed anything.

"Nova Scotia Power's argument is that it's an issue with the grid. Well, then it should be based on what touches the grid," Hood said.

Far from actually making the system fair for everyone, Hood said this charge places solar only in the hands of the super-rich or NSP, with projects like its community solar gardens in Amherst, N.S.


Green Party suggests legislation update
Nova Scotia's Green Party also said Tuesday that Gregg's arguments of fairness are misleading, echoing earlier premier opposition to a 14% hike on rates.

The party is calling for an update to the Electricity Act that would "prevent penalizing any activity that helps Nova Scotia reach its emissions target," aligning with calls to make the electricity system more accountable to residents.

In its application, NSP has also asked to increase electricity rates for residential customers by at least 10 per cent over the next three years, amid debate that culminated in a 14% rate hike approval by regulators. 

The company wants to maintain its nine per cent rate of return.

NSP expects to earn $153 million this year, $192 million in 2023, and $213 million in 2024 from its rate of return. 

 

Related News

View more

Germany is first major economy to phase out coal and nuclear

Germany Coal Phase-Out 2038 advances the energy transition, curbing lignite emissions while scaling renewable energy, carbon pricing, and hydrogen storage amid a nuclear phase-out and regional just-transition funding for miners and communities.

 

Key Points

Germany's plan to end coal by 2038, fund regional transition, and scale renewable energy while exiting nuclear.

✅ Closes last coal plant by 2038; reviews may accelerate.

✅ 40b euros aid for lignite regions and workforce.

✅ Emphasizes renewables, hydrogen, carbon pricing reforms.

 

German lawmakers have finalized the country's long-awaited phase-out of coal as an energy source, backing a plan that environmental groups say isn't ambitious enough and free marketeers criticize as a waste of taxpayers' money.

Bills approved by both houses of parliament Friday envision shutting down the last coal-fired power plant by 2038 and spending some 40 billion euros ($45 billion) to help affected regions cope with the transition, which has been complicated by grid expansion woes in recent years.

The plan is part of Germany's `energy transition' - an effort to wean Europe's biggest economy off planet-warming fossil fuels and generate all of the country's considerable energy needs from renewable sources. Achieving that goal is made harder than in comparable countries such as France and Britain because of Germany's existing commitment to also phase out nuclear power entirely by the end of 2022.

"The days of coal are numbered in Germany," Environment Minister Svenja Schulze said. "Germany is the first industrialized country that leaves behind both nuclear energy and coal."

Greenpeace and other environmental groups have staged vocal protests against the plan, including by dropping a banner down the front of the Reichstag building Friday. They argue that the government's road map won't reduce Germany's greenhouse gas emissions fast enough to meet the targets set out in the Paris climate accord.

"Germany, the country that burns the greatest amount of lignite coal worldwide, will burden the next generation with 18 more years of carbon dioxide," Greenpeace Germany's executive director Martin Kaiser told The Associated Press.

Kaiser, who was part of a government-appointed expert commission, accused Chancellor Angela Merkel of making a "historic mistake," saying an end date for coal of 2030 would have sent a strong signal for European and global climate policy. Merkel has said she wants Europe to be the first continent to end its greenhouse gas emissions, by 2050, even as some in Berlin debate a possible nuclear U-turn to reach that goal faster.

Germany closed its last black coal mine in 2018, but it continues to import the fuel and extract its own reserves of lignite, a brownish coal that is abundant in the west and east of the country, and generates about a third of its electricity from coal in recent years. Officials warn that the loss of mining jobs could hurt those economically fragile regions, though efforts are already under way to turn the vast lignite mines into nature reserves and lakeside resorts.

Schulze, the environment minister, said there would be regular government reviews to examine whether the end date for coal can be brought forward, even as Berlin temporarily extended nuclear operations during the energy crisis. She noted that by the end of 2022, eight of the country's most polluting coal-fired plants will have already been closed.

Environmentalists have also criticized the large sums being offered to coal companies to shut down their plants, a complaint shared by libertarians such as Germany's opposition Free Democratic Party.

Katja Suding, a leading FDP lawmaker, said the government should have opted to expand existing emissions trading systems that put a price on carbon, thereby encouraging operators to shut down unprofitable coal plants.

Katja Suding, a leading FDP lawmaker, said the government should have opted to expand existing emissions trading systems, rather than banking on a nuclear option, that put a price on carbon, thereby encouraging operators to shut down unprofitable coal plants.

"You just have to make it so expensive that it's not profitable anymore to turn coal into electricity," she said.

This week, utility companies in Spain shut down seven of the country's 15 coal-fired power plants, saying they couldn't be operated at profit without government subsidies.

But the head of Germany's main miners' union, Michael Vassiliadis, welcomed the decision, calling it a "historic milestone." He urged the government to focus next on an expansion of renewable energy generation and the use of hydrogen as a clean alternative for storing and transporting energy in the future, amid arguments that nuclear won't fix the gas crunch in the near term.

 

Related News

View more

Sign Up for Electricity Forum’s Newsletter

Stay informed with our FREE Newsletter — get the latest news, breakthrough technologies, and expert insights, delivered straight to your inbox.

Electricity Today T&D Magazine Subscribe for FREE

Stay informed with the latest T&D policies and technologies.
  • Timely insights from industry experts
  • Practical solutions T&D engineers
  • Free access to every issue

Live Online & In-person Group Training

Advantages To Instructor-Led Training – Instructor-Led Course, Customized Training, Multiple Locations, Economical, CEU Credits, Course Discounts.

Request For Quotation

Whether you would prefer Live Online or In-Person instruction, our electrical training courses can be tailored to meet your company's specific requirements and delivered to your employees in one location or at various locations.