Coal dependency hits environment

By Newsday


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It takes five to 10 days for the pollution from China's coal-fired plants to make its way to the United States, like a slow-moving storm.

It shows up as mercury in the bass and trout caught in Oregon's Willamette River. It increases cloud cover and raises ozone levels. And along the way, it contributes to acid rain in Japan and South Korea and health problems everywhere from Taiyuan to the United States.

This is the dark side of the world's growing use of coal.

Cheap and abundant, coal has become the fuel of choice in much of the world, powering economic booms in China and India that have lifted millions of people out of poverty. Worldwide demand is projected to rise by about 60 percent through 2030 to 6.9 billion tons a year, most of it going to electrical power plants.

But the growth of coal-burning is also contributing to global warming, and is linked to environmental and health issues including acid rain and asthma. Air pollution kills more than 2 million people prematurely, according to the World Health Organization.

"Hands down, coal is by far the dirtiest pollutant," said Dan Jaffe, an atmospheric scientist at the University of Washington who has detected pollutants from Asia at monitoring sites on Mount Bachelor in Oregon and Cheeka Peak in Washington state. "It is a pretty bad fuel on all scores."

To understand the conflict over coal, look at Taiyuan and the surrounding Shanxi Province, the country's top coal-producing region - and one of its most polluted.

Almost overnight, coal has turned poor farmers in this city of 3 million people into Mercedes-driving millionaires, known derisively as "baofahu" or the quick rich. Flashy hotels display chunks of coal in the lobby, and sprawling malls advertise designer goods from Versace and Karl Lagerfeld. Real estate prices have doubled, residents say, and construction cranes fill the skyline.

A museum in Taiyuan celebrates all things coal. Amid photos of smiling miners, coal is presented as the foundation of the country's economic development, credited with making possible everything from the railroad to skin care products.

"Today, coal has penetrated into every aspect of people's lives," the museum says in one of many cheery pronouncements. "We can't live comfortably without coal."

Yet the cornstalks lining a highway outside the city 254 miles southwest of Beijing are covered in soot. The same soot settles on vegetables sold at the roadside, and the thick, acrid smoke blots out the morning sun. At its worst, the haze forces highway closures and flight delays.

With pressure to clean up major cities such as Shanghai and Beijing, particularly in the run-up to next year's Beijing Olympics, the central government is turning increasingly to provinces such as Shanxi to meet the country's power demands.

"They look at polluted places like Taiyuan and say it's so polluted there so it doesn't matter if they have another five power plants," said Ramanan Laxminarayan, a senior fellow at Resources For the Future, an American think tank that found links between air pollution and rising hospital admissions in Taiyuan.

"I visited these power plants and there is no concept of pollution control," he said. "They sort of had a laugh and asked, 'Why would you expect us to install pollution control equipment?'"

China is home to 20 of the world's 30 most polluted cities, according to a World Bank report.

Health costs related to air pollution total $68 billion a year, nearly 4 percent of the country's economic output, the report said. And acid rain has contaminated a third of the country, Sheng Huaren, a senior Chinese parliamentary official, said last year. It is said to destroy some $4 billion worth of crops every year.

"What we are facing in China is enormous economic growth, and... China is paying a price for it," said Henk Bekedam, the country representative for the World Health Organization. "Their growth is not sustainable from an environmental perspective. The good news is that they realize it. The bad news is they're dependent on coal as an energy source."

But the costs go far beyond China. The soot from power plants boosts global warming because coal emits almost twice as much carbon dioxide as natural gas. And researchers from Texas A&M University found that air pollution from China and India has increased in cloud cover and major Pacific Ocean storms by 20 percent to 50 percent over the past 20 years.

"We know dust from factories in China, India, Mexico and Africa does not simply disappear; the wind brings it here," said the U.S. Chamber of Commerce's Bill Kovacs.

Kovacs said overseas dust is adding to the number of counties that do not qualify for federal transportation funds because they are out of compliance with ozone standards. More than 100 counties do not meet the limit of 84 parts per billion. China alone contributes 3 to 5 parts per billion, estimates Daniel J. Jacob, professor of atmospheric chemistry and environmental engineering at Harvard University.

Mercury, a byproduct of some coal-mining, is another major concern. The potent toxin falls into waterways and shows up in fish. Asia's contribution to U.S. mercury levels has shot up over the past 20 years. Jacob estimated half of the mercury in the United States comes from overseas, especially China.

"It's a global problem and right now China is a source on the rise," he said. "If we want to bring down mercury levels in fish, then we have to go after emissions in East Asia."

A fifth of the mercury in the Willamette River came from China and other foreign sources, said Bruce K. Hope of the Oregon Department of Environmental Quality. Pregnant or nursing women who eat the fish put their babies at risk of neurological damage.

"It's frustrating to realize that part of your problem is someone else's behavior and you can't really go to them and say, 'Can you do something different?'" Hope said.

China has closed some polluting factories and says it will retire 50 gigawatts of inefficient power plants, or 8 percent of the total power grid, by 2010, according to the Pew Center for Global Climate Change. The government has also mandated that solar, wind, hydroelectric and other forms of renewable energy provide 10 percent of the nation's power by 2010, and ordered key industries to reduce energy consumption by 20 percent.

President Hu Jintao, in a speech to a key party congress last month, promised a cleanup. But China has fallen short of its national targets for using energy more efficiently, and coal remains a major energy source.

"Everyone knows coal is dirty, but there is no way that China can get rid of coal," the World Bank's Zhao Jianping said in Beijing. "It must rely on it for years to come, until humans can find a new magic solution."

Robert N. Schock, the director of studies for the World Energy Council, agreed that coal, cheap and abundant, will remain a crucial source of energy for many years and be crucial to improving living standards in developing countries.

"Twenty-five percent of the world's electric power is now generated by coal, and those plants are not likely to disappear overnight," Schock said. In Shanxi province, authorities have pledged to close 900 coal mines and dozens of makeshift factories that process coal for the steel industry, according to the official Xinhua News Agency. The Asian Development Bank is providing more than $200 million in loans to improve air quality in the province, through programs to shift to cleaner-burning natural gas for household heating and a demonstration project to capture methane, a greenhouse gas released in coal mining.

Taiyuan, dubbed the world's most polluted city in the 1990s, is no longer thought to be the worst, thanks to various efforts including phasing out coal-burning boilers. But the level of pollutants in the air remains five to 10 times higher than levels in New York or London. Residents say they see blue skies fewer than 120 days a year.

Australians Paul and Helen Douglas, who work for Evergreen in Taiyuan, an American social service agency, said their 21-month-old daughter Rose has been found in tests to have elevated lead levels. She has developed a chronic cough, Paul Douglas said, and the family will likely return to Australia before their contract ends if their daughter's toxin levels rise further.

"People say we are irresponsible and that we are making decisions that are injuring our children," he said of coming under fire from relatives and church members for staying in Taiyuan.

Taiyuan residents, though, shrug wearily when the talk turns to pollution, fearful that speaking out could get them in trouble. But when pressed, the complaints tumble forth and expose a community held hostage by the soot.

Residents seal their windows to keep out the dirty air. Parents are warned not to let their toddlers play outside, for fear of being covered in coal dust. Fruits and vegetables must be washed in detergent.

"I'm worried about my children," said a woman who lives in the shadow of a power plant and fertilizer factory. She would only give her surname, Zhang. "We worry about everything. If you get sick seriously, you will die."

Many complain of chronic sore throats, bronchitis, lung cancer and pulmonary fibrosis. One study, by researchers at Norway's Center for International Climate and Environmental Research, found Taiyuan's pollution increased death rates by 15 percent and chronic respiratory ailments by 40 to 50 percent.

"I feel terrible and I'm coughing all the time," said William Li, a retired engineer from Taiyuan. His father died of lung cancer and his son has tracheitis, an upper respiratory condition. "The coal, it produces electric power that we send to other provinces. But we are left with the pollution."

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Report: Solar ITC Extension Would Be ‘Devastating’ for US Wind Market

Solar ITC Impact on U.S. Wind frames how a 30% solar investment tax credit could undercut wind PTC economics, shift corporate procurement, and, without transmission and storage, slow onshore builds despite offshore wind momentum.

 

Key Points

It is how a solar ITC extension may curb U.S. wind growth absent PTC parity, transmission, storage, and offshore backing.

✅ ITC at 30% risks shifting corporate procurement to solar.

✅ Post-PTC wind faces grid, transmission, and curtailment headwinds.

✅ Offshore wind, storage pairing, TOU demand could offset.

 

The booming U.S. wind industry, amid a wind power surge, faces an uncertain future in the 2020s. Few factors are more important than the fate of the solar ITC.

An extension of the solar investment tax credit (ITC) at its 30 percent value would be “devastating” to the future U.S. wind market, according to a new Wood Mackenzie report.

The U.S. is on track to add a record 14.6 gigawatts of new wind capacity in 2020, despite Covid-19 impacts, and nearly 39 gigawatts during a three-year installation boom from 2019 to 2021, according to Wood Mackenzie’s 2019 North America Wind Power Outlook.

But the market’s trajectory begins to look highly uncertain from the early 2020s onward, and solar is one of the main reasons why.

Since the dawn of the modern American renewables market, the wind and solar sectors have largely been allies on the national stage, benefiting from many of the same favorable government plans and sharing big-picture goals. Until recently, wind and solar companies rarely found themselves in direct competition.

But the picture is changing as solar catches up to wind on cost and the grid penetration of renewables surges. What was once a vague alliance between the two fastest growing renewables technologies could morph into a serious rivalry.

While many project developers are now active in both sectors, including NextEra Energy Resources, Invenergy and EDF, the country’s thriving base of wind manufacturers could face tougher days ahead.

 

The ITC's inherent advantage

At this point, wind remains solar’s bigger sibling in many ways.

The U.S. has nearly 100 gigawatts of installed wind capacity today, compared to around 67 gigawatts of solar. With their substantially higher capacity factors, wind farms generated four times more power for the U.S. grid last year than utility-scale solar plants, for a combined wind-solar share of 8.2 percent, according to government figures, even as renewables are projected to reach one-fourth of U.S. electricity generation. (Distributed PV systems further add to solar’s contribution.)

But it's long been clear that wind would lose its edge at some point. The annual solar market now regularly tops wind. The cost of solar energy is falling more rapidly, and appears to have more runway for further reduction. Solar’s inherent generation pattern is more valuable in many markets, delivering power during peak-demand hours, while the wind often blows strongest at night.

 

And then there’s the matter of the solar ITC.

In 2015, both wind and solar secured historic multi-year extensions to their main federal subsidies. The extensions gave both industries the longest period of policy clarity they’ve ever enjoyed, setting in motion a tidal wave of installations set to crest over the next few years.

Even back in 2015, however, it was clear that solar got the better deal in Washington, D.C.

While the wind production tax credit (PTC) began phasing down for new projects almost immediately, solar developers were given until the end of 2019 to qualify projects for the full ITC.

And critically, while the wind PTC drops to nothing after its sunset, commercially owned solar projects will remain eligible for a 10 percent ITC forever, based on the existing legislation. Over time, that amounts to a huge advantage for solar.

In another twist, the solar industry is now openly fighting for an extension of the 30 percent ITC, while the wind industry seemingly remains cooler on the prospect of pushing for a similar prolongation — having said the current PTC extension would be the last.

 

Plenty of tailwinds, too

Wood Mackenzie's report catalogues multiple factors that could work for or against the wind market in the "uncharted" post-PTC years, many of them, including the Covid-19 crisis, beyond the industry’s direct control.

If things go well, annual installations could bounce back to near-record levels by 2027 after a mid-decade contraction, the report says. But if they go badly, installations could remain depressed at 4 gigawatts or below from 2022 through most of the coming decade, and that includes an anticipated uplift from the offshore market.

An extension of the solar ITC without additional wind support would “severely compound” the wind market’s struggle to rebound in the 2020s, the report says. The already-evident shift in corporate renewables procurement from wind to solar could intensify dramatically.

The other big challenge for wind in the 2020s is the lack of progress on transmission infrastructure that would connect potentially massive low-cost wind farms in interior states with bigger population centers. A hoped-for national infrastructure package that might address the issue has not materialized.

Even so, many in the wind business remain cautiously optimistic about the post-PTC years, with a wind jobs forecast bolstering sentiment, and developers continue to build out longer-term project pipelines.

Turbine technology continues to improve. And an extension of the solar ITC is far from assured.

Other factors that could work in wind’s favor in the years ahead include:

The nascent offshore sector, which despite lingering regulatory uncertainty at the federal level looks set to blossom into a multi-gigawatt annual market by the mid-2020s, in line with an offshore wind forecast that highlights substantial growth potential. Lobbying efforts for an offshore wind ITC extension are gearing up, offering a potential area for cooperation between wind and solar.

The potential linkage of policy support for energy storage to wind projects, building on the current linkage with solar.

Growing electric vehicle sales and a shift toward time-of-use retail electricity billing, which could boost power demand during off-peak hours when wind generation is strong.

The land-use advantages wind farms have over solar in some agricultural regions.

 

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Nova Scotia's last paper mill seeks new discount electricity rate

Nova Scotia Power Active Demand Control Tariff lets the utility direct Port Hawkesbury Paper load, enabling demand response, efficiency, and industrial electricity rates, while regulators assess impacts on ratepayers, grid reliability, mill viability, and savings.

 

Key Points

A four-year tariff letting the utility control the mill load for demand response, efficiency, and lower costs.

✅ Utility can increase or reduce daily consumption at the mill

✅ Projected savings of $10M annually for other ratepayers to 2023

✅ Regulators reviewing cost allocation, monitoring, and viability

 

Nova Scotia Power is scheduled to appear before government regulators Tuesday morning seeking approval for a unique discount rate for its largest customer.

Under the four-year plan, Nova Scotia Power would control the supply of electricity to Port Hawkesbury Paper, a move referenced in a grid operations report that urges changes, with the right to direct the company to increase or reduce daily consumption throughout the year.

The rate proposal is supported by the mill, which says it needs to lower its power bill to keep its operation viable.

The rate went into effect on Jan. 1 on a temporary basis, pending the outcome of a hearing this week before the Nova Scotia Utility and Review Board, amid broader calls for an independent body to lead electricity planning.

The mill accounts for 10 per cent of the provincial electricity load, even as a neighbouring utility pursues more Quebec power for the region, producing glossy paper used in magazines and catalogs.

Nova Scotia Power says controlling how much electricity the mill uses — and when — will allow it to operate the system much more efficiently, as it expands biomass generation initiatives, saving other customers $10 million a year until the rate expires in 2023.

Ceding control 'not an easy decision'
In its opening statement that was filed in advance, Port Hawkesbury Paper said ceding the control of its electrical supply to Nova Scotia Power was "not an easy decision" to make, but the company is confident the arrangement will work.

In September 2019, Nova Scotia Power and the mill jointly applied for an "extra large active demand control tariff," which would provide electricity to the mill for about $61 per megawatt hour, well below the full cost of generating the electricity.

The utility said "fully allocating costs" would result in "prices in excess of $80/MWh ... and [would] not [be] financially viable for the mill."

In its statement, Port Hawkesbury Paper said since the initial filing "there have been greater near term declines in market demand and pricing for PHP's product than was forecast at that time, continuing to put pressure on our business and further highlighting the need to maintain the balance provided for in the new tariff."

Consumer advocate sees 'advantage,' but will challenge
Bill Mahody represents Nova Scotia Power's 400,000 residential customers before the review board. He wants proof the mill will pay enough toward the cost of generating the electricity it uses, amid concerns over biomass use in the province today.

"We filed evidence, as have others involved in the proceeding, that would call into question whether or not the rate design is capturing all of those costs and that will be a significant issue before the board," Mahody said.

Still, he sees value in the proposal.

The proposed new rate went into effect on Jan. 1 on a temporary basis. (The Canadian Press)
"This proposed rate gives Nova Scotia Power the ability to control that sizable Port Hawkesbury Paper load to the advantage of other ratepayers, as the province pursues more wind and solar projects, because Nova Scotia Power would be reducing the costs that other ratepayers are going to face," he said.

Mahody is also calling for a mechanism to monitor whether the mill's position actually improves to the point where it could pay higher rates.

"An awful lot can change during a four-year period, with new tidal power projects underway, and I think the board ought to have the ability to check in on this and make sure that their preferential rate continues to be justified," he said.

Major employer
Port Hawkesbury Paper, owned by Stern Partners in Vancouver, has received discounted power rates since it bought the idled mill in 2012. But the "load retention tariff" as it was called, expired at the end of 2019.

Regulators have accepted Nova Scotia Power's argument that it would cost other customers more if the mill ceased to operate.

The mill said it spends between $235 million and $265 million annually, employing 330 people directly and supporting 500 other jobs indirectly.

The Nova Scotia government pledged $124 million in financial assistance as part of the reopening in 2012.

 

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Chester County Landfill Converts Methane to Renewable Gas

SECCRA Waga Energy RNG Partnership captures landfill methane with WAGABOX, upgrades biogas to pipeline-quality RNG, enables grid injection, and lowers greenhouse gas emissions, delivering sustainable energy to Chester County homes and businesses.

 

Key Points

A joint project converting landfill methane to RNG with WAGABOX, cutting emissions and supplying local heat.

✅ WAGABOX captures and purifies landfill gas to RNG

✅ Grid injection supplies energy for 4,000+ homes

✅ Cuts methane and greenhouse gas emissions significantly

 

In a significant environmental initiative, the Southeastern Chester County Refuse Authority (SECCRA) has partnered with French energy company Waga Energy to convert methane emissions from its landfill into renewable natural gas (RNG). This collaboration aims to reduce greenhouse gas emissions and provide sustainable energy to the local community, echoing energy efficiency projects in Quebec seen elsewhere.

Understanding the Issue

Landfills are a substantial source of methane emissions, accounting for over 14% of human-induced methane emissions, according to the U.S. Environmental Protection Agency. Methane is a potent greenhouse gas, and issues like SF6 in power equipment further boost warming, trapping more heat in the atmosphere than carbon dioxide, making its reduction crucial in the fight against climate change.

The SECCRA-Waga Energy Partnership

SECCRA, serving approximately 105,000 residents in Chester County, processes between 450 to 500 tons of waste daily. To mitigate methane emissions from its landfill, SECCRA has partnered with Waga Energy to install a WAGABOX unit—a technology designed to capture and convert landfill methane into RNG, while related efforts like electrified LNG in B.C. illustrate sector-wide decarbonization.

How the WAGABOX Technology Works

The WAGABOX system utilizes a proprietary process to extract methane from landfill gas, purify it, and inject it into the natural gas grid. This process not only reduces harmful emissions, as emerging carbon dioxide electricity generation concepts also aim to do, but also produces a renewable energy source that can be used to heat homes and power businesses.

Environmental and Community Benefits

By converting methane into RNG, the project significantly lowers greenhouse gas emissions, supported by DOE funding for carbon capture initiatives, contributing to climate change mitigation. Additionally, the RNG produced is expected to supply energy to heat over 4,000 homes, providing a sustainable energy source for the local community.

Broader Implications

This initiative aligns with international clean energy cooperation to reduce methane emissions from landfills. Similar projects have been implemented worldwide, demonstrating the effectiveness of converting landfill methane into renewable energy. For instance, Waga Energy has successfully deployed WAGABOX units at various landfills, showcasing the scalability and impact of this technology.

The collaboration between SECCRA and Waga Energy represents a proactive step toward environmental sustainability and energy innovation. By transforming landfill methane into renewable natural gas, the project not only addresses a significant source of greenhouse gas emissions as new EPA power plant rules on carbon capture advance parallel strategies, but also provides a clean energy alternative for the Chester County community.

 

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N.L. premier says Muskrat Falls costs are too great for optimism about benefits

Muskrat Falls financial impact highlights a hydro megaproject's cost overruns, rate mitigation challenges, and inquiry findings in Newfoundland and Labrador, with power exports, Churchill River generation, and subsea cables shaping long-term viability.

 

Key Points

It refers to the project's burden on provincial finances, driven by cost overruns, rate hikes, and debt risks.

✅ Costs rose to $12.7B from $6.2B; inquiry cites suppressed risks.

✅ Rate mitigation needed to offset power bill shocks.

✅ Exports via subsea cables may improve long-term viability.

 

Newfoundland and Labrador's premier says the Muskrat Falls hydro megaproject is currently too much of a massive financial burden for him to be optimistic about its long-term potential.

"I am probably one of the most optimistic people in this room," Liberal Premier Dwight Ball told the inquiry into the project's runaway cost and scheduling issues, echoing challenges at Manitoba Hydro that have raised similar concerns.

"I believe the future is optimistic for Newfoundland Labrador, of course I do. But I'm not going to sit here today and say we have an optimistic future because of the Muskrat Falls project."

Ball, who was re-elected on May 16, has been critical of the project since he was opposition leader around the time it was sanctioned by the former Tory government.

He said Friday that despite his criticism of the Labrador dam, which has seen costs essentially double to more than $12.7 billion, he didn't set out to celebrate a failed project.

He said he still wants to see Muskrat Falls succeed someday through power sales outside the province, but there are immediate challenges -- including mitigating power-rate hikes once the dam starts providing full power and addressing winter reliability risks for households.

"We were told the project would be $6.2 billion, we're at $12.7 (billion). We were never told this project would be nearly 30 per cent of the net debt of this province just six, seven years later," the premier said.

"I wanted this to be successful, and in the long term I still want it to be successful. But we have to deal with the next 10 years."

The nearly complete dam will harness Labrador's lower Churchill River to provide electricity to the province as well as Nova Scotia and potentially beyond through subsea cables, while the legacy of Churchill Falls continues to shape regional power arrangements.

Ball's testimony wraps up a crucial phase of hearings in the extensive public inquiry.

The inquiry has heard from dozens of witnesses, with current and former politicians, bureaucrats, executives and consultants, amid debates over Quebec's electricity ambitions in the region, shedding long-demanded light on what went on behind closed doors that made the project go sideways.

Some witnesses have suggested that estimates were intentionally suppressed, and many high-ranking officials, including former premiers, have denied seeing key information about risk.

On Thursday, Ball testified to his shock when he began to understand the true financial state of the project after he was elected premier in 2015.

On Friday, Ball said he has more faith in future of the offshore oil and gas industry, and emerging options like small nuclear reactors, for example, than a mismanaged project that has put immense pressure on residents already struggling to make ends meet.

After his testimony, Ball said he takes some responsibility for a missed opportunity to mitigate methylmercury risks downstream from the dam through capping the reservoir, in parallel with debates over biomass power in electricity generation, something he had committed to doing before it is fully flooded this summer.

Still to come is a third phase of hearings on future best practices for issues like managing large-scale projects and independent electricity planning, two public feedback sessions and closing submissions from lawyers.

The final report from the inquiry is due before Dec. 31.

 

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First US coal plant in years opens where no options exist

Alaska Coal-Fired CHP Plant opens near Usibelli mine, supplying electricity and district heat to UAF; remote location without gas pipelines, low wind and solar potential, and high heating demand shaped fuel choice.

 

Key Points

A 17 MW coal CHP at UAF producing power and campus heat, chosen for remoteness and lack of gas pipelines.

✅ 17 MW generator supplying electricity and district heat

✅ Near Usibelli mine; limited pipeline access shapes fuel

✅ Alternative options like LNG, wind, solar not cost-effective

 

One way to boost coal in the US: Find a spot near a mine with no access to oil or natural gas pipelines, where it’s not particularly windy and it’s dark much of the year.

That’s how the first coal-fired plant to open in the U.S. since 2015 bucked the trend in an industry that’s seen scores of facilities close in recent years. A 17-megawatt generator, built for $245 million, is set to open in April at the University of Alaska Fairbanks, just 100 miles from the state’s only coal mine.

“Geography really drove what options are available to us,” said Kari Burrell, the university’s vice chancellor for administrative services, in an interview. “We are not saying this is ideal by any means.”

The new plant is arriving as coal fuels about 25 percent of electrical generation in the U.S., down from 45 percent a decade earlier, even as some forecasts point to a near-term increase in coal-fired generation in 2021. A near-record 18 coal plants closed in 2018, and 14 more are expected to follow this year, according to BloombergNEF.

The biggest bright spot for U.S. coal miners recently has been exports to overseas power plants. At home, one of the few growth areas has been in pizza ovens.

There are a handful of other U.S. coal power projects that have been proposed, including plans to build an 850 megawatt facility in Georgia and an 895 megawatt plant in Kansas, even as a Minnesota utility reports declining coal returns across parts of its portfolio. But Ashley Burke, a spokeswoman for the National Mining Association, said she’s unaware of any U.S. plants actively under development besides the one in Alaska.

 

Future of power

“The future of power in the U.S. does not include coal,” Tessie Petion, an analyst for HSBC Holdings Plc, said in a research note, a view echoed by regions such as Alberta retiring coal power early in their transition.

Fairbanks sits on the banks of the Chena River, amid the vast subarctic forests in the heart of Alaska. The oil and gas fields of the state’s North slope are 500 miles north. The nearest major port is in Anchorage, 350 miles south.

The university’s new plant is a combined heat and power generator, which will create steam both to generate electricity and heat campus buildings. Before opting for coal, the school looked into using liquid natural gas, wind and solar, bio-mass and a host of other options, as new projects in Southeast Alaska seek lower electricity costs across the region. None of them penciled out, said Mike Ruckhaus, a senior project manager at the university.

The project, financed with university and state-municipal bonds, replaces a coal plant that went into service in 1964. University spokeswoman Marmian Grimes said it’s worth noting that the new plant will emit fewer emissions.

The coal will come from Usibelli Coal Mine Inc., a family-owned business that produces between 1.2 and 2 million tons per year from a mine along the Alaska railroad, according to the company’s website.

While any new plant is good news for coal miners, Clarksons Platou Securities Inc. analyst Jeremy Sussman said this one is "an isolated situation."

“We think the best producers can hope for domestically is a slow down in plant closures,” he said, even as jurisdictions like Alberta close their last coal plant entirely.

 

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Bruce Power cranking out more electricity after upgrade

Bruce Power Capacity Uprate boosts nuclear output through generator stator upgrades, turbine and transformer enhancements, and cooling pump improvements at Bruce A and B, unlocking megawatts and efficiency gains from legacy heavy water design capacity.

 

Key Points

Upgrades that raise Bruce Power capacity via stator, turbine, transformer, and cooling enhancements.

✅ Generator stator replacement increases electrical conversion efficiency

✅ Turbine and transformer upgrades enable higher MW output

✅ Cooling pump enhancements optimize plant thermal performance

 

Bruce Power’s Unit 3 nuclear reactor will squeeze out an extra 22 megawatts of electricity, thanks to upgrades during its recent planned outage for refurbishment.

Similar gains are anticipated at its three sister reactors at Bruce A generating station, which presents the opportunity for the biggest efficiency gains and broader economic benefits for Ontario, due to a design difference over Bruce B’s four reactors, Bruce Power spokesman John Peevers said.

Bruce A reactor efficiency gains stem mainly from the fact Bruce A’s non-nuclear side, including turbines and the generator, was sized at 88 per cent of the nuclear capacity, Peevers said, while early Bruce C exploration work advances.

This allowed 12 per cent of the energy, in the form of steam, to be used for heavy water production, which was discontinued at the plant years ago. Heavy water, or deuterium, is used to moderate the reactors.

That design difference left a potential excess capacity that Bruce Power is making use of through various non-nuclear enhancements. But the nuclear operator, which also made major PPE donations during the pandemic, will be looking at enhancements at Bruce B as well, Peevers said.

Bruce Power’s efficiency gain came from “technology advancements,” including a “generator-stator improvement project that was integral to the uprate,” and contributed to an operating record at the site, a Bruce Power news release said July 11.

Peevers said the stationary coils and the associated iron cores inside the generator are referred to as the stator. The stator acts as a conductor for the main generator current, while the turbine provides the mechanical torque on the shaft of the generator.

“Some of the other things we’re working on are transformer replacement and cooling pump enhancements, backed by recent manufacturing contracts, which also help efficiency and contribute to greater megawatt output,” Peevers said.

The added efficiency improvements raised the nuclear operator’s peak generating capacity to 6,430 MW, as projects like Pickering life extensions continue across Ontario.

 

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