Some Coal Power Plants Produce More Than Fair Share of Mercury Emissions

By The Mercury


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Our nationÂ’s coal-fired power plants are increasingly being retrofitted with technologies to mitigate the output of various forms of pollution, but a number of bad apples do continue to cause more than their fair share of mercury emissions.

This past March the Environmental Defense Fund, a leading nonprofit, released a report showing that the top 25 emitters of mercury, a potent neurotoxin and a nasty by-product of coal-fired electricity generation, contribute only 8 percent of the U.S. electric supply. At the same time, these power plants, which have failed to install readily available pollution controls already widely in use by other plants, account for nearly a third of all mercury emissions by the American electricity sector overall.

The report, “Mercury Alert: Cleaning up Coal Plants for Healthier Lives,” factors in emissions of mercury at power plants across the country in 2009. According to EDF, 20 of the top 25 mercury emitters are located within 50-100 miles of some of the largest metropolitan areas in the nation, including Chicago, Dallas, Houston, Atlanta, Minneapolis, Detroit, Pittsburgh, Cleveland, St. Louis and Austin. EDF found that Texas produces the most pollution from coal-fired electricity generation of all the U.S. states.

Besides listing the worst mercury polluters, the report also details recent cases of mercury contamination and fish consumption advisories across the country, as well as reported new installations of mercury controls and recently enacted state regulations driving their implementation.

The release of the report was timed to coincide with the announcement by the U.S. Environmental Protection Agency of more stringent rules regarding emissions of mercury and other air pollutants such as arsenic, dioxin and acid gases from individual power plants. EDF hopes that the report will bolster public support for the federal government to crack down on any plants that continue to buck the trend toward cleaner operations.

“There are widely available, cost-effective and tested technologies to reduce mercury pollution from power plants by more than 90 percent,” reports EDF. Currently only 17 U.S. states regulate mercury air emissions, but the upcoming EPA rule will force plants even in unregulated states to clean up their acts.

Mercury pollution is an ongoing problem around the world. Exposure to mercury in the environment has been linked to a variety of reproductive, cardiovascular and other human health problems. Airborne mercury from electricity plants usually finds its way into waterways and eventually the ocean, where it is taken up by successively larger marine life as it works its way up the food chain. The top ocean predators such as tuna and swordfish contain relatively large amounts of mercury in their fatty tissue as a result of eating smaller fish which have in turn eaten even smaller forms of marine life.

Consumers can limit their mercury intake by minimizing consumption of these larger fish including albacore canned tuna, but the problem will linger long into the future even if we start to reign in mercury pollution domestically, especially because the cleaner technologies being implemented here may take decades to find their way to power plants in poor and developing countries.

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Alberta Introduces New Electricity Rules

Alberta Rate of Last Resort streamlines electricity regulations to stabilize the default rate, curb price volatility, and protect rural communities, low-income households, and seniors while preserving competition in the province's energy market.

 

Key Points

Alberta's Rate of Last Resort sets biennial default electricity prices, curbing volatility and protecting customers.

✅ Biennial default rate to limit price spikes

✅ Focus on rural, senior, and low-income customers

✅ Encourages competitive contracts and market stability

 

The Alberta government is overhauling its electricity regulations as part of a market overhaul aimed at reducing spikes in electricity prices for consumers and businesses. The new rules, set to be introduced this spring, are intended to stabilize the default electricity rate paid by many Albertans.


Background on the Rate of Last Resort

Albertans currently have the option to sign up for competitive contracts with electricity providers. These contracts can sometimes offer lower rates than the default electricity rate, officially known as the Regulated Rate Option (RRO). However, these competitive rates can fluctuate significantly. Currently, those unable to secure these contracts or those who are on the default rate are experiencing rising electricity prices and high levels of price volatility.

To address this, the Alberta government is renaming the default rate as the Rate of Last Resort designation (RoLR) under the new framework. This aims to reduce the sense of security that some consumers might associate with the current name, which the government feels is misleading.


Key Changes Under New Regulations

The new regulations, which include proposed market changes that affect pricing, focus on:

  • Price Stabilization: Default electricity rates will be set every two years for each utility provider, providing greater predictability by enabling a consumer price cap and reducing the potential for extreme price swings.
  • Rural and Underserved Communities: The changes are intended to particularly benefit rural Albertans and those on the default rate, including low-income individuals and seniors. These groups often lack access to the competitive rates offered by some providers and have been disproportionately affected by recent price increases.
  • Promoting Economic Stability: The goal is to lower the cost of utilities for all Albertans, leading to overall lower costs of living and doing business. The government anticipates these changes will create a more attractive environment for investment and job creation.


Opposition Views

Critics argue that limiting the flexibility of prices for the default electricity rate could interfere with market dynamics and stifle market competition among providers. Some worry it could ultimately lead to higher prices in the long term. Others advocate directly subsidizing low-income households rather than introducing broad price controls.


Balancing Affordability and the Market

The Alberta government maintains that the proposed changes will strike a balance between ensuring affordable electricity for vulnerable Albertans and preserving a competitive energy market. Provincial officials emphasize that the new regulations should not deter consumers from seeking out competitive rates if they choose to.


The Path Ahead

The new electricity regulations are part of the Alberta government's broader Affordable Utilities Program, alongside electricity policy changes across the province. The legislation is expected to be introduced and debated in the provincial legislature this spring with the potential of coming into effect later in the year. Experts expect these changes will significantly impact the Alberta electricity market and ignite further discussion about how best to manage rising utility costs for consumers and businesses.

 

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CALIFORNIA: Why your electricity prices are soaring

California Electricity Prices are surging across PG&E, SCE, and SDG&E territories, driven by fixed grid costs, wildfire mitigation, CARE subsidies, and Net Energy Metering, burdening low-income renters and increasing statewide utility debt, CPUC reports show.

 

Key Points

High rates driven by fixed grid costs and policies, burdening low-income customers across PG&E, SCE, and SDG&E.

✅ Fixed costs: transmission, distribution, wildfire mitigation

✅ Solar NEM shifts grid costs onto remaining ratepayers

✅ CPUC, CARE, LIHEAP aim to relieve rising utility debt

 

California's electricity prices are among the highest in the country, new research says, and those costs are falling disproportionately on a customer base that's already struggling to pay their bills.

PG&E customers pay about 80 percent more per kilowatt-hour than the national average, according to a study by the energy institute at UC Berkeley's Haas Business School with the nonprofit think tank Next 10. The study analyzed the rates of the state's three largest investor-owned utilities and found that Southern California Edison charged 45 percent more than the national average, while San Diego Gas & Electric charged double. Even low-income residents enrolled in the California Alternate Rates for Energy program paid more than the average American.

"California's retail prices are out of line with utilities across the country," said UC Berkeley assistant professor and study co-author Meredith Fowlie, citing Hawaii and some New England states among the outliers with even higher rates. "And they're increasing, as regulators face calls for action across the state."


So why are prices so high?
One reason is that California's size and geography inflate the "fixed" costs of operating its electric system, even as the state considers revamping electricity rates to clean the grid in parallel, which include maintenance, generation, transmission, and distribution as well as public programs like CARE and wildfire mitigation, according to the study. Those costs don't change based on how much electricity residents consume, yet between 66 and 77 percent of Californians' electricity bills are used to offset the costs of those programs, the study found.

These are legitimate expenses, Fowlie said. However, because lower-income residents use only moderately less electricity than higher income households, they end up with a disproportionate share of the burden, according to the study. And while the bills of older, wealthier Californians continue to decrease as they adopt cost-efficient alternatives like the state's Net Energy Metering solar program and the resulting solar power cost shift dynamic, costs will keep rising for a shrinking customer base composed mostly of low- and middle-income renters who still use electricity as their main energy source.

"When households adopt solar, they're not paying their fair share," Fowlie said. While solar users generate power that decreases their bills, they still rely on the state's electric grid for much of their power consumption - without paying for its fixed costs like others do.

"As this continues it's going to make electricity even more unaffordable," said F. Noel Perry, founder of Next 10, which funds nonpartisan research on the economy and environment.

PG&E this month raised its electricity rates 3.7 percent, amounting to a $5.01 a month increase for the average residential customer, who now pays $138.85 a month for electricity. It was the second increase this year, as regulators consider major changes to electric bills statewide, said Mark Toney, executive director of The Utility Reform Network, who noted that higher rates are particularly difficult for those who have lost their jobs in the pandemic. The California Public Utilities Commission last year approved a PG&E plan for more incremental increases through Dec. 31, 2022.

PG&E spokesperson Kristi Jourdan said in an email statement that the company was committed to keeping prices as low as possible as the state weighs income-based flat-fee utility bills proposals, and that although some programs are meant to be subsidized through rates, "in other cases, given that some customers have greater access to energy alternatives, the remaining customers - often those with limited means - are left paying unintended subsidies."

The costs quickly became overwhelming for Fretea Sylver, who rents a small house in Castro Valley and lost much of her work as the owner of a small woodwork business early in the pandemic. "They're little tiny changes but they accumulate. You turn around and you're like wait a second, why is my bill $20 more?," Sylver said. "And you have to pay it, no matter what."

Many more are unable to pay. Between February and December of last year, Californians accumulated more than $650 million in late payments from their utility providers, according to an analysis by the CPUC. In 2019, utility debt fell $71,646,869 from the prior year.

Sylver, who was on unemployment for 10 months last year, accumulated over $600 in unpaid PG&E bills. "We sort of went into a bit of debt, having to use credit cards and loans to sustain what we had to pay for. We're trying to catch up," Sylver said. The family received some help from the federal Low-Income Home Energy Assistance Program, which provides up to $1,000 to those who are late on their utility bills.

The study identified improvements to make California's power grid more equitable, such as income-based fixed electricity charges for the grid's cost that are based on income. Republican state senators this week called on the state to use federal relief money to forgive the billions Californians owe in utility debt, even as some lawmakers move to overturn income-based utility charges amid ongoing debate. Californians are currently protected by a statewide moratorium on disconnection for nonpayment of electricity bills through June 30. The CPUC this month began taking public input on the issue of how to grant some relief to those who have fallen behind on their utility bills.

This article is part of the California Divide, a collaboration among newsrooms examining income inequality and economic survival in California.

 

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Costa Rica hits record electricity generation from 99% renewable sources

Costa Rica Renewable Energy Record highlights 99.99% clean power in May 2019, driven by hydropower, wind, solar, geothermal, and biomass, enabling ICE REM electricity exports and reduced rates from optimized generation totaling 984.19 GWh.

 

Key Points

May 2019 benchmark: Costa Rica generated 99.99% of 984.19 GWh from renewables, shifting from imports to regional exports.

✅ 99.99% renewable share across hydro, wind, solar, geothermal, biomass

✅ 984.19 GWh generated; ICE suspended imports and exported via REM

✅ Geothermal output increased to offset dry-season hydropower variability

 

During the whole month of May 2019, Costa Rica generated a total of 984.19 gigawatt hours of electricity, the highest in the country’s history. What makes this feat even more impressive is the fact that 99.99% of this energy came from a portfolio of renewable sources such as hydropower, wind, biomass, solar, and geothermal.

With such a high generation rate, the state power company Instituto Costariccense de Electricidad (ICE) were able to suspend energy imports from the first week of May and shifted to exports, while U.S. renewable electricity surpassed coal in 2022 domestically. To date, the power company continues to sell electricity to the Regional Electricity Market (REM) which generates revenues and is likely to reduce local electricity rates, a trend echoed in places like Idaho where a vast majority of electricity comes from renewables.

The record-breaking power generation was made possible by optimization of the country’s renewable sources, much as U.S. wind capacity surpassed hydro capacity at the end of 2016 to reshape portfolios. As the period coincided with the tail end of the dry season, the geothermal quota had to be increased.

Costa Rica remains a leader in renewable power generation, whereas U.S. wind generation has become the most-used renewable source in recent years. In 2015, more than 98% of the country’s electrical generation came from renewable sources, while U.S. renewables hit a record 28% in April in one recent benchmark. Through the years, this figure has remained fairly constant despite dry bouts caused by the El Niño phenomenon, and U.S. solar generation also continued to rise.

 

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UK Anticipates a 16% Decrease in Energy Bills in April

UK Energy Price Cap Cut 2024 signals relief as wholesale gas prices fall; Ofgem price cap drops per Cornwall Insight, aided by LNG supply, mild winter, despite Red Sea tensions and Ukraine conflict impacts.

 

Key Points

A forecast cut to Great Britain's Ofgem price cap as wholesale gas falls, easing typical annual household bills in 2024.

✅ Cap falls from £1,928 to £1,620 in April 2024

✅ Forecast £1,497 in July, then about £1,541 from October

✅ Drivers: lower wholesale gas, LNG supply, mild winter

 

Households in Great Britain are set to experience a significant reduction in energy costs this spring, with bills projected to drop by over £300 annually. This decrease is primarily due to a decline in wholesale gas prices, offering some respite to those grappling with the cost of living crisis.

Cornwall Insight, a well-regarded industry analyst, predicts a 16% reduction in average bills from the previous quarter, potentially reaching the lowest levels since the onset of the Ukraine conflict.

The industry’s price cap, indicative of the average annual bill for a typical household, is expected to decrease from the current £1,928, set earlier this month, to £1,620 in April – a reduction of £308 and £40 less than previously forecasted in December, as ministers consider ending the gas-electricity price link to improve market resilience.

Concerns about escalating tensions in the Red Sea, where Houthi rebels have disrupted global shipping, initially led analysts to fear an increase in wholesale oil prices and subsequent impact on household energy costs.

Contrary to these concerns, oil prices have remained relatively stable, and European gas reserves have been higher than anticipated during a mild winter, with European gas prices returning to pre-Ukraine war levels since November.

Cornwall Insight anticipates that energy prices will continue to be comparatively low through 2024. They predict a further decline to £1,497 for a typical annual bill from July, followed by a slight increase to £1,541 starting in October.

This forecast is a welcome development for Britons who have been dealing with increased expenses across various sectors, from food to utilities, amidst persistently high inflation rates, with energy-driven EU inflation hitting lower-income households hardest across member states.

Energy bills saw a steep rise in 2021, which escalated further due to the Ukraine conflict in 2022, driving up wholesale gas prices. This surge prompted government intervention to subsidize bills, with the UK price cap estimated to cost around £89bn to the public purse, capping costs to a typical household at £2,500.

Cornwall Insight noted that the supply of liquified natural gas to Europe had not been as adversely affected by the Red Sea disruptions as initially feared. Moreover, the UK has been well-supplied with gas from the US, which has become a more significant supplier since the Ukraine war, even as US electricity prices have risen to multi-decade highs. Contributing factors also include lower gas prices in Asia, mild weather, and robust gas availability.

Craig Lowrey, a principal consultant at Cornwall Insight, remarked that concerns about Red Sea events driving up energy prices have not materialized, allowing households to expect a reduction in prices.

On Monday, the next-month wholesale gas price dropped by 4% to 65p a therm.

However, Lowrey cautioned that a complete return to pre-crisis energy bill levels remains unlikely due to ongoing market impacts from shifting away from Russian energy sources and persistent geopolitical tensions, as well as policy changes such as Britain’s Energy Security Bill shaping market reforms.

Richard Neudegg, director of regulation at Uswitch, welcomed the potential further reduction of the price cap in April. However, he pointed out that this offers little solace to households currently struggling with high winter energy costs during the winter. Neudegg urged Ofgem, the energy regulator, to prompt suppliers to reintroduce more competitive and affordable fixed-price deals.

 

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NT Power Penalized $75,000 for Delayed Disconnection Notices

NT Power OEB Compliance Penalty highlights a $75,000 fine for improper disconnection notices, 14-day rule violations, process oversight failures, refunds, LEAP support, and corrective training to strengthen consumer protection and regulatory adherence in Ontario areas.

 

Key Points

A $75,000 OEB fine to NT Power for improper disconnection notices; refunds, LEAP support, and improved compliance.

✅ $75k administrative monetary penalty; $25k LEAP donation; refunds

✅ 870 notices misdated; 14-day rule training implemented

✅ 10 disconnects reconnected; $100 goodwill credits

 

The Ontario Energy Board recently ruled against Newmarket-Tay Power Distribution Ltd. (NT Power), fining them $75,000 for failing to issue timely disconnection notices to 870 customers between April and August 2022. These notices did not comply with the Ontario Energy Board's distribution system code, similar to standards reaffirmed in the OEB decision on Hydro One rates earlier this year, which mandates a minimum 14-day notice period before disconnection.

Out of the affected customers, ten had their electricity services disconnected, and six were additionally charged reconnection fees. However, NT Power has since reconnected all disconnected customers and refunded the reconnection fees, as confirmed by the Ontario Energy Board.

In response to these issues, NT Power has voluntarily accepted an assurance of compliance. This agreement stipulates that NT Power will pay a $75,000 administrative monetary penalty. Furthermore, they will make an additional payment of $25,000 to the Salvation Army's Northridge Community Church, which administers the Low-income Energy Assistance Program (LEAP) within NT Power's service area, aligning with broader efforts to reduce costs for industry highlighted by Canadian Manufacturers & Exporters recently, according to the association.

This is not the first time NT Power has faced compliance issues in this regard. The utility company admitted that this incident marks the second instance in three years where they failed to adhere to their disconnection-related obligations as outlined in the code, and sector governance debates, including the Manitoba Hydro board debate, underscore how oversight remains a national focus.

In a statement to NewmarketToday, NT Power acknowledged a similar issue three years ago when they were alerted to problems with their disconnection process. They promptly made adjustments to align their in-house procedures with the requirements of the Ontario Energy Board. Unfortunately, they neglected to implement a secondary check, leading to disconnect notices being dated a few days too early.

Alex Braletic, NT Power's Vice President of Engineering and Operation, clarified that no customers were actually disconnected prematurely, and debates over paying for electricity in India illustrate how enforcement challenges differ globally, but the issued letters contained inaccuracies. He added that NT Power has since instituted additional verification procedures to prevent such errors from occurring again.

The Ontario Energy Board emphasized that NT Power has assured them that corrective measures have been taken to ensure that their staff involved in the disconnection process receive proper training and management oversight, and recent market reactions such as Hydro One shares falling after leadership changes underscore the importance of strong governance to guarantee compliance with regulatory requirements.

Brian Hewson, Vice President of Consumer Protection and Industry Performance at the Ontario Energy Board, stated, referencing earlier Ontario rate reductions for businesses that complemented consumer protections, "As a result of the actions we have taken and NT Power’s assurance that it is aware of its obligations and has taken steps to improve its processes, consumers will be better protected."

Braletic encouraged NT Power's customers who are facing difficulties paying their electricity bills to reach out to their customer service department or visit their website. He emphasized that various programs and services are available to provide relief for bills, and amid ongoing Toronto Hydro impersonation scams customers should contact NT Power directly. NT Power is committed to collaborating with customers proactively and connecting them with assistance to avoid serving them with disconnection notices.

Furthermore, NT Power plans to send a letter to the ten affected customers and provide each of them with a $100 bill credit as a goodwill gesture.

 

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Ontario First Nations urge government to intervene in 'urgently needed' electricity line

East-West Transmission Project Ontario connects Thunder Bay to Wawa, facing OEB bidding, Hydro One vs NextBridge, First Nations consultation, environmental assessment, Pukaskwa National Park route, and reliability needs for Northwestern Ontario industry and communities.

 

Key Points

A 450 km Thunder Bay-Wawa power line proposal facing OEB bidding, Hydro One competition, and First Nations consultation.

✅ Competing bids: Hydro One vs NextBridge under OEB rules

✅ First Nations cite duty to consult and environmental review gaps

✅ Route debate: Pukaskwa Park vs bypass; jobs and reliability at stake

 

Leaders of six First Nations are urging the Ontario government to "clean up" the bureaucratic process that determines who will build an "urgently needed" high-capacity power transmission line to service northern Ontario.

The proposed 450 kilometre East-West Transmission Project is set to stretch from Thunder Bay to Wawa, providing much-needed electricity to northern Ontario. NextBridge Infrastructure, in partnership with Bamkushwada Limited Partnership (BLP) — an entity the First Nations created in order to become co-owners and active participants in the economic development of the line — have been the main proponents of the project since 2012 and were awarded the right to construct.

In 2018, Hydro One appealed to the previous Liberal government with a proposal to build the transmission line with lower maintenance costs. On Dec. 20, the Ontario Energy Board (OEB) issued a decision that said it will issue the contract to construct the project to the company with the lowest bid, even as a Manitoba Hydro line delay followed a board recommendation in a comparable case.

The transmission regime in Ontario allows competing bids at the beginning of a project to designate a transmitter, and then again at the end of the project to award leave to construct.

As a result, the Hydro One was permitted to submit a competing bid, five years after it was first proposed. The chiefs of the six First Nations say that will delay the project by two years, impede their land and violate their rights. The former Liberal government under which the project was initiated "left the door open" for competition to enter this late in the construction, according to the community leaders.

"The former government created this mess and Hydro One has taken advantage of this loophole," Fort William First Nation Chief Peter Collins said in a Queen's Park news conference on Thursday. "Hydro One is an interloper coming in at the last minute, trying taking over the project and all the hard work that has been done, without doing the work it needs to do."

 

Mess will explode, says chief

According to Collins, the Ontario Energy Board is likely to choose Hydro One's late submission in February, "causing this mess to explode." The electricity and distribution utility has not completed any of the legal requirements demanded by a project of this magnitude, Collins said, including extensive consultations with First Nations, such as oral traditional evidence hearings that inform regulators, and thorough environment assessments. He speculated that by ignoring these two things, even though in B.C. Ottawa did not oppose a Site C work halt pending a treaty rights challenge, Hydro One's bid will be the lowest cost.

"Hydro One's interference is a big problem," said Collins. He was flanked by the leaders of the Pic Mobert First Nation, Opwaaganasiniing (also known as the Red Rock Indian Band), Michipicoten, Biigtigong Nishnaabeg — or Pic River First Nation — and Pays Plat First Nation.

Collins also highlighted that Hydro One's proposed route for the transmission line will go through Pukaskwa National Park on which there are Aboriginal title claims, and noted that an opponent of the Site C dam has been sharing concerns with northerners, underscoring the need for meaningful engagement. NextBridge's proposal, Collins said, will go around the park.

If Hydro One is awarded the construction project, at risk, too, are as many as 1,000 job opportunities in northern Ontario (including the Ring of Fire) that are expected from NextBridge's proposal, as well as the "many millions" in contracting opportunities for the communities, Collins said.

"That companies such as Hydro One can do this and dissolve all that has been developed by NextBridge and our [partnership] and all the opportunities we have created will signal to ... everyone in Ontario that Ontario's not open for business, at least fair business," Collins said.

 

Ontario Energy Minister 'disappointed' by OEB's decision

In an email statement to National Observer, Energy Minister Greg Rickford's press secretary said the government acknowledged the concerns of the First Nations leaders, and is "disappointed that the OEB continues to stall on this important project."

"The East-West Tie project is a priority for Ontario because it is needed to provide a reliable and adequate supply of electricity to northwestern Ontario to support economic growth," she wrote.

In October, Rickford wrote to the OEB outlining his expectation that a prompt decision would be made through an efficient and fair process.

Despite the minister’s request, the OEB delayed a decision on this project in December — as in B.C., a utilities watchdog has pressed for answers on Site C dam stability — pushing the service date back to at least 2021. In 2017, NextBridge said that, pending OEB approval, it would start construction in 2018, with completion scheduled for 2020.

Without the transmission line, the community faces a higher likelihood of power outages and less reliable electricity overall.

"Our government takes the duty to consult seriously and it is committed to ensuring that all Indigenous communities are properly consulted and kept informed regardless of the result of the OEB process," Rickford's office's statement said.

In a letter sent to Premier Doug Ford, Rickford and to Environment Minister Rod Phillips, all members of the Bamkushwada Limited Partnership said they will be compelled to appeal the OEB's decision if the right to construct is given to Hydro One.

The entire situation, they wrote in their letter, is "an undeniable mess" that requires government intervention.

"If the Ontario government can correct this looming outcome, it is incumbent on the Ontario government to do so," they wrote, urging the government to "take all legal means to prevent the OEB from rendering an unconstitutional and unjust decision."

"Our First Nations and the north have waited five long years for this transmission project," Collins said. "Enough is enough."

 

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