Progress Energy plans paths for new lines

ISEM Price Volatility reflects Ireland-Northern Ireland grid balancing pressures, driven by dispatchable power shortages, day-ahead market dynamics, renewable shortfalls, and interconnector constraints, affecting intraday trading, operational reserves, and cross-border electricity flows.

Key Points

ISEM price volatility is Irish power price swings from grid balancing stress and limited dispatchable capacity.

✅ One-off spike linked to plant outage and low renewables

✅ Day-ahead market settling; intraday trading integration pending

✅ Interconnectors and reserves vital to manage adequacy

Irish grid-balancing prices soared to €3,774 ($4,284) per megawatt-hour last month amid growing concerns over dispatchable power capacity across Europe.

The price spike, triggered by an alert regarding generation losses, came only four months after Ireland and Northern Ireland launched an Integrated Single Electricity Market (ISEM) designed to make trading more competitive and improve power distribution across the island.

Evie Doherty, senior consultant for Ireland at Cornwall Insight, a U.K.-based energy consultancy, said significant price volatility was to be expected while ISEM is still settling down, aligning with broader 2019 grid edge trends seen across markets.

When the U.K. introduced a single market for Great Britain, called British Electricity Trading and Transmission Arrangements, in 2005, it took at least six months for volatility to subside, Doherty said.

In the case of ISEM, “it will take more time to ascertain the exact drivers behind the high prices,” she said. “We are being told that the day-ahead market is functioning as expected, but it will take time to really be able to draw conclusions on efficiency.”

Ireland and Northern Ireland have been operating with a single market “very successfully” since 2007, said Doherty. Although each jurisdiction has its own regulatory authority, they make joint decisions regarding the single market.

ISEM, launched in October 2018, was designed to help include Ireland and Northern Ireland day-ahead electricity prices in a market pricing system called the European Union Pan-European Hybrid Electricity Market Integration Algorithm.

In time, ISEM should also allow the Irish grids to participate in European intraday markets, and recent examples like Ukraine's grid connection underline the pace of integration efforts across Europe. At present, they are only able to do so with Great Britain. “The idea was to...integrate energy use and create more efficient flows between jurisdictions,” Doherty said.

EirGrid, the Irish transmission system operator, has reported that flows on its interconnector with Northern Ireland are more efficient than before, she said.

The price spike happened when the System Operator for Northern Ireland issued an alert for an unplanned plant outage at a time of low renewable output and constraints on the north-south tie-line with Ireland, according to a Cornwall Insight analysis.

Not an isolated event

Although it appears to have been a one-off event, there are increasing worries that a shortage of dispatchable power could lead to similar situations elsewhere across Europe, as seen in Nordic grid constraints recently.

Last month, newspaper Frankfurter Allgemeine Zeitung (FAZ) reported that German industrial concerns had been forced to curtail more than a gigawatt of power consumption to maintain operational reserves on the grid in December, after renewable production fell short of expectations and harsh weather impacts strained systems elsewhere.

Paul-Frederik Bach, a Danish energy consultant, has collected data showing that this was not an isolated incident. The FAZ report said German aluminum smelters had been forced to cut back on energy use 78 times in 2018, he noted.

Energy availability was also a concern last year in Belgium, where six out of seven nuclear reactors had been closed for maintenance. The closures forced Belgium to import 23 percent of its electricity from neighboring countries, Bach reported.

In a separate note, Bach revealed that 11 European countries that were net importers of energy had boosted their imports by 26 percent between 2017 and 2018. It is important to note that electricity imports do not necessarily imply a shortage of power, he stated.

However, it is also true that many European grid operators are girding themselves for a future in which dispatchable power is scarcer than today.

EirGrid, for example, expects dispatchable generation and interconnection capacity to drop from 10.6 gigawatts in 2018 to 9 gigawatts in 2027.

The Swedish transmission system operator Svenska Kraftnät, meanwhile, is forecasting winter peak power deficits could rise from 400 megawatts currently to 2.5 gigawatts in 2020-21.

Research conducted by the European Network of Transmission System Operators for Electricity, suggests power adequacy will fall across most of Europe up to 2025, although perhaps not to a critical degree.

The continent’s ability to deal with the problem will be helped by having more efficient trading systems, Bach told GTM. That means developments such as ISEM could be a step in the right direction, despite initial price volatility.

In the long run, however, Europe will need to make sure market improvements are accompanied by investments in HVDC technology and interconnectors and reserve capacity. “Somewhere there must be a production of electricity, even when there is no wind,” said Bach. 

Related News

• Electricity Forum News

• Power Generation News

Senate Renewable Energy Tax Credits face Finance Committee scrutiny, with Democrats urging action on tax extenders, clean energy incentives, and climate policy, while Republicans cite prior wins in wind, biodiesel, and EV credits.

Key Points

Legislative incentives debated in the Senate Finance Committee to extend and align clean energy tax benefits.

✅ Democrats press hearings and action on energy tax policy

✅ Focus on clean energy, EVs, wind, biodiesel, and resilience

✅ Grassley cites prior extenders; disputes push for bigger subsidies

A group of 27 Democratic senators is calling for action in the Senate Finance Committee on extending energy-related tax credits and examining new tax proposals, especially those that incentivize renewable energy projects and align with FERC action on aggregated DERs across the grid.

Sen. Ron Wyden, D-Ore., the ranking Democrat on the Senate Finance Committee, who recently introduced a wildfire-resilient grid bill with Sen. Merkley, led the group of Democrats in writing a letter Tuesday to Sen. Charles Grassley, R-Iowa, who chairs the committee.

“Despite numerous opportunities, including in the recent tax extenders package, the Finance Committee has failed to take action on the dozens of energy tax proposals pending before it,” they wrote. “It is critical that the Committee move to address these issues in a timely manner, along with much needed policy changes that heed warnings on regulatory rollbacks to combat the damage and growing dangers caused by global climate change.”

The number of Americans ages 65 and over is projected to nearly double by 2060. And most would prefer to age in place and hiresenior caregivers if needed.

They pointed out that the Senate Finance Committee hasn’t held a single hearing on energy tax policy during the previous congressional term, and has yet to hold one in the current one.

“The sole energy tax-related recommendation of the Committee’s temporary policy task forces was ignored in the tax extender legislation passed in December 2019, along with nearly all proposals put forward in members’ legislation this Congress,” they wrote. “This Committee must fulfill its role in examining members’ energy tax proposals and in bolstering our nation’s efforts to combat climate change, including a clean electricity standard approach that sets firm targets.”

They noted that In 2019, the global average temperature was the second highest ever recorded and the past decade was the hottest ever. The lawmakers pointed to raging wildfires and increased flooding in the western part of the U.S., as well as challenges in California’s power system during the transition, causing unprecedented destruction over the past several years. They called for tax incentives for renewable energy to help combat climate change.

“Gaps in the tax code have disadvantaged complementary technologies that could improve climate resiliency and provide additional emissions reductions,” they wrote. “While power sector emissions continue to decrease, emissions from transportation, heavy industry and agriculture have stayed level or increased over the past 10 years, even amid $5 gas not spurring a green shift in consumer behavior. The United States is not on pace to meet its international climate commitments, to say nothing of the reductions necessary to stave off the worst potential outcomes of global warming.”

Grassley reacted to the letter, noting that he had worked to get tax extenders legislation passed, even as some states consider bans on clean energy use by utilities. "I begged Democrats for a year to help me get an extenders package passed, about half of which were green energy policies, so this rings hollow," he said in a statement Tuesday. "We wouldn’t have a wind energy credit or a biodiesel credit but for me, let alone an extension of either. Democrats were holding up these green energy provisions in an attempt to get a big expansion of taxpayer subsidies for rich Tesla owners."

Related News

• Electricity Forum News

• Energy Policy News

Zaporizhzhia Nuclear Plant Mines reported by IAEA at the Russian-occupied site: anti-personnel devices in a buffer zone, restricted areas; access limits to reactor rooftops and turbine halls heighten nuclear safety and security concerns in Ukraine.

Key Points

IAEA reports anti-personnel mines at Russian-held Zaporizhzhia, raising nuclear safety risks in buffer zones.

✅ IAEA observes mines in buffer zone at occupied site

✅ Restricted areas; no roof or turbine hall access granted

✅ Safety systems unaffected, but staff under pressure

The United Nations atomic watchdog said it saw anti-personnel mines at the site of Ukraine's Zaporizhzhia nuclear power plant which is occupied by Russian forces.

Europe's largest nuclear facility fell to Russian forces shortly after the invasion of Ukraine in February last year, as Moscow later sought to build power lines to reactivate it amid ongoing control of the area. Kyiv and Moscow have since accused each other of planning an incident at the site.

On July 23 International Atomic Energy Agency (IAEA) experts "saw some mines located in a buffer zone between the site's internal and external perimeter barriers," agency chief Rafael Grossi said in a statement on Monday.

The statement did not say how many mines the team had seen.

The devices were in "restricted areas" that operating plant personnel cannot access, Mr Grossi said, adding the IAEA's initial assessment was that any detonation "should not affect the site's nuclear safety and security systems".

Laying explosives at the site was "inconsistent with the IAEA safety standards and nuclear security guidance" and, amid controversial proposals on Ukraine's nuclear plants that have circulated internationally, created additional psychological pressure on staff, he added.

Ukrainians in Nikopol are out of water and within Russia's firing line. But Zaporizhzhia nuclear power plant could pose the biggest threat, even as Ukraine has resumed electricity exports to regional grids.

Last week the IAEA said its experts had carried out inspections at the plant, without "observing" the presence of any mines, although they had not been given access to the rooftops of the reactor buildings, while a possible agreement to curb attacks on plants was being discussed.

The IAEA had still not been given access to the roofs of the reactor buildings and their turbine halls, its latest statement said, even as a proposal to control Ukraine's nuclear plants drew scrutiny.

After falling into Russian hands, Europe's biggest power plant was targeted by gunfire and has been severed from the grid several times, raising nuclear risk warnings from the IAEA and others.

The six reactor units, which before the war produced around a fifth of Ukraine's electricity, have been shut down for months, prompting interest in wind power development as a harder-to-disrupt source.

Related News

• Electricity Forum News

• Power Generation News

Canadian Hydropower Transmission delivers HVDC clean energy via New England Clean Energy Connect and Champlain Hudson Power Express, linking HydroQuébec to Maine and New York grids for renewable energy, decarbonization, and lower wholesale electricity rates.

Key Points

HVDC delivery of HydroQuébec power to New England and New York via NECEC and CHPE, cutting emissions and costs.

✅ 1,200 MW via NECEC; 1,000 MW via CHPE.

✅ HVDC routes: 145-mile NECEC and 333-mile CHPE.

✅ Debates: land impacts, climate justice, wholesale rates.

As the sole residents of unorganized territory T5 R7 deep within Maine's North Woods, Duane Hanson and his wife, Sally Kwan, have watched the land around them—known for its natural beauty, diverse wildlife and recreational fishing—transformed by decades of development. 

But what troubles them most is what could happen in the next few months. State and corporate officials are pushing for construction of a 53-mile-long power line corridor cutting right through the woods and abutting the wild lands surrounding Hanson's property. 

If its proponents succeed, Hanson fears the corridor may represent the beginning of the end of his ability to live "off the land" away from the noise of technology-obsessed modern society. Soon, that noise may be in his backyard. 

"I moved here to be in the pristine wilderness," said Hanson.
 
With his life in what he considers the last "wild" place left on the East Coast on the line, the stakes have never felt higher to Hanson—and many across New England, as well.

The corridor is part of the New England Clean Energy Connect, one of two major and highly controversial transmission line projects meant to deliver Canadian hydropower from the government-owned utility HydroQuébec, in a province that has closed the door on nuclear power, to New England electricity consumers. 

As New England states rush to green their electric grids and combat the accelerating climate crisis, the simultaneous push from Canada to expand the market for hydroelectric power from its vast water resources, including Manitoba's clean energy, has offered these states a critical lifeline at just the right moment. 

The other big hydropower transmission line project will deliver 1,000 megawatts of power, or enough to serve approximately one million residential customers, to the New York City metropolitan area, which includes the city, Long Island, and parts of the Hudson Valley, New Jersey, Connecticut and Pennsylvania. 

The 333-mile-long Champlain Hudson Power Express project will consist of two high voltage direct current cables running underground and underwater from Canada, beneath Lake Champlain and the Hudson River, to Astoria, Queens. 

There, the Champlain Hudson project will interconnect to a sector of the New York electricity grid where city and corporate officials say the hydropower supplied can help reduce the fossil fuels that currently comprise significantly more of the base load than in other parts of the state. Though New York has yet to finalize a contract with HydroQuébec over its hydropower purchase, developers plan to start construction on the $2.2 billion project in 2021 and say it will be operational in 2025. 

The New England project consists of 145 miles of new HVDC transmission line that will run largely above ground from the Canadian border, through Maine to Massachusetts. The $1 billion project, funded by Massachusetts electricity consumers, is expected to deliver 1,200 megawatts of clean energy to the New England energy grid, becoming the region's largest clean energy source. 

Central Maine Power, which will construct the Maine transmission corridor, says the project will decrease wholesale electric rates and create thousands of jobs. Company officials expect to receive all necessary permits and begin construction by the year's end, with the project completed and in service by 2020. 

With only months until developers start making both projects on-the-ground realities, they have seized public attention within, and beyond, their regions. 

Hanson is one among many concerned New England and New York residents who've joined the ranks of environmental activists in a contentious battle with public and corporate officials over the place of Canadian hydropower in their states' clean energy futures. 

Officials and transmission line proponents say importing Canadian hydropower offers an immediate and feasible way to help decarbonize electricity portfolios in New York and New England and to address existing transmission constraints that limit cross-border flows today, supporting their broader efforts to combat climate change. 

But some environmental activists say hydropower has a significant carbon footprint of its own. They fear the projects will make states look "greener" at the expense of the local environment, Indigenous communities, and ultimately, the climate. 

"We're talking about the most environmentally and economically just pathway" to decarbonization, said Annel Hernandez, associate director of the NYC Environmental Justice Alliance. "Canadian hydro is not going to provide that." 

To that end, environmental groups opposing Canadian hydropower say New York and New England should seize the moment to expedite local development of wind and solar power. 

Paul Gallay, president of the nonprofit environmental organization Riverkeeper—which withdrew its initial support for the Champlain Hudson Power Express last November— believes New York has the capacity to develop enough in-state renewable energy sources to meet its clean energy goals, without the new transmission line. 

Yet New York City's analysis shows clearly that Canadian hydropower is critical for its clean energy strategy, said Dan Zarrilli, director of OneNYC and New York City's chief climate policy adviser. 

"We need every bit of clean energy we can get our hands on," he said, to meet the city's goal of carbon neutrality by 2050 and help achieve the state's clean energy mandates. 

Removing Canadian hydropower from the equation, said Zarilli, would commit the city to the "unacceptable outcome" of burning more gas. The city's marginalized communities would likely suffer most from the resulting air pollution and associated health impacts. 

While the two camps debate Canadian hydropower's carbon footprint and what climate justice requires, this much is clear: When it comes to pursuing a zero-carbon future, there are no easy answers. 

Hydropower's Carbon Footprint
Many people take for granted that because hydropower production doesn't involve burning fossil fuels, it's a carbon-neutral endeavor. But that's not always the case, depending on where hydropower is sourced. 

Large-scale hydropower projects often involve the creation of hydroelectric dams and reservoirs, and, in some cases, repowering existing dams to generate clean electricity. The release and flow of water from the reservoir through the dam provides the energy necessary to generate hydropower, which long-distance power lines, or transmission lines, carry to its intended destination—in this case, New England and New York. 

The initial process of flooding land to create a hydroelectric reservoir can have a sizable carbon footprint, especially in heavily vegetated areas. It causes the vegetation and soil underwater to decompose, releasing carbon dioxide and methane—a greenhouse gas 84 times more potent over a 20-year period than carbon dioxide. 

Hydropower accounts for 60 percent of Canada's electricity generation, and HydroQuébec has planned to increase capacity to 37,000 MW in 2021, with the nation second only to China in the percentage of the world's total hydroelectricity it generates. By contrast, hydropower only accounts for seven percent of U.S. utility-scale electricity generation, making it a foreign concept to many Americans. 

As New England works to introduce substantial amounts of Canadian hydropower to its electricity grid, hydropower proponents are promoting it as a prime source for clean electricity, and new NB Power agreements are expanding regional transfers within Canada as well. 

Last fall, Central Maine Power formed its own political action committee, Clean Energy Matters, to advance the New England hydropower project. Together with HydroQuébec, the Maine utility has spent nearly $17 million campaigning for the project this year. 

Related News

• Electricity Forum News

• Power Generation News

Canada Manufacturing Policy prioritizes affordable energy, trims carbon taxes, aligns with Buy America, and supports the resource sector, PPE and plastics supply, nearshoring, and resilient supply chains amid COVID-19, correcting costly green energy policies.

Key Points

A policy to boost industry with affordable energy, lower carbon taxes, resource ties, and aligned U.S. trade.

✅ Cuts energy costs and carbon tax burdens for competitiveness

✅ Rebuilds resource-sector linkages and domestic supply chains

✅ Seeks Buy America relief and clarity on plastics regulation

By Jocelyn Bamford

Since its inception in 2017, the Coalition of Concerned Manufacturers and Businesses has warned all levels of government that there would be catastrophic effects if policies that drove both the manufacturing and natural resources sectors out of the country were adopted.

The very origins of our coalition was in the fight for a competitive landscape in Ontario, a cornerstone of which is affordable energy and sounding the alarm that the Green Energy Policy in Ontario pushed many manufacturers out of the province.

The Green Energy Policy made electricity in Ontario four times the average North American rate. These unjust prices were largely there to subsidize the construction of expensive and inefficient wind and solar energy infrastructure, even as cleaning up Canada's grid is cited as critical to meeting climate pledges.

My company’s November hydro bill was $55,000 and $36,500 of that was the so-called global adjustment charge, the name given to these green energy costs.

Unaffordable electricity, illustrated by higher Alberta power costs in recent years, coupled with ever-more burdensome carbon taxes, have pushed Canadian manufacturing into the open arms of other countries that see the importance of affordable energy to attract business.

One can’t help but ask the question: If Canada had policies that attracted and maintained a robust manufacturing sector, would we be in the same situation with a lack of personal protective equipment and medical supplies for our front-line medical workers and our patients during this pandemic?  If our manufacturing sector wasn’t crippled by taxes and regulation, would it be more nimble and able to respond to a national emergency?

It seems that the federal government’s policies are designed to push manufacturing out, stifle our resource sector, and kill the very plastics industry that is so essential to keeping our front-line medical staff, patients, and citizens safe, even as the net-zero race accelerates federally.

As the federal government chased its obsession with a new green economy – a strange obsession given our country’s small contribution to global GHGs – including proposals for a fully renewable grid by 2030 advocated by some leaders, it has been blinded from the real threats to our country, threats that became very, very real with COVID-19.

After the pandemic has passed, the federal government must work to make Canada manufacturing and resource friendly again, recognizing that the IEA net-zero electricity report projects the need for more power. COVID-19 proves that Canada relies on a robust resource economy and manufacturing sector to survive. We need to ensure that we are prepared for future crises like the one we are facing now.

Here are five things our government can do now to meet that end:

1. End all carbon taxes immediately.

2. Create a mandate to bring manufacturing back to Canada through competitive offerings and favourable tax regimes.

3. Recognize the interconnections between the resource sector and manufacturing, including how fossil-fuel workers support the transition across supply chains. Many manufacturers supply parts and pieces to the resource sector, and they rely on affordable energy to compete globally.

4. Stop the current federal government initiative to label plastic as toxic. At a time when the government is appealing to manufacturers to re-tool and produce needed plastic products for the health care sector, labelling plastics as toxic is counterproductive.

5. Work to secure a Canadian exemption to Buy America. This crisis has clearly shown us that dependency on China is dangerous. We must forge closer ties with America and work as a trading block in order to be more self-sufficient.

These are troubling times. Many businesses will not survive.

We need to take back our manufacturing sector.  We need to take back our resource sector.

We need to understand the interconnected nature of these two important segments of our gross domestic production, and opportunities like an Alberta–B.C. grid link to strengthen reliability.
If we do not, in the next pandemic we may find ourselves not only without ventilators, masks and gowns but also without energy to operate our hospitals.

Jocelyn Bamford is a Toronto business executive and President of the Coalition of Concerned Manufacturers and Businesses of Canada

Related News

• Electricity Forum News

• Climate Change News

Colorado Wildfire Power Shutoffs reduce ignition risk through PSPS, grid safety protocols, data-driven forecasts, and emergency coordination, protecting communities, natural resources, and infrastructure during extreme fire weather fueled by drought and climate change.

Key Points

Planned PSPS outages cut power in high-risk areas to prevent ignitions, protect residents, and boost wildfire resilience.

✅ PSPS triggered by forecasts, fuel moisture, and fire danger indices.

✅ Utilities coordinate alerts, timelines, and critical facility support.

✅ Paired with forest management, education, and rapid response.

Colorado, known for its stunning landscapes and outdoor recreation, has implemented proactive measures to reduce the risk of wildfires by strategically shutting off power in high-risk areas, similar to PG&E wildfire shutoffs implemented in California during extreme conditions. This approach, while disruptive, aims to safeguard communities, protect natural resources, and mitigate the devastating impacts of wildfires that have become increasingly prevalent in the region.

The decision to initiate power outages as a preventative measure against wildfires underscores Colorado's commitment to proactive fire management and public safety, aligning with utility disaster planning practices that strengthen grid readiness. With climate change contributing to hotter and drier conditions, the state faces heightened wildfire risks, necessitating innovative strategies to minimize ignition sources and limit fire spread.

Utility companies, in collaboration with state and local authorities, identify areas at high risk of wildfire based on factors such as weather forecasts, fuel moisture levels, and historical fire data. When conditions reach critical thresholds, planned power outages, also known as Public Safety Power Shutoffs (PSPS), are implemented to reduce the likelihood of electrical equipment sparking wildfires during periods of extreme fire danger, particularly during windstorm-driven outages that elevate ignition risks.

While power outages are a necessary precautionary measure, they can pose challenges for residents, businesses, and essential services that rely on uninterrupted electricity, as seen when a North Seattle outage affected thousands last year. To mitigate disruptions, utility companies communicate outage schedules in advance, provide updates during outages, and coordinate with emergency services to ensure the safety and well-being of affected communities.

The implementation of PSPS is part of a broader strategy to enhance wildfire resilience in Colorado. In addition to reducing ignition risks from power lines, the state invests in forest management practices, wildfire prevention education, and emergency response capabilities, including continuity planning seen in the U.S. grid COVID-19 response, to prepare for and respond to wildfires effectively.

Furthermore, Colorado's approach to wildfire prevention highlights the importance of community preparedness and collaboration, and utilities across the region adopt measures like FortisAlberta precautions to sustain critical services during emergencies. Residents are encouraged to create defensible space around their properties, develop emergency evacuation plans, and stay informed about wildfire risks and response protocols. Community engagement plays a crucial role in building resilience and fostering a collective effort to protect lives, property, and natural habitats from wildfires.

The effectiveness of Colorado's proactive measures in mitigating wildfire risks relies on a balanced approach that considers both short-term safety measures and long-term fire prevention strategies. By integrating technology, data-driven decision-making, and community partnerships, the state aims to reduce the frequency and severity of wildfires while enhancing overall resilience to wildfire impacts.

Looking ahead, Colorado continues to refine its wildfire management practices in response to evolving environmental conditions and community needs, drawing on examples of localized readiness such as PG&E winter storm preparation to inform response planning. This includes ongoing investments in fire detection and monitoring systems, research into fire behavior and prevention strategies, and collaboration with neighboring states and federal agencies to coordinate wildfire response efforts.

In conclusion, Colorado's decision to implement power outages as a preventative measure against wildfires demonstrates proactive leadership in wildfire risk reduction and public safety. By prioritizing early intervention and community engagement, the state strives to safeguard vulnerable areas, minimize the impact of wildfires, and foster resilience in the face of increasing wildfire threats. As Colorado continues to innovate and adapt its wildfire management strategies, its efforts serve as a model for other regions grappling with the challenges posed by climate change and wildfire risks.

Related News

• Electricity Forum News

• Utility Operations News