Con Ed’s vision of a nuclear future – circa 1962

By New York Times


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The year was 1962, and nuclear power was in the ascendant.

A handful of atomic plants had opened across the country, with many more in the pipeline. Across the ocean, a depressed coal town in the Japanese prefecture of Fukushima had welcomed overtures from Tokyo Electric to build a nuclear generating station, and the utility was surveying the site.

Thirty miles north of New York City, the Consolidated Edison CompanyÂ’s Indian Point plant, the first fully private nuclear power plant to be licensed, had just achieved a sustained chain reaction and was about to go online.

But Con Ed had bigger plans. On Dec. 10, it applied to the Atomic Energy Commission to build the worldÂ’s largest nuclear plant, with a capacity of a thousand megawatts, more power than all the other atomic plants in the United States put together.

The plant, Con Ed said, would rise on the East River waterfront in Long Island City, Queens, less than two miles from Times Square.

The idea of siting a mammoth nuclear generator in the heart of New York City seems preposterous now, and increasingly so.

At the time, while controversial, it was not unthinkable.

Around the world, governments were contemplating nuclear plants in or near big cities, weighing the remote risk of catastrophe against the higher long-run cost and air pollution associated with conventional plants: the unknown devil against the known.

And the world watched as the yearlong struggle, now all but forgotten, over Con EdÂ’s proposed Ravenswood nuclear plant played out.

On a snowy night in February 1963, more than 250 people crowded into a church auditorium a few blocks from the plant site in the middle-and-working-class neighborhood of Ravenswood for the first community meeting on the project. The Queens borough president, Mario J. Cariello, set the tone, thundering, to cheers and applause, “I was opposed to this project, I am opposed, and I will continue in that stand until convinced otherwise.”

If Con Ed was cowed, it did not let on. In April, the utility’s chairman, Harland C. Forbes, told a Congressional committee that “one or two people have raised some question about the genetic effects of radiation and so forth.” Such concerns were “rather silly,” Mr. Forbes said.

“It seems to me,” he said, “that the public in general has reached the point where it has accepted nuclear plants as a matter of course.”

But a former chairman of the Atomic Energy Commission, David E. Lilienthal, told the same committee, “I would not dream of living in the borough of Queens if there were a large atomic power plant in that region, because there is an alternative — a conventional thermal power plant as to which there are no risks.”

Con Ed officials noted that there were already two large oil-fired plants at its Ravenswood site building another would worsen air pollution. If nuclear power were to compete with conventional power, Con Ed said, plants had to be built in the areas they served. Building a nuclear reactor the size of Ravenswood at Indian Point, the utility said, required transmission lines that would tack $75 million onto the reactorÂ’s $175 million price, an increase of 40 percent.

In May, the Democratic leader of the City Council introduced a bill to ban commercial nuclear power in New York City. At a hearing on the bill, six women and a man picketed outside. One carried a sign that read, “Atomic power plants increase the toll of deformed, stillborn and mentally retarded children.”

In June, the City Council heard more than seven hours of testimony on the ban. A city utility commissioner called it “repressive and shortsighted.” The chairman of the Atomic Energy Commission, Glenn T. Seaborg, questioned the measure’s legality. A state senator from Queens, Seymour R. Thaler, told the Council, “The mind of man has not yet invented an accident-proof piece of mechanical equipment.”

All told, 29 people testified against the ban 30 testified in favor. Out in City Hall Plaza, the growing crowd of picketers now had a name: Canpop, the Committee Against a Nuclear Power Plant in New York City.

In Washington, the Atomic Energy Commission harbored doubts. In August, it sent Con Ed a list of safety questions about the plant. The commission’s 1962 siting guidelines were deliberately ambiguous. On one hand, they called for a one-mile unpopulated zone around a nuclear plant, and low population density within a 16-mile radius. More than five million people lived or worked within five miles of the Ravenswood site. But the guidelines also noted that applicants were “free — and indeed encouraged” to argue for exceptions.

Con Ed had boasted that the shielding for its pressurized water reactor, featuring a concrete igloo 167 feet high and 7 feet thick, encased in another shell of thick concrete, could withstand a complete meltdown or a jetliner crash.

The plant’s neighbors remained unimpressed. “We think one of the threats is a decline in property values, and that is a factor,” Irving Katz, a founder of Canpop and a biochemist, told The Times in an October 1963 article. “But really it comes down to this — when we look out of our windows and see those two stacks up there, we are frightened. And our women are frightened.”

On Dec. 9, Con Edison told the commission it would modify its plans to include “additional engineering safeguards.”

Instead, on Jan. 6, 1964, Con Ed withdrew its Ravenswood application. It said it had made arrangements to buy hydroelectric power from Canada instead, a move that “had absolutely nothing to do with the public opposition to the proposal.” The cost of building transmission lines was suddenly not a factor.

Con Ed was not done trying to build a nuclear plant in the city, though. In 1968, it floated a plan to build an underground reactor — “because it would provide the nth degree of safety” — beneath an abandoned hospital site at the south end of Welfare Island, now Roosevelt Island, a few hundred feet from the Ravenswood plants and that much closer to the East Side of Manhattan. It went nowhere.

In 1970, the utility proposed nuclear plants on man-made islands several miles off Coney Island and Staten Island, built of solid waste and each crowned with four thousand-megawatt reactors.

That proposal, too, was blocked by public opposition. But J. Samuel Walker, a former historian for the Nuclear Regulatory Commission, said that neither one ever had a chance of getting approved.

“Ravenswood was kind of a test case,” Mr. Walker said. After that, the atomic commission “agreed on kind of an informal rule. They wouldn’t allow a plant any closer to a city than Indian Point.”

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Court reinstates constitutional challenge to Ontario's hefty ‘global adjustment’ electricity charge

Ontario Global Adjustment Charge faces constitutional scrutiny as a regulatory charge vs tax; Court of Appeal revives case over electricity pricing, feed-in tariff contracts, IESO policy, and hydro rate impacts on consumers and industry.

 

Key Points

A provincial electricity fee funding generator contracts, now central to a court fight over tax versus regulatory charge.

✅ Funds gap between market price and contracted generator rates

✅ At issue: regulatory charge vs tax under constitutional law

✅ Linked to feed-in tariff, IESO policy, and hydro rate hikes

 

Ontario’s court of appeal has decided that a constitutional challenge of a steep provincial electricity charge should get its day in court, overturning a lower-court judgment that had dismissed the legal bid.

Hamilton, Ont.-based National Steel Car Ltd. launched the challenge in 2017, saying Ontario’s so-called global adjustment charge was unconstitutional because it is a tax — not a valid regulatory charge — that was not passed by the legislature.

The global adjustment funds the difference between the province’s hourly electricity price and the price guaranteed under contracts to power generators. It is “the component that covers the cost of building new electricity infrastructure in the province, maintaining existing resources, as well as providing conservation and demand management programs,” the province’s Independent Electricity System Operator says.

However, the global adjustment now makes up most of the commodity portion of a household electricity bill, and its costs have ballooned, as regulators elsewhere consider a proposed 14% rate hike in Nova Scotia.

Ontario’s auditor general said in 2015 that global adjustment fees had increased from $650 million in 2006 to more than $7 billion in 2014. She added that consumers would pay $133 billion in global adjustment fees from 2015 to 2032, after having already paid $37 billion from 2006 to 2014.

National Steel Car, which manufactures steel rail cars and faces high electricity rates that hurt Ontario factories, said its global adjustment costs went from $207,260 in 2008 to almost $3.4 million in 2016, according to an Ontario Court of Appeal decision released on Wednesday.

The company claimed the global adjustment was a tax because one of its components funds electricity procurement contracts under a “feed-in tariff” program, or FIT, which National Steel Car called “the main culprit behind the dramatic price increases for electricity,” the decision said.

Ontario’s auditor general said the FIT program “paid excessive prices to renewable energy generators.” The program has been ended, but contracts awarded under it remain in place.


National Steel Car claimed the FIT program “was actually designed to accomplish social goals unrelated to the generation of electricity,” such as helping rural and indigenous communities, and was therefore a tax trying to help with policy goals.

“The appellant submits that the Policy Goals can be achieved by Ontario in several ways, just not through the electricity pricing formula,” the decision said.

National Steel Car also argued the global adjustment violated a provincial law that requires the government to hold a referendum for new taxes.

“The appellant’s principal claim is that the Global Adjustment was a ‘colourable attempt to disguise a tax as a regulatory charge with the purpose of funding the costs of the Policy Goals,’” the decision said. “The appellant pressed this argument before the motion judge and before this court. The motion judge did not directly or adequately address it.”

The Ontario government applied to have the challenge thrown out for having “no reasonable cause of action,” and a Superior Court judge did so in 2018, saying the global adjustment is not a tax.

National Steel Car appealed the decision, and the decision published Wednesday allowed the appeal, set aside the lower-court judgment, and will send the case back to Superior Court, where it could get a full hearing.

“The appellant’s claim is sufficiently plausible on the evidentiary record it put forward that the applications should not have been dismissed on a pleadings motion before the development of a full record,” wrote Justice Peter D. Lauwers. “It is not plain, obvious and beyond doubt that the Global Adjustment, and particularly the challenged component, is properly characterized as a valid regulatory charge and not as an impermissible tax.”

Jerome Morse of Morse Shannon LLP, one of National Steel Car’s lawyers, said the Ontario government would now have 60 days to decide whether to seek permission to appeal to the Supreme Court of Canada.

“What the court has basically said is, ‘this is a plausible argument, here are the reasons why it’s plausible, there was no answer to this,’” Morse told the Financial Post.

Ontario and the IESO had supported the lower-court decision, but there has been a change in government since the challenge was first launched, with Progressive Conservative Premier Doug Ford replacing the Liberals and Kathleen Wynne in power. The Liberals had launched a plan aimed at addressing hydro costs before losing in a 2018 election, the main thrust of which had been to refinance global adjustment costs.

Wednesday’s decision states that “Ontario’s counsel advised the court that the current Ontario government ‘does not agree with the former government’s electricity procurement policy (since-repealed).’

“The government’s view is that: ‘The solution does not lie with the courts, but instead in the political arena with political actors,’” it adds.

A spokesperson for Ontario Energy Minister Greg Rickford said in an email that they are reviewing the decision but “as this matter is in the appeal period, it would be inappropriate to comment.” 

Ontario had also requested to stay the matter so a regulator, the Ontario Energy Board, could weigh in, while the Nova Scotia regulator approved a 14% hike in a separate case.

“However, Ontario only sought this relief from the motion judge in the alternative, and given the motion judge’s ultimate decision, she did not rule on the stay,” Thursday’s decision said. “It would be premature for this court to rule on the issue, although it seems incongruous for Ontario to argue that the Superior Court is the convenient forum in which to seek to dismiss the applications as meritless, but that it is not the convenient forum for assessing the merits of the applications.”

National Steel Car’s challenge bears a resemblance to the constitutional challenges launched by Ontario and other provinces over the federal government’s carbon tax, but Justice Lauwers wrote “that the federal legislative scheme under consideration in those cases is distinctly different from the legislation at issue in this appeal.”

“Nothing in those decisions impacts this appeal,” the judge added.
 

 

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Calgary's electricity use soars in frigid February, Enmax says

Calgary Winter Energy Usage Surge highlights soaring electricity demand, added megawatt-hours, and grid reliability challenges driven by extreme cold, heating loads, and climate change, with summer air conditioning also shifting seasonal peaks.

 

Key Points

A spike in Calgary's power use from extreme cold, adding 22k MWh and testing reliability as heating demand rises.

✅ +22,000 MWh vs Feb 2018 amid fourth-coldest February

✅ Heating loads spike; summer A/C now drives peak demand

✅ Grid reliability monitored; more solar and green resources ahead

 

February was so cold in Calgary that the city used enough extra energy to power 3,400 homes for a whole year, echoing record-breaking demand in B.C. in 2021 during severe cold.

Enmax Power Corporation, the primary electricity utility in the city, says the city 's energy consumption was up 22,000 megawatt hours last month compared with Februray 2018.

"We've seen through this cold period our system has held up very well. It's been very reliable," Enmax vice-president Andre van Dijk told the Calgary Eyeopener on Friday. "You know, in the absence of a windstorm combined with cold temperatures and that sort of thing, the system has actually held up pretty well."

The past month was the fourth coldest in Calgary's history, and similar conditions have pushed all-time high demand in B.C. in recent years across the West. The average temperature for last month was –18.1 C. The long-term average for February is –5.4 C.

 

Watching use, predicting issues

The electricity company monitors demand and load on a daily basis, always trying to predict issues before they happen, van Dijk said, and utilities have introduced winter payment plans to help customers manage bills during prolonged cold.

One of the issues they're watching is climate change, and how extreme temperatures and weather affect both the grid's reliability, as seen when Quebec shattered consumption records during cold snaps, and the public's energy use.

The colder it gets, the higher you turn up the heat. The hotter it is, the more you use air conditioning.

He also noted that using fuels then contributes to climate change, creating a cycle.

​"We are seeing variations in temperature and we've seen large weather events across the continent, across the world, in fact, that impact electrical systems, whether that's flooding, as we've experienced here, or high winds, tornadoes," van Dijk said.

"Climate change and changing weather patterns have definitely had had an impact on us as an electrical industry."

In 2012, he said, Calgary switched from using the most power during winter to using the most during summer, in large part due to air conditioning, he said.

"Temperature is a strong influencer of energy consumption and of our demand," van Dijk said.

Christmas tree lights have also become primarily LED, van Dijk said, which cuts down on a big energy draw in the winter.

He said he expects more solar and other green resources will be added into the electrical system in the future to mitigate how much the increasingly levels of energy use impact climate change, and to help moderate electricity costs in Alberta over time.

 

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Quebec Halts Crypto Mining Electricity Requests

Hydro-Quebec Crypto Mining Pause signals a temporary halt as blockchain power requests surge; energy regulator review will weigh electricity demand, winter peak constraints, tariffs, investments, and local jobs to optimize grid stability and revenues.

 

Key Points

A provincial halt on new miner power requests as Hydro-Quebec sets rules to safeguard demand, winter peaks, and rates.

✅ Temporary halt on new electricity sales to crypto miners

✅ Regulator to rank projects by jobs, investment, and revenue

✅ Winter peak demand and tariffs central to new framework

 

Major Canadian electricity provider Hydro-Québec will temporarily stop processing requests from cryptocurrency miners in order for the company to fulfil its obligations to supply energy to the entire province, while its global ambitions adjust to changing demand, according to a press release published June 7.

Hydro-Québec is experiencing “unprecedented” demand from blockchain companies, which reportedly exceeds the electric utility’s short and medium-term capacity. In this regard, the Quebec provincial government has ordered Hydro-Québec to halt electric power sales to cryptocurrency miners, and, following the New Hampshire rejection of Northern Pass announced a new framework for this category of electricity consumers.

In the coming days, Hydro-Québec will reportedly file an application to local energy regulator Régie de l'énergie, proposing a selection process for blockchain industry projects so as “not to miss the opportunities offered by this industry.” Regulators will reportedly target companies which can offer the province the most profitable economic advantages, including investments and local job creation.

#google#

Régie de l'énergie is instructed to consider “the need for a reserved block of energy for this category of consumers, the possibility of maximizing Hydro-Québec's revenues, and issues related to the winter peak period” as well as interprovincial arrangements like the Ontario-Québec electricity deal under discussion. Éric Filion, President of Hydro-Québec Distribution, said:

"The blockchain industry is a promising avenue for Hydro-Québec. Guidelines are nevertheless required to ensure that the development of this industry maximizes spinoffs for Québec without resulting in rate increases for our customers. We are actively participating in the Régie de l'énergie's process so that these guidelines can be produced as quickly as possible."

With this move, the government of Québec deviates from its decision to reportedly open the electricity market to miners at the end of last month, even as an Ontario-Quebec energy swap helps manage electricity demands. In March, the government said it was not interested in providing cheap electricity to Bitcoin miners, stating that cryptocurrency mining at a discount without any sort of “added value” for the local economy was unfavorable.

 

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Alberta's Path to Clean Electricity

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

 

Key Points

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

✅ Phases out coal and curbs greenhouse gas emissions

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

✅ Balances provincial autonomy with national climate targets

 

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

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

The Federal Perspective

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

Alberta's Response

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

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

The Balancing Act

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

Economic Implications

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

Moving Forward

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

Conclusion

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

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

 

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Solar PV and wind power in the US continue to grow amid favourable government plans

US Renewable Power Outlook 2030 projects surging capacity, solar PV and wind growth, grid modernization, and favorable tax credits, detailing market trends, CAGR, transmission expansion, and policy drivers shaping clean energy generation and consumption.

 

Key Points

A forecast of US power capacity, generation, and consumption, highlighting solar, wind, tax credits, and grid modernization.

✅ Targets 48.4% renewable capacity share by 2030

✅ Strong growth in solar PV and onshore wind installations

✅ Investment and tax credits drive grid and transmission upgrades

 

GlobalData’s latest report, ‘United States Power Market Outlook to 2030, Update 2021 – Market Trends, Regulations, and Competitive Landscape’ discusses the power market structure of the United States and provides historical and forecast numbers for capacity, generation and consumption up to 2030. Detailed analysis of the country’s power market regulatory structure, competitive landscape and a list of major power plants are provided. The report also gives a snapshot of the power sector in the country on broad parameters of macroeconomics, supply security, generation infrastructure, transmission and distribution infrastructure, about a quarter of U.S. electricity from renewables in recent years, electricity import and export scenario, degree of competition, regulatory scenario, and future potential. An analysis of the deals in the country’s power sector is also included in the report.

Renewable power held a 19% share of the US’s total power capacity in 2020, and in that year renewables became the second-most prevalent source in the U.S. electricity mix by generation; this share is expected to increase significantly to 48.4% by 2030. Favourable policies introduced by the US Government will continue to drive the country’s renewable sector, particularly solar photovoltaics (PV) and wind power, with wind now the most-used renewable source in the U.S. generation mix. Installed renewable capacity* increased from 16.5GW in 2000 to 239.2GW in 2020, growing at a compound annual growth rate (CAGR) of 14.3%. By 2030, the cumulative renewable capacity is expected to rise to 884.6GW, growing at a CAGR of 14% from 2020 to 2030. Despite increase in prices of renewable equipment, such as solar modules, in 2021, the US renewable sector will show strong growth during the 2021 to 2030 period as this increase in equipment prices are short term due to supply chain disruptions caused by the Covid-19 pandemic.

The expansion of renewable power capacity during the 2000 to 2020 period has been possible due to the introduction of federal schemes, such as Production Tax Credits, Investment Tax Credits and Manufacturing Tax Credits. These have massively aided renewable installations by bringing down the cost of renewable power generation and making it at par with power generated from conventional sources. Over the last few years, the cost of solar PV and wind power installations has declined sharply, and by 2023 wind, solar, and batteries made up most of the utility-scale pipeline across the US, highlighting investor confidence. Since 2010, the cost of utility-scale solar PV projects decreased by around 82% while onshore wind installations decreased by around 39%. This has supported the rapid expansion of the renewable market. However, the price of solar equipment has risen due to an increase in raw material prices and supply shortages. This may slightly delay the financing of some solar projects that are already in the pipeline.

The US will continue to add significant renewable capacity additions during the forecast period as industry outlooks point to record solar and storage installations over the coming years, to meet its target of reaching 80% clean energy by 2030. In November 2021, President Biden signed a $1tr Infrastructure Bill, within which $73bn is designated to renewables. This includes not just renewable capacity building, but also strengthening the country’s power grid and laying new high voltage transmission lines, both of which will be key to driving solar and wind power capacity additions as wind power surges in the U.S. electricity mix nationwide.

The US was one of the worst hit countries in the world due to the Covid-19 pandemic in 2020. With respect to the power sector, the electricity consumption in the country declined by 2.5% in 2020 as compared to 2019, even as renewable electricity surpassed coal in 2022 in the generation mix, highlighting continued structural change. Power plants that were under construction faced delays due to unavailability of components due to supply chain disruptions and unavailability of labour due to travel restrictions.

According to the US Energy Information Administration, 61 power projects, having a total capacity of 2.4GWm which were under construction during March and April 2020 were delayed because of the Covid-19 pandemic. Among renewable power technologies, solar PV and wind power projects were the most badly affected due to the pandemic.

In March and April 2020, 53 solar PV projects, having a total capacity of 1.3GW, and wind power projects, having a total capacity of 1.2GW, were delayed due to the Covid-19 pandemic. Moreover, several states suspended renewable energy auctions due to the pandemic.

For instance, New York State Energy Research and Development Authority (NYSERDA) had issued a new offshore wind solicitation for 1GW and up to 2.5GW in April 2020, but this was suspended due to the Covid-19 pandemic. In July 2020, the authority relaunched the tender for 2.5GW of offshore wind capacity, with a submission deadline in October 2020.

To ease the financial burden on consumers during the pandemic, more than 1,000 utilities in the country announced disconnection moratoria and implemented flexible payment plans. Duke Energy, American Electric Power, Dominion Power and Southern California Edison were among the major utilities that voluntarily suspended disconnections.

 

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A tidal project in Scottish waters just generated enough electricity to power nearly 4,000 homes

MeyGen Tidal Stream Project delivers record 13.8 GWh to Scotland's grid, showcasing renewable ocean energy. Simec Atlantis Energy's 6 MW array of tidal turbines advances EU power goals and plans an ocean-powered data center.

 

Key Points

A Scottish tidal energy array exporting record power, using four 1.5 MW turbines and driving renewable innovation.

✅ Delivered 13.8 GWh to the grid in 2019, a project record.

✅ Four 1.5 MW turbines in Phase 1A, 6 MW installed.

✅ Plans include an ocean-powered data center near site.

 

A tidal power project in waters off the north coast of Scotland, where Scotland’s wind farms also deliver significant output, sent more than 13.8 gigawatt hours (GWh) of electricity to the grid last year, according to an operational update issued Monday. This figure – a record – almost doubled the previous high of 7.4 GWh in 2018.

In total, the MeyGen tidal stream array has now exported more than 25.5 GWh of electricity to the grid since the start of 2017, according to owners Simec Atlantis Energy. Phase 1A of the project is made up of four 1.5 megawatt (MW) turbines.

The 13.8 GWh of electricity exported in 2019 equates to the average yearly electricity consumption of roughly 3,800 “typical” homes in the U.K., where wind power records have been set recently, according to the company, with revenue generation amounting to £3.9 million ($5.09 million).

Onshore maintenance is now set to be carried out on the AR1500 turbine used by the scheme, with Atlantis aiming to redeploy the technology in spring.

In addition to the production of electricity, Atlantis is also planning to develop an “ocean-powered data centre” near the MeyGen project.

The European Commission has described “ocean energy” as being both abundant and renewable, and milestones like the biggest offshore windfarm starting U.K. supply underscore wider momentum, too. It’s estimated that ocean energy could potentially contribute roughly 10% of the European Union’s power demand by the year 2050, according to the Commission.

While tidal power has been around for decades — EDF’s 240 MW La Rance Tidal Power Plant in France was built as far back as 1966, and the country’s first offshore wind turbine has begun producing electricity — recent years have seen a number of new projects take shape.

In December last year, Scottish tidal energy business Nova Innovation was issued with a permit to develop a project in Nova Scotia, Canada, aiming to harness the Bay of Fundy tides in the region further.

In an announcement at the time, the firm said a total of 15 tidal stream turbines would be installed by the year 2023. The project, according to the firm, will produce enough electricity to power 600 homes, as companies like Sustainable Marine begin delivering tidal energy to the Nova Scotia grid.

Elsewhere, a business called Orbital Marine Power is developing what it describes as the world’s most powerful tidal turbine, with grid-supplied output already demonstrated.

The company says the turbine will have a swept area of more than 600 square meters and be able to generate “over 2 MW from tidal stream resources.” It will use a 72-meter-long “floating superstructure” to support two 1 MW turbines.

 

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