An Old Steel Mill Retools to Produce Clean Energy

By New York Times


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Empty grain elevators and dormant railroad tracks line the Buffalo River to the east and Lake Erie to the west, interspersed with empty fields overgrown with gnarled shrubbery. Test wells that monitor decades of buried industrial waste dot the landscape. A passenger ship, rust overtaking its aqua paint, sits beside a decaying mill.

The road from Buffalo to this city to the south offers a stark reminder of the regionÂ’s faded past as a hub of industry and shipping.

Yet in the past few months, a different sight has emerged on the 2.2-mile shoreline above a labyrinth of pipes, blackened buildings and crumbling coke ovens that was once home to a behemoth Bethlehem Steel plant: eight gleaming white windmills with 153-foot blades slowly turning in the wind off Lake Erie, on a former Superfund site where iron and steel slag and other industrial waste were dumped during 80 years of production.

“It’s changing the image of the city of Lackawanna,” said Norman L. Polanski Jr., the city’s mayor and a former Bethlehem worker who lost his job when the company stopped making steel here in 1983. “We were the old Rust Belt, with all the negatives. Right now, we are progressive and we are leading the way on the waterfront.”

Christine Real de Azua, of the American Wind Energy Association, said Steel Winds, as this wind farm is known, is the largest to rise in a city, and according to the state Department of Environmental Conservation, it is the first to rise on land overseen by New YorkÂ’s brownfields program. (Brownfields are low-level toxic waste sites concentrated mainly around abandoned factories.)

“It’s a way to convert the Rust Belt to the Wind Belt,” Ms. Real de Azua said.

The turbines, owned jointly by BQ Energy of Pawling, N.Y., and UPC Wind of Newton, Mass., are able to produce a total of 20 megawatts of electricity a year, enough to provide power to 7,000 homes, said the project manager, Mark Mitskovski. The companies involved in the project plan to sell the energy to individual customers or utilities.

The company began construction of the wind farm in September 2006, six months after the federal Environmental Protection Agency declared the site clean enough to be removed from the Superfund list, allowing the state Department of Environmental Conservation to oversee its development.

The windmills are a welcome change for an area buffeted by the loss of jobs and environmental problems since BethlehemÂ’s steep decline began in the mid-1970s as cheaper imported steel, mainly from Japan, began flooding the United States.

At its peak during World War II and through the boom years that followed, Bethlehem employed more than 20,000 people here, most living within walking distance of the plant. But as the jobs vanished, the cityÂ’s population fell from a high of 30,000 in the 1960s to about 19,000 today.

Smoke from the blast furnaces and coke ovens coated the mill town with a layer of red ore dust, and artificial clouds glowed several times each day, when rail cars tipped their loads of slag into Lake Erie, creating a lavalike flow visible from miles away.

“As a kid, we’d be at the beach and you’d see the ladle cars going out there 24 hours a day,” said Michael Malyak, of Lackawanna’s Steel Plant Museum, who was a shipping clerk at Bethlehem for eight years before becoming an elementary school teacher. “The sky would light up, and you’d see this red-hot slag rolling down the hillside.”

Mayor Polanski said that as dangerous and unhealthy as it was, “it was a way of life.”

And one that passed through generations. Like many of his classmates, Mr. Polanski, who is 58, followed his father to Bethlehem, getting hired as an apprentice pipe fitter.

“I graduated in June of ’67, and at the end of July, I had a job at the steel plant,” he said. “I never figured I’d lose that job.”

But as the lower-priced imported steel began to dominate the market, Bethlehem started to shrink. About 7,300 workers lost their jobs when the company stopped making steel in Lackawanna, leaving only the coke ovens and several finishing mills in operation.

Bethlehem ended coke production in 2001, the year the company filed for bankruptcy. A much smaller mill that finishes galvanized steel and employs about 250 is now operated by Mittal Steel, which acquired BethlehemÂ’s assets in 2005 in a merger with International Steel Group.

About $300,000 in state and federal assistance was used to research wind patterns and evaluate the environmental impact, and the windmills each cost $4.5 million to build. Power lines left from the plant carry the electricity from the turbines, while paved roads, rail lines and an industrial port built by Bethlehem were used to bring much of the construction material to the site.

“It’s much easier to do this on farmland somewhere,” Mr. Mitskovski said. “But all the things you would need to build in a green field setting are already here.”

Steel Winds has permits to build two more turbines and plans to put up as many as 27 in all. This month, local officials announced plans to move a rail line and build new roads in an effort to open 400 more acres of brownfields at the former Bethlehem site for redevelopment and to revitalize the Lake Erie port there, which is large enough to handle eight oceangoing ships at a time.

The economic effect of the wind farm on this city will never rival that of the steel giant. Mr. Mitskovski estimated that Steel Winds will ultimately employ a few dozen people, compared with the tens of thousands who punched the clock at Bethlehem. And though there are incentives for clean energy production, taxes generated by the wind farm will never match those paid by the steel mill, which at one time subsidized most of LackawannaÂ’s government.

The greatest effect of the eight windmills, however, may have more to do with attitude.

“A community that has had difficulty moving forward has accepted a technology that leapfrogs other forms of energy generation,” Mr. Mitskovski said. “Decades of steel-making created this environmental legacy. But that also created the opportunity to take this fallow, contaminated land and reuse it.”

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California's future with income-based flat-fee utility bills is getting closer

California Income-Based Utility Fees would overhaul electricity bills as CPUC weighs fixed charges tied to income, grid maintenance costs, AB 205 changes, and per-kilowatt-hour rates, shifting from pure usage pricing to hybrid utility rate design.

 

Key Points

Income-based utility fees are fixed monthly charges tied to earnings, alongside per-kWh rates, to help fund grid costs.

✅ CPUC considers fixed charges by income under AB 205

✅ Separates grid costs from per-kWh energy charges

✅ Could shift rooftop solar and EV charging economics

 

Electricity bills in California are likely to change dramatically in 2026, with major changes under discussion statewide.

The California Public Utilities Commission (CPUC) is in the midst of an unprecedented overhaul of the way most of the state’s residents pay for electricity, as it considers revamping electricity rates to meet grid and climate goals.

Utility bills currently rely on a use-more pay-more system, where bills are directly tied to how much electricity a resident consumes, a setup that helps explain why prices are soaring for many households.

California lawmakers are asking regulators to take a different approach, and some are preparing to crack down on utility spending as oversight intensifies. Some of the bill will pay for the kilowatt hours a customer uses and a monthly fixed fee will help pay for expenses to maintain the electric grid: the poles, the substations, the batteries, and the wires that bring power to people’s homes.

The adjustments to the state’s public utility code, section 739.9, came about because of changes written into a sweeping energy bill passed last summer, AB 205, though some lawmakers now aim to overturn income-based charges in subsequent measures.

A stroke of a pen, a legislative vote, and the governor’s signature created a move toward unprecedented income-based fixed charges across the state.

“This was put in at the last minute,” said Ahmad Faruqui, a California economist with a long professional background in utility rates. “Nobody even knew it was happening. It was not debated on the floor of the assembly where it was supposedly passed. Of course, the governor signed it.”

Faruqui wonders who was responsible for legislation that was added to the energy bill during the budget writing process. That process is not transparent.

“It’s a very small clause in a very long bill, which is mostly about other issues,” Faruqui said.

But that small adjustment could have a massive impact on California residents, because it links the size of a monthly flat fee for utility service to a resident’s income. Earn more money and pay a higher flat fee.

That fee must be paid even before customers are charged for how much power they draw.

Regulators interpreted legislative change as a mandate, but Faruqui is not sold.

“They said the commission may consider or should consider,” Faruqui said. “They didn’t mandate it. It’s worth re-reading it.”

In fact, the legislative language says the commission “may” adopt income-based flat fees for utilities. It does not say the commission “should” adopt them.

Nevertheless, the CPUC has already requested and received nine proposals for how a flat fee should be implemented, as regulators face calls for action amid soaring electricity bills.

The suggestions came from consumer groups, environmentalists, the solar industry and utilities.

 

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Vancouver's Reversal on Gas Appliances

Vancouver Natural Gas Ban Reversal spotlights energy policy, electrification tradeoffs, heat pumps, emissions, grid reliability, and affordability, reshaping building codes and decarbonization pathways while inviting stakeholders to weigh practical constraints and climate goals.

 

Key Points

Vancouver ending its ban on natural gas in new homes to balance climate goals with reliability, costs, and technology.

✅ Balances emissions goals with reliability and affordability

✅ Impacts builders, homeowners, and energy infrastructure

✅ Spurs debate on electrification, heat pumps, and grid capacity

 

In a significant policy shift, Vancouver has decided to lift its ban on natural gas appliances in new homes, a move that marks a pivotal moment in the city's energy policy and environmental strategy. This decision, announced recently and following the city's Clean Energy Champion recognition for Bloedel upgrades, has sparked a broader conversation about the future of energy systems and the balance between environmental goals and practical energy needs. Stewart Muir, CEO of Resource Works, argues that this reversal should catalyze a necessary dialogue on energy choices, highlighting both the benefits and challenges of such a policy change.

Vancouver's original ban on natural gas appliances was part of a broader initiative aimed at reducing greenhouse gas emissions and promoting sustainability, including progress toward phasing out fossil fuels where feasible over time. The city had adopted stringent regulations to encourage the use of electric heat pumps and other low-carbon technologies in new residential buildings. This move was aligned with Vancouver’s ambitious climate goals, which include achieving carbon neutrality by 2050 and significantly cutting down on fossil fuel use.

However, the recent decision to reverse the ban reflects a growing recognition of the complexities involved in transitioning to entirely new energy systems. The city's administration acknowledged that while electric alternatives offer environmental benefits, they also come with challenges that can affect homeowners, builders, and the broader energy infrastructure, including options for bridging the electricity gap with Alberta to enhance regional reliability.

Stewart Muir argues that Vancouver’s policy shift is not just about natural gas appliances but represents a larger conversation about energy system choices and their implications. He suggests that the reversal of the ban provides an opportunity to address key issues related to energy reliability, affordability, and the practicalities of integrating new technologies, including electrified LNG options for industry within the province into existing systems.

One of the primary reasons behind the reversal is the recognition of the practical limitations and costs associated with transitioning to electric-only systems. For many homeowners and builders, natural gas appliances have long been a reliable and cost-effective option. The initial ban on these appliances led to concerns about increased construction costs and potential disruptions for homeowners who were accustomed to natural gas heating and cooking.

In addition to cost considerations, there are concerns about the reliability and efficiency of electric alternatives. Natural gas has been praised for its stable energy supply and efficient performance, especially in colder climates where electric heating systems might struggle to maintain consistent temperatures or fully utilize Site C's electricity under peak demand. By reversing the ban, Vancouver acknowledges that a one-size-fits-all approach may not be suitable for every situation, particularly when considering diverse housing needs and energy demands.

Muir emphasizes that the reversal of the ban should prompt a broader discussion about how to balance environmental goals with practical energy needs. He argues that rather than enforcing a blanket ban on specific technologies, it is crucial to explore a range of solutions that can effectively address climate objectives while accommodating the diverse requirements of different communities and households.

The debate also touches on the role of technological innovation in achieving sustainability goals. As energy technologies continue to evolve, renewable electricity is coming on strong and new solutions and advancements could potentially offer more efficient and environmentally friendly alternatives. The conversation should include exploring these innovations and considering how they can be integrated into existing energy systems to support long-term sustainability.

Moreover, Muir advocates for a more inclusive approach to energy policy that involves engaging various stakeholders, including residents, businesses, and energy experts. A collaborative approach can help identify practical solutions that address both environmental concerns and the realities of everyday energy use.

In the broader context, Vancouver’s decision reflects a growing trend in cities and regions grappling with energy transitions. Many urban centers are evaluating their energy policies and considering adjustments based on new information and emerging technologies. The key is to find a balance that supports climate goals such as 2050 greenhouse gas targets while ensuring that energy systems remain reliable, affordable, and adaptable to changing needs.

As Vancouver moves forward with its revised policy, it will be important to monitor the outcomes and assess the impacts on both the environment and the community. The reversal of the natural gas ban could serve as a case study for other cities facing similar challenges and could provide valuable insights into how to navigate the complexities of energy transitions.

In conclusion, Vancouver’s decision to reverse its ban on natural gas appliances in new homes is a significant development that opens the door for a critical dialogue about energy system choices. Stewart Muir’s call for a broader conversation emphasizes the need to balance environmental ambitions with practical considerations, such as cost, reliability, and technological advancements. As cities continue to navigate their energy futures, finding a pragmatic and inclusive approach will be essential in achieving both sustainability and functionality in energy systems.

 

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New England Emergency fuel stock to cost millions

Inventoried Energy Program pays ISO-NE generators for fuel security to boost winter reliability, with FERC approval, covering fossil, nuclear, hydropower, and batteries, complementing capacity markets to enhance grid resilience during severe cold snaps.

 

Key Points

ISO-NE program paying generators to hold fuel or energy reserves for emergencies, boosting winter reliability.

✅ FERC-approved stopgap for 2023 and 2024 winter seasons

✅ Pays for on-site fuel or stored energy during cold-trigger events

✅ Open to fossil, nuclear, hydro, batteries; limited gas participation

 

Electricity ratepayers in New England will pay tens of millions of dollars to fossil fuel and nuclear power plants later this decade under a program that proponents say is needed to keep the lights on during severe winters but which critics call a subsidy with little benefit to consumers or the grid, even as Connecticut is pushing a market overhaul across the region.

Last week the Federal Energy Regulatory Commission said ISO-New England, which runs the six-state power grid, can create what it calls the Inventoried Energy Program or IEP. This basically will pay certain power plants to stockpile of fuel for use in emergencies during two upcoming winters as longer-term solutions are developed.

The federal commission called it a reasonable short-term solution to avoid brownouts which doesn’t favor any given technology.

Not all agree, however, including FERC Commissioner Richard Glick, who wrote a fiery dissent to the other three commissioners.

“The program will hand out tens of millions of dollars to nuclear, coal and hydropower generators without any indication that those payments will cause the slightest change in those generators’ behavior,” Glick wrote. “Handing out money for nothing is a windfall, not a just and reasonable rate.”

The program is the latest reaction by ISO-NE to the winter of 2013-14 when New England almost saw brownouts because of a shortage of natural gas to create electricity during a pair of week-long deep freezes.

ISO-New England says the situation is more critical now because of the possible retirement of the gas-fired Mystic Generating Station in Massachusetts. As with closed nuclear plants such as Vermont Yankee and Pilgrim in Massachusetts, power plant owners say lower electricity prices, partly due to cheap renewables and partly to stagnant demand, means they can’t be profitable just by selling power.

Programs like the IEP are meant to subsidize such plants – “incentivize” is the industry term – even though some argue there is no need to subsidize nuclear in deregulated markets so they’ll stay open if they are needed.

The IEP approved last week will be applied to the winters of 2023 and 2024, after a different subsidy program expires. It sets prices, despite warnings about rushing pricing changes from industry groups, for stocking certain amounts of fuel and payments during any “trigger” event, defined as a day when the average of high and low temperatures at Bradley International Airport in Connecticut is no more than 17 degrees Fahrenheit.

These payments will be made on top of a complex system of grid auctions used to decide how much various plants get paid for generating electricity at which times.

ISO-NE estimates the new program will cost between $102 million and $148 million each winter, depending on weather and market conditions.

It says the payments are open to plants that burn oil, coal, nuclear fuel, wood chips or trash; utility-scale battery storage facilities; and hydropower dams “that store water in a pond or reservoir.” Natural gas plants can participate if they guarantee to have fuel available, but that seems less likely because of winter heating contracts.

A major complaint and groups that filed petitions opposing the project is that ISO-NE presented little supporting evidence of how prices, amount and overall cost were determined. ISO-NE argued that there wasn’t time for such analysis before the Mystic shutdown, and FERC agreed.

“The proposal is a step in the right direction … while ISO-NE finishes developing a long-term market solution,” the commission said in its ruling.

The program is the latest example of complexities facing the nation’s electricity system evolves in the face of solar and wind power, which produce electricity so cheaply that they can render traditional power uneconomic but which can’t always produce power on demand, prompting discussions of Texas grid improvements among policymakers. Another major factor is climate change, which has increased the pressure to support renewable alternatives to plants that burn fossil fuels, as well as stagnant electricity demand caused by increased efficiency.

Opponents, including many environmental groups, say electricity utilities and regulators are too quick to prop up existing systems, as the 145-mile Maine transmission line debate shows, built when electricity was sent one way from a few big plants to many customers. They argue that to combat climate change as well as limit cost, the emphasis must be on developing “non-wire alternatives” such as smart systems for controlling demand, in order to take advantage of the current system in which electricity goes two ways, such as from rooftop solar back into the grid.

 

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Trump's Oil Policies Spark Shift in Wall Street's Energy Strategy

Wall Street Fossil Fuel Pivot signals banks reassessing ESG, net-zero, and decarbonization goals, reviving oil, gas, and coal financing while recalibrating clean energy exposure amid policy shifts, regulatory rollbacks, and investment risk realignment.

 

Key Points

A shift as major U.S. banks ease ESG limits to fund oil, gas, coal while rebalancing alongside renewables.

✅ Banks revisit lending to oil, gas, and coal after policy shifts.

✅ ESG and net-zero commitments face reassessment amid returns.

✅ Renewables compete for capital as risk models are updated.

 

The global energy finance sector, worth a staggering $1.4 trillion, is undergoing a significant transformation, largely due to former President Donald Trump's renewed support for the oil, gas, and coal industries. Wall Street, which had previously aligned itself with global climate initiatives and the energy transition and net-zero goals, is now reassessing its strategy and pivoting toward a more fossil-fuel-friendly stance.

This shift represents a major change from the earlier stance, where many of the largest U.S. banks and financial institutions took a firm stance on decarbonization push, including limiting their exposure to fossil-fuel projects. Just a few years ago, these institutions were vocal supporters of the global push for a sustainable future, with many committing to support clean energy solutions and abandon investments in high-carbon energy sources.

However, with the change in administration and the resurgence of support for traditional energy sectors under Trump’s policies, these same banks are now rethinking their strategies. Financial institutions are increasingly discussing the possibility of lifting long-standing restrictions that limited their investments in controversial fossil-fuel projects, including coal mining, where emissions drop as coal declines, and offshore drilling. The change reflects a broader realignment within the energy finance sector, with Wall Street reexamining its role in shaping the future of energy.

One of the most significant developments is the Biden administration’s policy reversal, which emphasized reducing the U.S. carbon footprint in favor of carbon-free electricity strategies. Under Trump, however, there has been a renewed focus on supporting the traditional energy sectors. His administration has pushed to reduce regulatory burdens on fossil-fuel companies, particularly oil and gas, while simultaneously reintroducing favorable tax incentives for the coal and gas industries. This is a stark contrast to the Biden administration's efforts to incentivize the transition toward renewable energy and zero-emissions goals.

Trump's policies have, in effect, sent a strong signal to financial markets that the fossil-fuel industry could see a resurgence. U.S. banks, which had previously distanced themselves from financing oil and gas ventures due to the pressure from environmental activists and ESG (Environmental, Social, and Governance) investors, as seen in investor pressure on Duke Energy, are now reconsidering their positions. Major players like JPMorgan Chase and Goldman Sachs are reportedly having internal discussions about revisiting financing for energy projects that involve high carbon emissions, including controversial oil extraction and gas drilling initiatives.

The implications of this shift are far-reaching. In the past, a growing number of institutional investors had embraced ESG principles, with the goal of supporting the transition to renewable energy sources. However, Trump’s pro-fossil fuel stance appears to be emboldening Wall Street’s biggest players to rethink their commitment to green investing. Some are now advocating for a “balanced approach” that would allow for continued investment in traditional energy sectors, while also acknowledging the growing importance of renewable energy investments, a trend echoed by European oil majors going electric in recent years.

This reversal has led to confusion among investors and analysts, who are now grappling with how to navigate a rapidly changing landscape. Wall Street's newfound support for the fossil-fuel industry comes amid a backdrop of global concerns about climate change. Many investors, who had previously embraced policies aimed at curbing the effects of global warming, are now finding it harder to reconcile their environmental commitments with the shift toward fossil-fuel-heavy portfolios. The reemergence of fossil-fuel-friendly policies is forcing institutional investors to rethink their long-term strategies.

The consequences of this policy shift are also being felt by renewable energy companies, which now face increased competition for investment dollars from traditional energy sectors. The shift towards oil and gas projects has made it more challenging for renewable energy companies to attract the same level of financial backing, even as demand for clean energy continues to rise and as doubling electricity investment becomes a key policy call. This could result in a deceleration of renewable energy projects, potentially delaying the progress needed to meet the world’s climate targets.

Despite this, some analysts remain optimistic that the long-term shift toward green energy is inevitable, even if fossil-fuel investments gain a temporary boost. As the world continues to grapple with the effects of climate change, and as technological advancements in clean energy continue to reduce costs, the transition to renewables is likely to persist, regardless of the political climate.

The shift in Wall Street’s approach to energy investments, spurred by Trump’s pro-fossil fuel policies, is reshaping the $1.4 trillion global energy finance market. While the pivot towards fossil fuels may offer short-term gains, the long-term trajectory for energy markets remains firmly in the direction of renewables. The next few years will be crucial in determining whether financial institutions can balance the demand for short-term profitability with their long-term environmental responsibilities.

 

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Europeans push back from Russian oil and gas

EU Renewable Energy Transition is accelerating under REPowerEU, as wind and solar generation hit records, improving energy security, efficiency, and decarbonization while reducing reliance on Russian fossil fuels across the EU grid.

 

Key Points

EU shift to wind and solar under REPowerEU to cut fossil fuels, boost efficiency, and secure energy supply.

✅ Wind and solar set record 22% of EU electricity in 2022

✅ REPowerEU targets over 40% renewables and 15% lower demand by 2030

✅ Diversifies away from Russian fuels; partners with US and Norway

 

Europe is producing all-time highs of wind and solar energy as the 27-country group works to reduce its reliance on fossil fuels from Russia, a shift underscored by Europe's green surge across the bloc.

Four months after Vladimir Putin’s full-scale invasion of Ukraine in February 2022, the European Commission launched REPowerEU. This campaign aims to:

  • Boost the use of renewable energy.
  • Reduce overall energy consumption.
  • Diversify energy sources.

EU countries were already moving toward renewable energy, but Russia’s war against Ukraine accelerated that trend. In 2022, for the first time, renewables surpassed fossil fuels and wind and solar power surpassed gas as a source of electricity. Wind and solar provided a record-breaking 22% of EU countries’ electrical supply, according to London-based energy think tank Ember.

“We have to double down on investments in home-grown renewables,” European Commission President Ursula von der Leyen said in October 2022. “Not only for the climate but also because the transition to the clean energy is the best way to gain independence and to have security of energy supply.”

Across the continent, growth in solar generation rose by 25% in 2022, according to Ember, as solar reshapes electricity prices in Northern Europe. Twenty EU countries produced their highest share of solar power in 2022. In October, Greece ran entirely on renewables for several hours and is seven years ahead of schedule for its 2030 solar capacity target.

Meanwhile, Ireland's green electricity target aims to make more than a third of its power supply renewable within four years.

By 2030, RePowerEU aims to provide more than 40% of the EU’s total power from renewables, aligning with global renewable records being shattered worldwide.

To meet the European Commission’s goal to cut EU energy usage by 15%, people and governments changed their habits and became more energy-efficient, while Germany's solar power boost helped bolster supply. Among their actions:

  • Germany turned down the heat in public buildings and lowered the cost of train tickets to reduce car usage, as clean energy hit 50% in Germany during this period.
  • Spain ordered stores and public buildings to turn off their lights at night.
  • France dimmed the Eiffel Tower and reduced city speed limits.

For the oil and gas that the EU still needed to import, countries turned to partners such as Norway and the United States.

 

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Big prizes awarded to European electricity prediction specialists

Electricity Grid Flow Prediction leverages big data, machine learning, and weather analytics to forecast power flows across smart grids, enhancing reliability, reducing blackouts and curtailment, and optimizing renewable integration under EU Horizon 2020 innovation.

 

Key Points

Short-term forecasting of power flows using big data, weather inputs, and machine learning to stabilize smart grids.

✅ Uses big data, weather, and ML for 6-hour forecasts

✅ Improves reliability, cuts blackouts and energy waste

✅ Supports smart grids, renewables, and grid balancing

 

Three European prediction specialists have won prizes worth €2 million for developing the most accurate predictions of electricity flow through a grid

The three winners of the Big Data Technologies Horizon Prize received their awards at a ceremony on 12th November in Austria.

The first prize of €1.2 million went to Professor José Vilar from Spain, while Belgians Sofie Verrewaere and Yann-Aël Le Borgne came in joint second place and won €400,000 each.

The challenge was open to individuals groups and organisations from countries taking part in the EU’s research and innovation programme, Horizon 2020.

Carlos Moedas, Commissioner for Research, Science and Innovation, said: “Energy is one of the crucial sectors that are being transformed by the digital grid worldwide.

“This Prize is a good example of how we support a positive transformation through the EU’s research and innovation programme, Horizon 2020.

“For the future, we have designed our next programme, Horizon Europe, to put even more emphasis on the merger of the physical and digital worlds across sectors such as energy, transport and health.”

The challenge for the applicants was to create AI-driven software that could predict the likely flow of electricity through a grid taking into account a number of factors including the weather and the generation source (i.e. wind turbines, solar cells, etc).

Using a large quantity of data from electricity grids, EU smart meters, combined with additional data such as weather conditions, applicants had to develop software that could predict the flow of energy through the grid over a six-hour period.

Commissioner for Digital Economy and Society Mariya Gabriel said: “The wide range of possible applications of these winning submissions could bring tangible benefits to all European citizens, including efforts to tackle climate change with machine learning across sectors.”

The decision to focus on energy grids for this particular prize was driven by a clear market need, including expanding HVDC technology capabilities.

Today’s energy is produced at millions of interconnected and dispersed unpredictable sites such as wind turbines, solar cells, etc., so it is harder to ensure that electricity supply matches the demand at all times.

This complexity means that huge amounts of data are produced at the energy generation sites, in the grid and at the place where the energy is consumed.

Being able to make accurate, short-term predictions about power grid traffic is therefore vital to reduce the risks of blackouts or, by enabling utilities to use AI for energy savings, limit waste of energy.

Reliable predictions can also be used in fields such as biology and healthcare. The predictions can help to diagnose and cure diseases as well as to allocate resources where they are most needed.

Ultimately, the winning ideas are set to be picked up by the energy sector in the hopes of creating smarter electricity infrastructure, more economic and more reliable power grids.

 

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