The city of Copenhagen aims to bring carbon-dioxide (CO2) emissions down to zero and become the first carbon-neutral capital city by 2025.
The seven mayors of the city announced the target while launching Copenhagen's new climate plan recently. The plan involves the initial reduction of CO2 emissions by 20% by 2015, and 50 clear initiatives have been outlined to achieve that target. The business community and the local inhabitants have been invited to work closely with the city's administration towards achieving these ambitious goals.
One of the initiatives to achieve a CO2-neutral Copenhagen by 2025 includes the development of a new geothermal power station, increasing the production of geothermal heat by 600%. Such a project would cost the city about $183.33 million.
According to Professor Hendrik Lund of the Department of Development and Planning at Aalborg University, a new power station could be set up within six to seven years. Lund's paper observes that Copenhagen could utilize geothermal energy to generate up to 50% of the district heating requirements.
Klaus Bondam, Mayor of Technical and Environmental Administration, said that instead of choosing the easiest solutions to reduce greenhouse gases, Copenhagen would implement the green solution to create a healthy city. The other initiatives of the city's climate plan include the use of hydrogen-powered and electric cars that could be parked for free in parking areas and recharged at street corners.
The plan also includes the refurbishment of educational institutions, increased use of wind turbines, development of a wind power project, and the use of biomass in power stations to ensure that the energy produced is carbon-neutral.
According to results of a recent survey, the ground a few kilometers beneath Copenhagen has enough hot water to fulfill all the heating requirements of the eastern Zealand district for thousands of years. The survey reports that the geothermal reserves under the city contain about 70 times more energy than required by Denmark to fulfill its heating, electricity and transportation needs.
According to Jesper Magtengaard, an engineer of DONG Energy, new calculations have shown that it is economically feasible to allow building heating systems to absorb heat from the water, send the used water back underground, allowing it to be reheated, and then reuse it for district heating. Although using geothermal energy is not comparable with the existing power and heat plants in the short-term, it is a plan that could be developed for the long-term.
Denmark currently has two operating geothermal plants. The plant in the town of Thisted in Jutland was set up in 1984, while the second plant is located on the island of Amager, which is a part of Copenhagen. Copenhagen already has three large-scale, waste-combustion plants that produce surplus heat during summer. According to the project manager for the heating plan for the capital, Thomas Hartmann, setting up a geothermal plant now would be less economical than continuing with the existing biomass- and waste-fueled heat and power plants.
Copenhagen will host three climate conferences in December 2009. The United Nations' Framework Convention on Climate Change summit will outline the new paths to be followed to fight climate change after 2012, when the first stage of the Kyoto Protocol concludes. The two other summits are the Children's Climate Change Forum and a mayors' summit, which is expected to generate practical methods that can be followed by municipal bodies to fight climate change.
Canada Three-Layer Mask Recommendation advises non-medical masks with a polypropylene filter layer and tightly woven cotton, aligned with WHO guidance, to curb COVID-19 aerosols indoors through better fit, coverage, and public health compliance.
Key Points
PHAC advises three-layer non-medical masks with a polypropylene filter to improve indoor COVID-19 protection.
✅ Two fabric layers plus a non-woven polypropylene filter
✅ Ensure snug fit: cover nose, mouth, chin without gaps
✅ Aligns with WHO guidance for aerosols and droplets
The Public Health Agency of Canada is now recommending Canadians choose three-layer non-medical masks with a filter layer to prevent the spread of COVID-19, even as an IEA report projects higher electricity needs for net-zero, as they prepare to spend more time indoors over the winter.
Chief Public Health Officer Dr. Theresa Tam made the recommendation during her bi-weekly pandemic briefing in Ottawa Tuesday, as officials also track electricity grid security amid critical infrastructure concerns.
"To improve the level of protection that can be provided by non-medical masks or face coverings, we are recommending that you consider a three-layer nonmedical mask," she said.
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According to recently updated guidelines, two layers of the mask should be made of a tightly woven fabric, such as cotton or linen, and the middle layer should be a filter-type fabric, such as non-woven polypropylene fabric, as Canada explores post-COVID manufacturing capacity for PPE.
"We're not necessarily saying just throw out everything that you have," Tam told reporters, suggesting adding a filter can help with protection.
The Public Health website now includes instructions for making three-layer masks, while national goals like Canada's 2050 net-zero target continue to shape recovery efforts.
The World Health Organization has recommended three layers for non-medical masks since June, and experts note that cleaning up Canada's electricity is critical to broader climate resilience. When pressed about the sudden change for Canada, Tam said the research has evolved.
"This is an additional recommendation just to add another layer of protection. The science of masks has really accelerated during this particular pandemic. So we're just learning again as we go," she said.
"I do think that because it's winter, because we're all going inside, we're learning more about droplets and aerosols, and how indoor comfort systems from heating to air conditioning costs can influence behaviors."
She also urged Canadians to wear well-fitted masks that cover the nose, mouth and chin without gaping, as the federal government advances emissions and EV sales regulations alongside public health guidance.
ITER Nuclear Fusion advances tokamak magnetic confinement, heating deuterium-tritium plasma with superconducting magnets, targeting net energy gain, tritium breeding, and steam-turbine power, while complementing laser inertial confinement milestones for grid-scale electricity and 2025 startup goals.
Key Points
ITER Nuclear Fusion is a tokamak project confining D-T plasma with magnets to achieve net energy gain and clean power.
✅ Tokamak magnetic confinement with high-temp superconducting coils
✅ Deuterium-tritium fuel cycle with on-site tritium breeding
✅ Targets net energy gain and grid-scale, low-carbon electricity
It sounds like the stuff of dreams: a virtually limitless source of energy that doesn’t produce greenhouse gases or radioactive waste. That’s the promise of nuclear fusion, often described as the holy grail of clean energy by proponents, which for decades has been nothing more than a fantasy due to insurmountable technical challenges. But things are heating up in what has turned into a race to create what amounts to an artificial sun here on Earth, one that can provide power for our kettles, cars and light bulbs.
Today’s nuclear power plants create electricity through nuclear fission, in which atoms are split, with next-gen nuclear power exploring smaller, cheaper, safer designs that remain distinct from fusion. Nuclear fusion however, involves combining atomic nuclei to release energy. It’s the same reaction that’s taking place at the Sun’s core. But overcoming the natural repulsion between atomic nuclei and maintaining the right conditions for fusion to occur isn’t straightforward. And doing so in a way that produces more energy than the reaction consumes has been beyond the grasp of the finest minds in physics for decades.
But perhaps not for much longer. Some major technical challenges have been overcome in the past few years and governments around the world have been pouring money into fusion power research as part of a broader green industrial revolution under way in several regions. There are also over 20 private ventures in the UK, US, Europe, China and Australia vying to be the first to make fusion energy production a reality.
“People are saying, ‘If it really is the ultimate solution, let’s find out whether it works or not,’” says Dr Tim Luce, head of science and operation at the International Thermonuclear Experimental Reactor (ITER), being built in southeast France. ITER is the biggest throw of the fusion dice yet.
Its $22bn (£15.9bn) build cost is being met by the governments of two-thirds of the world’s population, including the EU, the US, China and Russia, at a time when Europe is losing nuclear power and needs energy, and when it’s fired up in 2025 it’ll be the world’s largest fusion reactor. If it works, ITER will transform fusion power from being the stuff of dreams into a viable energy source.
Constructing a nuclear fusion reactor ITER will be a tokamak reactor – thought to be the best hope for fusion power. Inside a tokamak, a gas, often a hydrogen isotope called deuterium, is subjected to intense heat and pressure, forcing electrons out of the atoms. This creates a plasma – a superheated, ionised gas – that has to be contained by intense magnetic fields.
The containment is vital, as no material on Earth could withstand the intense heat (100,000,000°C and above) that the plasma has to reach so that fusion can begin. It’s close to 10 times the heat at the Sun’s core, and temperatures like that are needed in a tokamak because the gravitational pressure within the Sun can’t be recreated.
When atomic nuclei do start to fuse, vast amounts of energy are released. While the experimental reactors currently in operation release that energy as heat, in a fusion reactor power plant, the heat would be used to produce steam that would drive turbines to generate electricity, even as some envision nuclear beyond electricity for industrial heat and fuels.
Tokamaks aren’t the only fusion reactors being tried. Another type of reactor uses lasers to heat and compress a hydrogen fuel to initiate fusion. In August 2021, one such device at the National Ignition Facility, at the Lawrence Livermore National Laboratory in California, generated 1.35 megajoules of energy. This record-breaking figure brings fusion power a step closer to net energy gain, but most hopes are still pinned on tokamak reactors rather than lasers.
In June 2021, China’s Experimental Advanced Superconducting Tokamak (EAST) reactor maintained a plasma for 101 seconds at 120,000,000°C. Before that, the record was 20 seconds. Ultimately, a fusion reactor would need to sustain the plasma indefinitely – or at least for eight-hour ‘pulses’ during periods of peak electricity demand.
A real game-changer for tokamaks has been the magnets used to produce the magnetic field. “We know how to make magnets that generate a very high magnetic field from copper or other kinds of metal, but you would pay a fortune for the electricity. It wouldn’t be a net energy gain from the plant,” says Luce.
One route for nuclear fusion is to use atoms of deuterium and tritium, both isotopes of hydrogen. They fuse under incredible heat and pressure, and the resulting products release energy as heat
The solution is to use high-temperature, superconducting magnets made from superconducting wire, or ‘tape’, that has no electrical resistance. These magnets can create intense magnetic fields and don’t lose energy as heat.
“High temperature superconductivity has been known about for 35 years. But the manufacturing capability to make tape in the lengths that would be required to make a reasonable fusion coil has just recently been developed,” says Luce. One of ITER’s magnets, the central solenoid, will produce a field of 13 tesla – 280,000 times Earth’s magnetic field.
The inner walls of ITER’s vacuum vessel, where the fusion will occur, will be lined with beryllium, a metal that won’t contaminate the plasma much if they touch. At the bottom is the divertor that will keep the temperature inside the reactor under control.
“The heat load on the divertor can be as large as in a rocket nozzle,” says Luce. “Rocket nozzles work because you can get into orbit within minutes and in space it’s really cold.” In a fusion reactor, a divertor would need to withstand this heat indefinitely and at ITER they’ll be testing one made out of tungsten.
Meanwhile, in the US, the National Spherical Torus Experiment – Upgrade (NSTX-U) fusion reactor will be fired up in the autumn of 2022, while efforts in advanced fission such as a mini-reactor design are also progressing. One of its priorities will be to see whether lining the reactor with lithium helps to keep the plasma stable.
Choosing a fuel Instead of just using deuterium as the fusion fuel, ITER will use deuterium mixed with tritium, another hydrogen isotope. The deuterium-tritium blend offers the best chance of getting significantly more power out than is put in. Proponents of fusion power say one reason the technology is safe is that the fuel needs to be constantly fed into the reactor to keep fusion happening, making a runaway reaction impossible.
Deuterium can be extracted from seawater, so there’s a virtually limitless supply of it. But only 20kg of tritium are thought to exist worldwide, so fusion power plants will have to produce it (ITER will develop technology to ‘breed’ tritium). While some radioactive waste will be produced in a fusion plant, it’ll have a lifetime of around 100 years, rather than the thousands of years from fission.
At the time of writing in September, researchers at the Joint European Torus (JET) fusion reactor in Oxfordshire were due to start their deuterium-tritium fusion reactions. “JET will help ITER prepare a choice of machine parameters to optimise the fusion power,” says Dr Joelle Mailloux, one of the scientific programme leaders at JET. These parameters will include finding the best combination of deuterium and tritium, and establishing how the current is increased in the magnets before fusion starts.
The groundwork laid down at JET should accelerate ITER’s efforts to accomplish net energy gain. ITER will produce ‘first plasma’ in December 2025 and be cranked up to full power over the following decade. Its plasma temperature will reach 150,000,000°C and its target is to produce 500 megawatts of fusion power for every 50 megawatts of input heating power.
“If ITER is successful, it’ll eliminate most, if not all, doubts about the science and liberate money for technology development,” says Luce. That technology development will be demonstration fusion power plants that actually produce electricity, where advanced reactors can build on decades of expertise. “ITER is opening the door and saying, yeah, this works – the science is there.”
Offshore Wind Cost Competitiveness is rising as larger turbines boost megawatt output, cut LCOE, and trim maintenance and installation time, enabling projects in New England to rival natural gas pricing while scaling reliably.
Key Points
It describes how larger offshore turbines lower LCOE and O&M, making U.S. projects price competitive with natural gas.
✅ Larger turbines boost MW output and reduce LCOE.
✅ Lower O&M and faster installation cut lifecycle costs.
✅ Competes with gas in New England bids, per BNEF.
Massive offshore wind turbines keep getting bigger, as projects like the biggest UK offshore wind farm come online, and that’s helping make the power cheaper — to the point where developers say new projects in U.S. waters can compete with natural gas.
The price “is going to be a real eye-opener,” said Bryan Martin, chairman of Deepwater Wind LLC, which won an auction in May to build a 400-megawatt wind farm southeast of Rhode Island.
Deepwater built the only U.S. offshore wind farm, a 30-megawatt project that was completed south of Block Island in 2016. The company’s bid was selected by Rhode Island the same day that Massachusetts picked Vineyard Wind to build an 800-megawatt wind farm in the same area, while international investors such as Japanese utilities in UK projects signal growing confidence.
#google#
Bigger turbines that make more electricity have cut the cost per megawatt by about half, a trend aided by higher-than-expected wind potential in many markets, said Tom Harries, a wind analyst at Bloomberg New Energy Finance. That also reduces maintenance expenses and installation time. All of this is helping offshore wind vie with conventional power plants.
“You could not build a thermal gas plant in New England for the price of the wind bids in Massachusetts and Rhode Island,” Martin said Friday at the U.S. Offshore Wind Conference in Boston. “It’s very cost-effective for consumers.”
The Massachusetts project could be about $100 to $120 a megawatt hour, according to a February estimate from Harries, though recent UK price spikes during low wind highlight volatility. The actual prices there and in Rhode Island weren’t disclosed.
For comparison, a new U.S. combine-cycle gas turbine ranges from $40 to $60 a megawatt-hour, and a new coal plant is $67 to $113, according to BNEF data.
A new power plant in land-constrained New England would probably be higher than that, and during winter peaks the region has seen record oil-fired generation in New England that underscores reliability concerns. More importantly, gas plants get a significant portion of their revenue from being able to guarantee that power is always available, something wind farms can’t do, said William Nelson, a New York-based analyst with BNEF. Looking only at the price at which offshore turbines can deliver electricity is a “narrow mindset,” he said.
Texas ERCOT Power Grid leads U.S. wind generation yet faces isolated interconnection, FERC exemption, and high industrial energy use, with distinct electricity and natural gas prices managed by a single balancing authority.
Key Points
The state-run interconnection that balances Texas electricity, isolated from FERC oversight and other U.S. grids.
✅ Largest U.S. wind power producer, high industrial demand
✅ Operates one balancing authority, independent interconnection
✅ Pays lower electricity, higher natural gas vs national average
For nearly two decades, the Lone Star State has generated more wind-sourced electricity than any other state in the U.S., according to the Energy Information Administration, or EIA.
In 2022, EIA reported Texas produced more electricity than any other state and generated twice as much as second-place Florida.
However, Texas also leads the country in another category. According to EIA, Texas is the largest energy-consuming state in the nation across all sectors with more than half of the state’s energy being used by the industrial sector.
As of May 2023, Texas residents paid 43% more for natural gas and around 10% less for electricity compared to the national average, according to EIA, and in competitive areas shopping for electricity is getting cheaper as well. Commercial and industrial sectors on average for the same month paid 25% less for electricity compared to the national average.
U.S. electric system compared to Texas The U.S. electric system is essentially split into three regions called interconnections and are managed by a total of 74 entities called balancing authorities that ensure that power supply and demand are balanced throughout the region to prevent the possibility of blackouts, according to EIA.
The three regions (Interconnections):
Eastern Interconnection: Covers all U.S. states east of the Rocky Mountains, a portion of northern Texas, and consists of 36 balancing authorities. Western Interconnection: Covers all U.S. states west of the Rockies and consists of 37 balancing authorities. ERCOT: Covers the majority of Texas and consists of one balancing authority (itself).
During the 2021 winter storm, Texas electric cooperatives were credited with helping maintain service in many communities.
“ERCOT is unique in that the balancing authority, interconnection, and the regional transmission organization are all the same entity and physical system,” according to EIA, a structure often discussed in analyses of Texas power grid challenges today.
With this being the case, Texas is the only state in the U.S. that balances itself, the only state that is not subject to the jurisdiction of the Federal Energy Regulatory Commission, or FERC, and the only state that is not synchronously interconnected to the grid in the rest of the United States in the event of tight grid conditions, highlighting ongoing discussions about improving Texas grid reliability before peak seasons, according to EIA.
Every other state in the U.S. is connected to a web of multiple balancing authorities that contribute to ensuring power supply and demand are met.
California, for example, was the fourth largest electricity producer and the third largest electricity consumer in the nation in 2022, according to EIA, and California imports the most electricity from other states while Pennsylvania exports the most.
Although California produces significantly less electricity than Texas, it has the ability to connect with more than 10 neighboring balancing authorities within the Western Interconnection to interchange electricity, a dynamic that can see clean states importing dirty electricity under certain market conditions. ERCOT being independent only has electricity interchange with two balancing authorities, one of which is in Mexico.
Regardless of Texas’ unique power structure compared to the rest of the nation, the vast majority of the U.S. risked electricity supplies during this summer’s high heat, as outlined in severe heat blackout risks reports, according to EIA.
CO2 Tax for UK Offshore Energy Efficiency can accelerate adoption of aero-derivative gas turbines, flare gas recovery, and combined cycle power, reducing emissions on platforms like Equinor's Mariner and supporting net zero goals.
Key Points
A carbon price pushing operators to adopt efficient turbines, flare recovery, and combined cycle to cut emissions.
✅ Aero-derivative turbines beat industrial units on efficiency
✅ Flare gas recovery cuts routine flaring and fuel waste
✅ Combined cycle raises efficiency and lowers emissions
By Tom Baxter
The recent Energy Voice article from the Equinor chairman concerning the Mariner project heralding a ‘significant point of reference’ for growth highlighted the energy efficiency achievements associated with the platform.
I view energy efficiency as a key enabler to net zero, and alongside this the UK must start large-scale storage to meet system needs; it is a topic I have been involved with for many years.
As part of my energy efficiency work, I investigated Norwegian practices and compared them with the UK.
There were many differences, here are three;
1. Power for offshore installations is usually supplied from gas turbines burning fuel from the oil and gas processing plant, and even as the UK's offshore wind supply accelerates, installations convert that to electricity or couple the gas turbine to a machine such as a gas compressor.
There are two main generic types of gas turbine – aero-derivative and industrial. As the name implies aero-derivatives are aviation engines used in a static environment. Aero-derivative turbines are designed to be energy efficient as that is very import for the aviation industry.
Not so with industrial type gas turbines; they are typically 5-10% less efficient than a comparable aero-derivative.
Industrial machines do have some advantages – they can be cheaper, require less frequent maintenance, they have a wide fuel composition tolerance and they can be procured within a shorter time frame.
My comparison showed that aero-derivative machines prevailed in Norway because of the energy efficiency advantages – not the case in the UK where there are many more offshore industrial gas turbines.
Tom Baxter is visiting professor of chemical engineering at Strathclyde University and a retired technical director at Genesis Oil and Gas Consultants
2. Offshore gas flaring is probably the most obvious source of inefficient use of energy with consequent greenhouse gas emissions.
On UK installations gas is always flared due to the design of the oil and gas processing plant.
Though not a large quantity of gas, a continuous flow of gas is routinely sent to flare from some of the process plant.
In addition the flare requires pilot flames to be maintained burning at all times and, while Europe explores electricity storage in gas pipes, a purge of hydrocarbon gas is introduced into the pipes to prevent unsafe air ingress that could lead to an explosive mixture.
On many Norwegian installations the flare system is designed differently. Flare gas recovery systems are deployed which results in no flaring during continuous operations.
Flare gas recovery systems improve energy efficiency but they are costly and add additional operational complexity.
3. Returning to gas turbines, all UK offshore gas turbines are open cycle – gas is burned to produce energy and the very hot exhaust gases are vented to the atmosphere. Around 60 -70% of the energy is lost in the exhaust gases.
Some UK fields use this hot gas as a heat source for some of the oil and gas treatment operations hence improving energy efficiency.
There is another option for gas turbines that will significantly improve energy efficiency – combined cycle, and in parallel plans for nuclear power under the green industrial revolution aim to decarbonise supply.
Here the exhaust gases from an open cycle machine are taken to a separate turbine. This additional turbine utilises exhaust heat to produce steam with the steam used to drive a second turbine to generate supplementary electricity. It is the system used in most UK power stations, even as UK low-carbon generation stalled in 2019 across the grid.
Open cycle gas turbines are around 30 – 40% efficient whereas combined cycle turbines are typically 50 – 60%. Clearly deploying a combined cycle will result in a huge greenhouse gas saving.
I have worked on the development of many UK oil and gas fields and combined cycle has rarely been considered.
The reason being is that, despite the clear energy saving, they are too costly and complex to justify deploying offshore.
However that is not the case in Norway where combined cycle is used on Oseberg, Snorre and Eldfisk.
What makes the improved Norwegian energy efficiency practices different from the UK – the answer is clear; the Norwegian CO2 tax.
A tax that makes CO2 a significant part of offshore operating costs.
The consequence being that deploying energy efficient technology is much easier to justify in Norway when compared to the UK.
Do we need a CO2 tax in the UK to meet net zero – I am convinced we do. I am in good company. BP, Shell, ExxonMobil and Total are supporting a carbon tax.
Not without justification there has been much criticism of Labour’s recent oil tax plans, alongside proposals for state-owned electricity generation that aim to reshape the power market.
To my mind Labour’s laudable aims to tackle the Climate Emergency would be much better served by supporting a CO2 tax that complements the UK's coal-free energy record by strengthening renewable investment.
Europe EV Sales Slowdown signals waning incentives, economic uncertainty, and supply chain constraints, threatening climate targets and net-zero emissions goals while highlighting the need for charging infrastructure, affordable batteries, and policy support across key markets.
Key Points
Europe's early-2024 EV registrations fell as incentives waned and supply gaps persisted, putting climate targets at risk.
✅ Fewer subsidies and tax breaks cut EV affordability
✅ Inflation and recession fears dampen car purchases
✅ Supply-chain and lithium constraints limit availability
A recent slowdown in Europe's electric vehicle (EV) sales raises serious concerns about the region's ability to achieve its ambitious climate targets. After years of steady growth, new EV registrations declined in key markets like Norway, Germany, and the U.K. in early 2024. Experts are warning that this slump jeopardizes the transition away from fossil fuels and could undermine Europe's commitment to a net-zero emissions future.
Factors Behind the Decline
Several factors are contributing to the slowdown in EV sales:
Reduced Incentives: Many European countries have scaled back generous subsidies and tax breaks for EV purchases. While these incentives played a crucial role in driving early adoption, their reduction has made EVs less financially attractive for some consumers, with many U.K. buyers citing higher prices even after discounts.
End of ICE Ban Support: Public support for phasing out gasoline and diesel-powered cars by 2035, a key European Union policy, appears to be waning in some areas. Without robust support for this measure, consumers may be less inclined to embrace the transition to electric vehicles.
Economic Uncertainty: Rising inflation and fears of a recession in Europe have made consumers hesitant to invest in big-ticket purchases like new cars, regardless of fuel type. This economic uncertainty is impacting both electric and conventional vehicle sales.
Supply Chain Constraints: Ongoing supply chain disruptions and shortages of raw materials like lithium continue to impact the availability of affordable electric vehicles. This means potential buyers face long wait times or inflated prices even when they're ready to embrace EVs.
Consequences for Europe's Green Agenda
The decline in EV sales threatens Europe's plans to reduce carbon emissions and become the first climate-neutral continent by 2050, aligning with a broader push for electricity to address the climate dilemma across Europe. The transportation sector is a major contributor to greenhouse gas emissions, and the rapid electrification of vehicles is a pillar of Europe's decarbonization strategy.
The current slump highlights the need for continued policy support for the EV market, as EVs still trail gas models in many markets today, to ensure long-term growth and affordability for consumers. Without action, experts fear that Europe may find itself locked into a dependence on fossil fuels for decades to come, making its climate targets unreachable.
A Global Concern
Europe is a leader in electric vehicle policies and technology, during a period when global EV sales climbed markedly. The recent slowdown, however, sends a worrying signal to other regions around the world aiming to accelerate their transition to electric vehicles, including the U.S. market's Q1 dip as a cautionary example. It underscores the importance of sustained government support, investment in charging infrastructure and overcoming supply chain challenges to secure a future of widespread electric vehicle use, with many forecasts suggesting mass adoption within a decade if support continues.
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