NYISO Issues 2013 to 2017 Strategic Plan

By The New York Independent System Operator NYISO


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RENSSELAER, N.Y.— Enhancement of electric grid reliability through improved power flows, market coordination, technological innovation and collaborative planning are key elements of the New York Independent System Operator NYISO 2013 to 2017 Strategic Plan.

The five-year plan, approved by the NYISO Board of Directors, incorporates long-term objectives, financial discipline and operational priorities based on the boardÂ’s review of the economic and regulatory outlook, economic and environmental factors affecting market participants and the growing interest in using competitive wholesale electricity markets to achieve public policy priorities.

“We see a growing need for interregional cooperation among markets to optimize grid operations, enhance market efficiency, implement comprehensive system planning and integrate technological advances into the grid to help consumers realize benefits from competitive wholesale markets,” said NYISO Board Chair Robert Hiney.

At the center of the NYISOÂ’s strategic plan is a vision of broader regional markets based on collaborative efforts among neighboring grid operators to optimize system efficiency and preserve reliability through the shared use of grid resources. This strategic vision acknowledges that reliability and economic efficiencies will be enhanced through expanded planning and operational coordination among market administrators.

Broadening the pool of grid resources through enhanced market design will expand competition and enable operators to better respond to dynamic market and operating conditions across market borders.

To achieve its regional strategy, the NYISO envisions: Optimizing the economic flow of electricity across borders through improved coordination of market rules and the increased flow of real-time data on system conditions Coordinating planning processes that facilitate transmission investments in support of reliability, economic efficiency and public policy activities Deploying smart grid technologies that maintain system balance through the use of robust data, communications and automated systems.

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This kite could harness more of the world's wind energy

Autonomous Energy Kites harness offshore wind on floating platforms, using carbon fiber wings, tethers, and rotors to generate grid electricity; an airborne wind energy solution backed by Alphabet's Makani to cut turbine costs.

 

Key Points

Autonomous Energy Kites are tethered craft that capture winds with rotors, generating grid power from floating platforms.

✅ Flies circles on tethers; rotors drive generators to feed the grid.

✅ Operates over deep-sea winds where fixed turbines are impractical.

✅ Lighter, less visual impact, and lower installation costs offshore.

 

One company's self-flying energy kite may be the answer to increasing wind power around the world, alongside emerging wave power solutions as well.

California-based Makani -- which is owned by Google's parent company, Alphabet -- is using power from the strongest winds found out in the middle of the ocean, where the offshore wind sector has huge potential, typically in spots where it's a challenge to install traditional wind turbines. Makani hopes to create electricity to power communities across the world.

Despite a growing number of wind farms in the United States and the potential of this energy source, lessons from the U.K. underscore how to scale, yet only 6% of the world's electricity comes from wind due to the the difficulty of setting up and maintaining turbines, according to the World Wind Energy Association.

When the company's co-founders, who were fond of kiteboarding, realized deep-sea winds were largely untapped, they sought to make that energy more accessible. So they built an autonomous kite, which looks like an airplane tethered to a base, to install on a floating platform in water, as part of broader efforts to harness oceans and rivers for power across regions. Tests are currently underway off the coast of Norway.

"There are many areas around the world that really don't have a good resource for renewable power but do have offshore wind resources," Makani CEO Fort Felker told Rachel Crane, CNN's innovation correspondent. "Our lightweight kites create the possibility that we could tap that resource very economically and bring renewable power to hundreds of millions of people."

This technology is more cost-efficient than a traditional wind turbine, which is a lot more labor intensive and would require lots of machinery and installation.

The lightweight kite, which is made of carbon fiber, has an 85-foot wingspan. The kite launches from a base station and is constrained by a 1,400-foot tether as it flies autonomously in circles with guidance from computers. Crosswinds spin the kite's eight rotors to move a generator that produces electricity that's sent back to the grid through the tether.

The kites are still in the prototype phase and aren't flown constantly right now as researchers continue to develop the technology. But Makani hopes the kites will one day fly 24/7 all year round. When the wind is down, the kite will return to the platform and automatically pick back up when it resumes.

Chief engineer Dr. Paula Echeverri said the computer system is key for understanding the state of the kite in real time, from collecting data about how fast it's moving to charting its trajectory.

Echeverri said tests have been helpful in establishing what some of the challenges of the system are, and the team has made adjustments to get it ready for commercial use. Earlier this year, the team successfully completed a first round of autonomous flights.

Working in deeper water provides an additional benefit over traditional wind turbines, according to Felker. By being farther offshore, the technology is less visible from land, and the growth of offshore wind in the U.K. shows how coastal communities can adapt. Wind turbines can be obtrusive and impact natural life in the surrounding area. These kites may be more attractive to areas that wish to preserve their scenic coastlines and views.

It's also desirable for regions that face constraints related to installing conventional turbines -- such as island nations, where World Bank support is helping developing countries accelerate wind adoption, which have extremely high prices for electricity because they have to import expensive fossil fuels that they then burn to generate electricity.

Makani isn't alone in trying to bring novelty to wind energy. Several others companies such as Altaeros Energies and Vortex Bladeless are experimenting with kites of their own or other types of wind-capture methods, such as underwater kites that generate electricity, a huge oscillating pole that generates energy and a blimp tethered to the ground that gathers winds at higher altitudes.

 

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Independent power project announced by B.C. Hydro now in limbo

Siwash Creek Hydroelectric Project faces downsizing under a BC Hydro power purchase agreement, with run-of-river generation, high grid interconnection costs, First Nations partnership, and surplus electricity from Site C reshaping clean energy procurement.

 

Key Points

A downsized run-of-river plant in BC, co-owned by Kanaka Bar and Green Valley, selling power via a BC Hydro PPA.

✅ Approved at 500 kW under a BC Hydro clean-energy program

✅ Grid interconnection initially quoted at $2.1M

✅ Joint venture: Kanaka Bar and Green Valley Power

 

A small run-of-river hydroelectric project recently selected by B.C. Hydro for a power purchase agreement may no longer be financially viable.

The Siwash Creek project was originally conceived as a two-megawatt power plant by the original proponent Chad Peterson, who holds a 50-per-cent stake through Green Valley Power, with the Kanaka Bar Indian Band holding the other half.

The partners were asked by B.C. Hydro to trim the capacity back to one megawatt, but by the time the Crown corporation announced its approval, it agreed to only half that — 500 kilowatts — under its Standing Order clean-energy program.

“Hydro wanted to charge us $2.1 million to connect to the grid, but then they said they could reduce it if we took a little trim on the project,” said Kanaka Bar Chief Patrick Michell.

The revenue stream for the band and Green Valley Power has been halved to about $250,000 a year. The original cost of running the $3.7-million plant, including financing, was projected to be $273,000 a year, according to the Kanaka Bar economic development plan.

“By our initial forecast, we will have to subsidize the loan for 20 years,” said Michell. “It doesn’t make any sense.”

The Kanaka Band has already invested $450,000 in feasibility, hydrology and engineering studies, with a similar investment from Green Valley.

B.C. Hydro announced it would pursue five purchase agreements last March with five First Nations projects — including Siwash Creek — including hydro, solar and wind energy projects, as two new generating stations were being commissioned at the time. A purchase agreement allows proponents to sell electricity to B.C. Hydro at a set price.

However, at least ten other “shovel-ready” clean energy projects may be doomed while B.C. Hydro completes a review of its own operations and its place in the energy sector, where legal outcomes like the Squamish power project ruling add uncertainty, including B.C.’s future power needs.

With the 1,100-megawatt Site C Dam planned for completion in 2024, and LNG demand cited to justify it, B.C. Hydro now projects it will have a surplus of electricity until the early 2030s.

Even if British Columbians put 300,000 electric vehicles on the road over the next 12 years, amid BC Hydro’s first call for power, they will require only 300 megawatts of new capacity, the company said.

A long-term surplus could effectively halt all small-scale clean energy development, according to Clean Energy B.C., even as Hydro One’s U.S. coal plant remains online in the region.

“(B.C. Hydro) dropped their offer down to 500 kilowatts right around the time they announced their review,” said Michell. “So we filled out the paperwork at 500 kilowatts and (B.C. Hydro) got to make its announcement of five projects.”

In the new few weeks, Kanaka and Green Valley will discuss whether they can move forward with a new financial model or shelve the project, he said.

B.C. Hydro declined to comment on the rationale for downsizing Siwash Creek’s power purchase agreement.

The Kanaka Bar Band successfully operates a 49.9-megawatt run-of-river plant on Kwoiek Creek with partners Innergex Renewable Energy.

 

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Shocking scam: fraudster pretending to be from BC Hydro attempts to extort business

BC Hydro Bitcoin Scam targets small businesses with utility impersonation, call spoofing, and disconnection threats, demanding prepaid cards, cash cards, or bitcoin. Learn payment policies and key warning signs to avoid costly power shutoffs.

 

Key Points

A phone fraud where impostors threaten power disconnection and demand immediate payment via bitcoin or prepaid cards.

✅ Demands bitcoin, cash cards, or prepaid credit within minutes

✅ Uses caller ID spoofing and utility impersonation tactics

✅ BC Hydro never takes bitcoin or prepaid cards for bills

 

'I've gotta give him very high marks for being a good scammer,' says almost-fooled business owner

It's an old scam with a new twist.

Fraudsters pretending to be BC Hydro representatives are threatening to disconnect small business owners' power, mirroring Toronto Hydro scam warnings recently, unless they send in cash cards, prepaid credit cards or even bitcoin right away.

Colin Mackintosh, owner of Trans National Art in Langley, B.C., said he almost was fooled by one such scammer.

It was just before quitting time on Thursday at his shop when he got an unpleasant phone call.

"The phone rings. My partner hands me the phone and this fellow says to me that he's outside, he works with BC Hydro and he has a disconnect notice," Mackintosh said.

The caller, Mackintosh said, claimed that if an immediate payment wasn't made they'd cut off the company's power.

'Very well done'

BC Hydro says the scam has been around for a while, and amid commercial power use during COVID-19 in B.C., demanding payment in bitcoin is a new wrinkle.

Fraudsters mostly target small businesses because losing their power for a day or two would be a huge financial hit, a spokesperson said.

Mackintosh said the scammer knew all about the business. His number even showed up as BC Hydro on the call display, and the utility has faced scrutiny in a regulator report unrelated to such scams.

"He had all the answers to every question I seemed to have for him.  Very professional. Very well done. I've gotta give him very high marks for being a good scammer," Mackintosh said.

The caller demanded Mackintosh make an immediate payment at the nearest BC Hydro kiosk. Mackintosh was directed to drive to a certain address to make the payment.

He was ready to pay hundreds of dollars but when he got to the address, there was no kiosk: just a tire shop and inside something that looked like a cash machine but was actually a bitcoin ATM.

"At the very top of it, in little letters, it said 'Bit Coin,'" Mackintosh said. "As soon as I saw those two words, I told him in two expressive words what I thought of him and I hung up the phone."

 

Scam increasing

BC Hydro spokesperson Mora Scott said fraudsters target small businesses because their livelihoods depend on power, and customers face pressures highlighted in a deferred costs report as well.

"Fraudsters will reach out to our customers pretending to be B.C. Hydro representatives," said Scott.

"They'll demand an immediate payment or they'll disconnect their power. This did start to surface around 2015 but we have seen an increase recently."

Scott said that BC Hydro will never ask for banking information over the phone and does not accept cash card, prepaid credit cards or bitcoin as payment, and customers can consult BC Hydro bill relief for legitimate assistance.

 

 

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Experts Advise Against Cutting Quebec's Energy Exports Amid U.S. Tariff War

Quebec Hydropower Export Retaliation examines using electricity exports to counter U.S. tariffs amid Canada-U.S. trade tensions, weighing clean energy supply, grid reliability, energy security, legal risks, and long-term market impacts.

 

Key Points

Using Quebec electricity exports as leverage against U.S. tariffs, and its economic, legal, and diplomatic consequences.

✅ Revenue loss for Quebec and higher costs for U.S. consumers

✅ Risk of legal disputes under trade and energy agreements

✅ Long-term erosion of market share and grid cooperation

 

As trade tensions between Canada and the United States continue to escalate, with electricity exports at risk according to recent reporting, discussions have intensified around potential Canadian responses to the imposition of U.S. tariffs. One of the proposals gaining attention is the idea of reducing or even halting the export of energy from Quebec to the U.S. This measure has been suggested by some as a potential countermeasure to retaliate against the tariffs. However, experts and industry leaders are urging caution, emphasizing that the consequences of such a decision could have significant economic and diplomatic repercussions for both Canada and the United States.

Quebec plays a critical role in energy trade, particularly in supplying hydroelectric power to the United States, especially to the northeastern states, including New York where tariffs may spike energy prices according to analysts, strengthening the case for stable cross-border flows. This energy trade is deeply embedded in the economic fabric of both regions. For Quebec, the export of hydroelectric power represents a crucial source of revenue, while for the U.S., it provides access to a steady and reliable supply of clean, renewable energy. This mutually beneficial relationship has been a cornerstone of trade between the two countries, promoting economic stability and environmental sustainability.

In the wake of recent U.S. tariffs on Canadian goods, some policymakers have considered using energy exports as leverage, echoing threats to cut U.S. electricity exports in earlier disputes, to retaliate against what is viewed as an unfair trade practice. The idea is to reduce or stop the flow of electricity to the U.S. as a way to strike back at the tariffs and potentially force a change in U.S. policy. On the surface, this approach may appear to offer a viable means of exerting pressure. However, experts warn that such a move would be fraught with significant risks, both economically and diplomatically.

First and foremost, Quebec's economy is heavily reliant on revenue from hydroelectric exports to the U.S. Any reduction in these energy sales could have serious consequences for the province's economic stability, potentially resulting in job losses and a decrease in investment. The hydroelectric power sector is a major contributor to Quebec's GDP, and recent events, including a tariff threat delaying a green energy bill in Quebec, illustrate how trade tensions can ripple through the policy landscape, while disrupting this source of income could harm the provincial economy.

Additionally, experts caution that reducing energy exports could have long-term ramifications on the energy relationship between Quebec and the northeastern U.S. These two regions have developed a strong and interconnected energy network over the years, and abruptly cutting off the flow of electricity could damage this vital partnership. Legal challenges could arise under existing trade agreements, and even as tariff threats boost support for Canadian energy projects among some stakeholders, the situation would grow more complex. Such a move could also undermine trust between the two parties, making future negotiations on energy and other trade issues more difficult.

Another potential consequence of halting energy exports is that U.S. states may seek alternative sources of energy, diminishing Quebec's market share in the long run. As the U.S. has a growing demand for clean energy, especially as it looks to transition away from fossil fuels, and looks to Canada for green power in several regions, cutting off Quebec’s electricity could prompt U.S. states to invest in other forms of energy, including renewables or even nuclear power. This could have a lasting effect on Quebec's position in the U.S. energy market, making it harder for the province to regain its footing.

Moreover, reducing or ceasing energy exports could further exacerbate trade tensions, leading to even greater economic instability. The U.S. could retaliate by imposing additional tariffs on Canadian goods or taking other measures that would negatively impact Canada's economy. This could create a cycle of escalating trade barriers that would hurt both countries and undermine the broader North American trade relationship.

While the concept of using energy exports as a retaliatory tool may seem appealing to some, the experts' advice is clear: the potential economic and diplomatic costs of such a strategy outweigh the short-term benefits. Quebec’s role as an energy supplier to the U.S. is crucial to its own economy, and maintaining a stable, reliable energy trade relationship is essential for both parties. Rather than escalating tensions further, it may be more prudent for Canada and the U.S. to seek diplomatic solutions that preserve trade relations and minimize harm to their economies.

While the idea of using Quebec’s energy exports as leverage in response to U.S. tariffs may appear attractive on the surface, and despite polls showing support for tariffs on energy and minerals among Canadians, it carries significant risks. Experts emphasize the importance of maintaining a stable energy export strategy to protect Quebec’s economy and preserve positive diplomatic relations with the U.S. Both countries have much to lose from further escalating trade tensions, and a more measured approach is likely to yield better outcomes in the long run.

 

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Europe's Worst Energy Nightmare Is Becoming Reality

European Energy Crisis shocks markets as Russia slashes gas via Nord Stream, spiking prices and triggering rationing, LNG imports, storage shortfalls, and emergency measures to secure energy security before a harsh winter.

 

Key Points

Europe-wide gas shock from reduced Russian flows drives price spikes, rationing risk, LNG reliance, and emergency action.

✅ Nord Stream cuts deepen supply insecurity and storage gaps

✅ LNG imports rise but terminal capacity and shipping are tight

✅ Policy tools: rationing, subsidies, demand response, coal restarts

 

As Russian gas cutoffs upend European energy security, the continent is struggling to cope with what experts say is one of its worst-ever energy crises—and it could still get much worse. 

For months, European leaders have been haunted by the prospect of losing Russia’s natural gas supply, which accounts for some 40 percent of European imports and has been a crucial energy lifeline for the continent. That nightmare is now becoming a painful reality as Moscow slashes its flows in retaliation for Europe’s support for Ukraine, dramatically increasing energy prices and forcing many countries to resort to emergency plans, including emergency measures to limit electricity prices in some cases, and as backup energy suppliers such as Norway and North Africa are failing to step up.

“This is the most extreme energy crisis that has ever occurred in Europe,” said Alex Munton, an expert on global gas markets at Rapidan Energy Group, a consultancy. “Europe [is] looking at the very real prospect of not having sufficient gas when it’s most needed, which is during the coldest part of the year.”

“Prices have shot through the roof,” added Munton, who noted that European natural gas prices—nearly $50 per MMBTu—have eclipsed U.S. price rises by nearly tenfold, and that rolling back electricity prices is tougher than it appears in the current market. “That is an extraordinarily high price to be paying for natural gas, and really there is no immediate way out from here.” 

Many officials and energy experts worry that the crisis will only deepen after Nord Stream 1, the largest gas pipeline from Russia to Europe, is taken down for scheduled maintenance this week. Although the pipeline is supposed to be under repair for only 10 days, the Kremlin’s history of energy blackmail and weaponization has stoked fears that Moscow won’t turn it back on—leaving heavily reliant European countries in the lurch. (Russia’s second pipeline to Germany, Nord Stream 2, was killed in February as Russian President Vladimir Putin prepared to invade Ukraine, leaving Nord Stream 1 as the biggest direct gas link between Russia and Europe’s biggest economy.)

“Everything is possible. Everything can happen,” German economy minister Robert Habeck told Deutschlandfunk on Saturday. “It could be that the gas flows again, maybe more than before. It can also be the case that nothing comes.”

That would spell trouble for the upcoming winter, when demand for energy surges and having sufficient natural gas is necessary for heating. European countries typically rely on the summer months to refill their gas storage facilities. And at a time of war, when the continent’s future gas supply is uncertain, having that energy cushion is especially crucial.

If Russia’s prolonged disruptions continue, experts warn of a difficult winter: one of potential rationing, industrial shutdowns, and even massive economic dislocation. British officials, who just a few months ago warned of soaring power bills for consumers, are now warning of even worse, despite a brief fall to pre-Ukraine war levels in gas prices earlier in the year.

Europe could face a “winter of discontent,” said Helima Croft, a managing director at RBC Capital Markets. “Rationing, industrial shut-ins—all of that is looming.”

Unrest has already been brewing, with strikes erupting across the continent as households struggle under the pressures of spiraling costs of living and inflationary pressures. Some of this discontent has also had knock-on effects in the energy market. In Norway, the European Union’s biggest supplier of natural gas after Russia, mass strikes in the oil and gas industries last week forced companies to shutter production, sending further shockwaves throughout Europe.

European countries are at risk of descending into “very, very strong conflict and strife because there is no energy,” Frans Timmermans, the vice president of the European Commission, told the Guardian. “Putin is using all the means he has to create strife in our societies, so we have to brace ourselves for a very difficult period.”

The pain of the crisis, however, is perhaps being felt most clearly in Germany, which has been forced to turn to a number of energy-saving measures, including rationing heated water and closing swimming pools. To cope with the crunch, Berlin has already entered the second phase of its three-stage emergency gas plan; last week, it also moved to bail out its energy giants amid German utility troubles that have been financially slammed by Russian cutoffs. 

But it’s not just Germany. “This is happening all across Europe,” said Olga Khakova, an expert on European energy security at the Atlantic Council, who noted that France has also announced plans to nationalize the EDF power company as it buckles under mounting economic losses, and the EU outlines gas price cap strategies to temper volatility. “The challenging part is how much can these governments provide in support to their energy consumers, to these companies? And what is that breaking point?”

The situation has also complicated many countries’ climate goals, even as some call it a wake-up call to ditch fossil fuels for Europe. In late June, Germany, Italy, Austria, and the Netherlands announced they would restart old coal power plants as they grapple with shrinking supplies. 

The potential outcomes that European nations are grappling with reveal how this crisis is occurring on a scale that has only been seen in times of war, Munton said. In the worst-case scenario, “we’re talking about rationing gas supplies, and this is not something that Europe has had to contend with in any other time than the wartime,” he said. “That’s essentially where things have got to now. This is an energy war.”

They also underscore the long and painful battle that Europe will continue to face in weaning itself off Russian gas. Despite the continent’s eagerness to leave Moscow’s supply behind, experts say Europe will likely remain trapped in this spiraling crisis until it can develop the infrastructure for greater energy independence—and that could take years. U.S. gas, shipped by tanker, is one option, but that requires new terminals to receive the gas and U.S. energy impacts remain a factor for policymakers. New pipelines take even longer to build—and there isn’t a surfeit of eligible suppliers.

Until then, European leaders will continue to scramble to secure enough supplies—and can only hope for mild weather. The “worst-case scenario is people having to choose between eating and heating come winter,” Croft said. 

 

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BloombergNEF: World offshore wind costs 'drop 32% per cent'

Global Renewable LCOE Trends reveal offshore wind costs down 32%, with 10MW turbines, lower CAPEX and OPEX, and parity for solar PV and onshore wind in Europe, China, and California, per BloombergNEF analysis.

 

Key Points

Benchmarks showing falling LCOE for offshore wind, onshore wind, and solar PV, driven by larger turbines and lower CAPEX

✅ Offshore wind LCOE $78/MWh; $53-64/MWh in DK/NL excl. transmission

✅ Onshore wind $47/MWh; solar PV $51/MWh, best $26-36/MWh

✅ Cost drivers: 10MW turbines, lower CAPEX/OPEX, weak China demand

 

World offshore wind costs have fallen 32% from just a year ago and 12% compared with the first half of 2019, according to a BNEF long-term outlook from BloombergNEF.

In its latest Levelized Cost of Electricity (LCOE) Update, BloombergNEF said its current global benchmark LCOE estimate for offshore wind is $78 a megawatt-hour.

“New offshore wind projects throughout Europe, including the UK's build-out, now deploy turbines with power ratings up to 10MW, unlocking CAPEX and OPEX savings,” BloombergNEF said.

In Denmark and the Netherlands, it expects the most recent projects financed to achieve $53-64/MWh excluding transmission.

New solar and onshore wind projects have reached parity with average wholesale power prices in California and parts of Europe, while in China levelised costs are below the benchmark average regulated coal price, according to BloombergNEF.

The company's global benchmark levelized cost figures for onshore wind and PV projects financed in the last six months are at $47 and $51 a megawatt-hours, underscoring that renewables are now the cheapest new electricity option in many regions, down 6% and 11% respectively compared with the first half of 2019.

BloombergNEF said for wind this is mainly down to a fall in the price of turbines – 7% lower on average globally compared with the end of 2018.

In China, the world’s largest solar market, the CAPEX of utility-scale PV plants has dropped 11% in the last six months, reaching $0.57m per MW.

“Weak demand for new plants in China has left developers and engineering, procurement and construction firms eager for business, and this has put pressure on CAPEX,” BloombergNEF said.

It added that estimates of the cheapest PV projects financed recently – in India, Chile and Australia – will be able to achieve an LCOE of $27-36/MWh, assuming competitive returns for their equity investors.

Best-in-class onshore wind farms in Brazil, India, Mexico and Texas can reach levelized costs as low as $26-31/MWh already, the research said.

Programs such as the World Bank wind program are helping developing countries accelerate wind deployment as costs continue to drop.

BloombergNEF associate in the energy economics team Tifenn Brandily said: “This is a three- stage process. In phase one, new solar and wind get cheaper than new gas and coal plants on a cost-of- energy basis.

“In phase two, renewables reach parity with power prices. In phase three, they become even cheaper than running existing thermal plants.

“Our analysis shows that phase one has now been reached for two-thirds of the global population.

“Phase two started with California, China and parts of Europe. We expect phase three to be reached on a global scale by 2030.

“As this all plays out, thermal power plants will increasingly be relegated to a balancing role, looking for opportunities to generate when the sun doesn’t shine or the wind doesn’t blow.”

 

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