Lessons from GermanyÂ’s energy renaissance

By Globe and Mail


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Solar power will cost next to nothing. The fuel - the sun - is free. The price of the photovoltaic cells used to covert sunlight into electricity will plummet.

Just give it time.

That's the theory of Ian MacLellan, the founder, vice-chairman and chief technology officer of Arise Technologies, a Canadian photovoltaic (PV) cell company. But there's one small hitch: Arise doesn't have time.

PV cells are still expensive. The solar energy market needs priming. Arise shareholders want profits. Mr. MacLellan is 51 and would like to see his company make a buck before he's a senior citizen.

Enter Germany. The ever-so-generous Germans tracked him down and made him an offer he couldn't refuse - free money, and lots of it - as long as Arise promised to build a PV factory on German soil. The German love-fest even came with flowers for Mr. MacLellan's wife, Cathy.

Today, Arise's first factory is about a month away from completion in Bischofswerda, a pretty eastern German town about 35 kilometres east of Dresden, in the state of Saxony. Covering two storeys and 100,000 square feet, the sleek grey metal building will have some 150 employees and produce enough PV cells each year to power the equivalent of 60,000 houses. The value of the annual output, based on today's prices, will be $375-million, or more than three times the company's current value on the Toronto Stock Exchange.

"I couldn't build this in Canada," Mr. MacLellan said. "Germany is a very high-quality environment for us. I have nothing to worry about."

Arise couldn't build the plant in Canada because the level of financial incentives, engineering and construction expertise and general awareness of the growth potential of renewable energy simply don't exist there.

Those factors are abundant in Germany and it shows: The country has become the world leader in renewable energy technology, manufacturing, sales and employment. The German map is dotted with hundreds of renewable energy companies. They make PV cells, wind turbines, solar thermal panels, biofuels and technology for biomass plants and geothermal energy.

No PV cells are made in Canada. The Canadian solar industry, lured by money and markets, is jumping across the Atlantic and landing in Germany and a few other European countries with generous incentives.

The German and Saxony governments, with a little help from the European Union, offered Arise about €50-million ($80-million) in financing. The package included a 25-million euro grant, which is being used to offset half the cost of building the factory and installing the three assembly lines, and 22.5-million euro of working credit lines and equipment loans at highly attractive rates.

The land was cheap and included a handsome, though abandoned, brick building from 1818 that began life as an army barracks, became a dance hall after the First World War and a Soviet military barracks during the Cold War.

Arise plans to restore the old pile and use it as an office and corporate retreat. "We're turning an old military base into a solar factory - how 21st Century is that?" Mr. MacLellan asked.

Germany has created 240,000 jobs in the renewable energy industry, 140,000 of them since 2001, said Matthias Machnig, State Secretary for the federal Ministry of the Environment. Renewable energy technologies already make up 4 to 5 per cent of Germany's gross domestic product; Mr. Machnig expects the figure to rise to 16 per cent by 2025.

Renewables generated 14 per cent of the country's electricity last year, significantly ahead of the 12.5-per-cent target set for 2010. "We are making a huge investment in the markets of the future," Mr. Machnig said.

How did Germany turn green technology into a leading industry? And is the aggressive effort to attract renewable energy companies, backed by scads of taxpayers' money, a formula that should be imitated in Canada or its provinces? Mr. MacLellan thinks so. "I think Ontario is in a leading position to clone Germany," he said.

GermanyÂ’s vast renewable energy industry is a careful and deliberate blend of industrial, political and green policies. Wind power has been leading the charge. Germany is a windy country and the ubiquitous wind farms generated 7.4 per cent of Germany's electricity last year.

With onshore wind energy growth starting to level off - offshore wind probably will take off once favourable regulations are in place - the Germans are injecting the photovoltaic industry with growth hormones. "In a few years, the PV industry could be bigger than the German car industry," said Thomas Grigoleit, senior manager for renewable energy for Invest In Germany, a government investment agency.

It should come as little surprise that Germany has become green energy's focal point. The country is a natural resources desert. It lacks oil and natural gas and its coal production, which is heavily subsidized, is falling. The country has a moratorium on nuclear energy development. Renewable energy is more than just a feel-good exercise; Germany sees it as securing its energy future in a world of disappearing fossil fuels.

There's more to it than energy security. Germany is both latching onto, and propelling, an industrial trend. It wants to do to renewables what it did to the car industry; that is, create a jobs and export juggernaut. "We are at the beginning of the third industrial revolution," said Mr. Machnig, referring to the growth potential for renewable energy.

Germany is using its political might to ensure it benefits mightily from the green revolution. The country is Europe's biggest economy and the continent's (and the world's) biggest exporter. As the economic heavyweight, it has a lot of political influence over its neighbours, said Paul Dubois, Canada's ambassador to Germany. "This is the key country," he said.

Nineteen of the European Union's 27 countries count Germany as their main trading partner, he noted. The figure for France is only three (Germany, Spain and Malta) and only one (Ireland) for the United Kingdom.

The upshot: If Germany builds green technology such as wind turbines and solar panels, its friendly neighbours will be sure to buy them, or so the German government believes. That translates into the things politicians and economists like - jobs, export earnings, trade surpluses, international prestige.

There's more. As Europe's most influential country, Germany can pretty much guarantee that renewable energies will be the growth machine of the future. How? By insisting on aggressive, EU-wide carbon reduction targets, care of Angela Merkel, the German Chancellor who is no doubt the greenest European leader.

In February, the EU vowed to reduce greenhouse gas emissions by 20 per cent by 2020 and said it would try to raise the target to 30 per cent. "If you take climate change seriously, we have to reduce carbon dioxide emissions by 60 to 80 per cent by 2050," Mr. Machnig said. "This is the biggest industrial change ever. This means reducing emissions [in Germany] from 10 tonnes per capita to two to four tonnes per capita."

Germany doesn't think the reductions are possible without a broad effort that includes renewable energy, the EU emissions trading system and, of course, a fortune in subsidies to kick-start the green technologies and guarantee them a market for many years. The main subsidy for renewable energy generation is the "feed-in tariff," which was established in 2000 under the Renewable Energy Sources Act.

As far as subsidies go, this one is a beauty. The feed-in tariff for solar electricity is about 50 euro cents per kilowatt-hour, or almost 10 times higher than the market price for conventionally produced electricity (the subsidy for wind energy is considerably less, though still well above the market rate).

German utilities must by law buy the renewable electricity. The cost, in turn, is passed on to the consumer and is buried in his electricity bill. "The feed-in tariff has put Germany on the world [renewable energy] map," said Mikael Nielsen, the central European vice-president of sales for Vestas, the Danish wind turbine company that makes turbine blades in Germany. "If it weren't for the tariff, you wouldn't have a market like this."

The subsidy for all forms of green energy, largely wind, with solar just starting to come on strong, costs the government about €3.5-billion a year. The figure is expected to rise to €6-billion by 2015, and then will slowly decline. No wonder the renewable energy industry is on fire in Germany.

But Germany's lunge into renewable energy is not without its critics. The solar industry in particular is sucking up tens of billions of euros of grants and the question is whether taxpayers are getting value for money. "The construction of a solar power plant is currently an almost riskless investment," the German newspaper Berliner Zeitung said in November.

RWI Essen, a German economic research institute, published a paper earlier in March called "Germany's Solar Cell Promotion: Dark Clouds on the Horizon," which concluded the feed-in tariff has not accomplished two of the government's most cherished goals - job creation and carbon reduction.

The subsidies for German solar energy probably rank as the highest in the world, thanks to the feed-in tariff and other subsidies. RWI estimated the total subsidies per job created in the PV industry (based on the subsidies and direct PV employment in 2006) at an astounding €205,000.

The tariff has created more demand than the German PV market can satisfy. In fact, most of the PV cells have been imported, creating jobs abroad, not in Germany (though this may change as Germany attracts manufacturers like Arise). RWI argues that billions of euros in subsidies have crowded out investment in other, perhaps more promising, technologies and has probably made the PV industry less efficient that it might otherwise be.

RWI said "the subsidized market penetration of non-competitive technologies in their early stages of development diminishes the incentives to invest in the research and development necessary to achieve competitiveness."

Finally, RWI says the feed-in tariff "does not imply any additional emission reductions beyond those already achieved" by the EU emissions trading system. Its argument is that reductions under the cap-and-trade system would be made whether or not the feed-in tariff existed.

The indictment is dismissed by the German Environment Ministry and by the PV industry. Mr. MacLellan notes that every form of energy is subsidized to some degree and that the PV subsidies will help Arise's German factory become profitable quickly, allowing the business to pay income taxes within two years. "This is not charity," he said.

For his part, Mr. Machnig said the subsidies will help establish an export market - three-quarters of the wind turbines made in Germany are exported, for example - as the number of technology manufacturers expands. Furthermore, he said, renewable energy can only make Germany more competitive as the price of fossil fuels rises. By 2020, renewables will provide 27 per cent of Germany's electricity production.

Arise Technologies was launched in 1996 by Ian MacLellan, an amiable motormouth and Ryerson electrical engineering graduate who calls himself a "solar geek with a spread sheet." Five years later, it formed a partnership with the University of Toronto to develop a high-efficiency "thin-film-on-silicon-wafer" solar cell.

The company, whose headquarters are in Waterloo, Ont., went public in 2003 in Toronto (it's also listed in Frankfurt) and at times came close to running out of money. Its fortunes reversed in the past couple of years as energy prices soared and Arise displayed a remarkable talent for snagging government freebies. The feds' Sustainable Technology Development Canada fund handed the company $6.4-million in 2006. The general enthusiasm for clean energy technologies allowed Arise to raise $34.5-million in a bought deal last October.

The company's biggest break came entirely by accident. In March, 2006, a German PV magazine called Photon International carried a story on Arise. Two months later, Mr. MacLellan was in Hawaii for the World Photovoltaic Conference. "A guy from Invest In Germany tracked me down," he said. "We met and he said: 'We're very interested in your company and we want all the best companies to build in Germany. We'll give you half the money.'"

Invest In Germany has offices around the world (though not in Canada) and its 80 employees, most of them young, multilingual and highly educated, are considered superb salesmen and women. Its goal is to convince foreign companies to build plants and create employment in Germany and the appeal is quick, one-stop-shopping.

The team offers everything from assistance in site selection and construction engineering to German financing and incentives from the European Union. Boozing even features into the sales pitch. In the "Quality of Life" section of the promotional literature, the agency cheerily notes the country is home to "1,250 breweries with more than 5,000 different kinds of beer" (a statistic not lost on Mr. MacLellan, who loves German beer).

The agency has had particular success in attracting renewable energy companies. Some of the industry's best-known players - among them Shell Solar, EverQ, First Solar, Nanosolar and Signet Solar - have built factories in Germany and created thousands of jobs. "We work hard to find suitable companies," said Mr. Grigoleit of Invest In Germany. "We go to conferences and trade fairs. We open up kiosks and we have offices in Chicago, Boston, Shanghai, Tokyo and other cities. What we can offer is speed of entry into the German market."

Mr. MacLellan was impressed by Invest in Germany's efficiency. Within months of the Hawaii meeting, the financial and engineering machinery for the German plant were in place. The funding package, including the 25-million euro grant, was approved in December, 2006, only seven months after the Hawaii encounter. Construction of the factory started last August and the first cells will roll off the assembly by the end of April. "This is amazing," he said. "We've gone from the first meeting to production in less than two years."

He optimistically predicts PV cells made by Arise and other companies "will hit a wall of infinite demand" and he's evidently not alone. At last count about 55 solar companies had set up in Germany. The majority are in the former East Germany, where the incentives are fatter because the employment rate is lower than in the industrialized western half of the country.

There are a similar number of wind energy companies. More of both are coming. The German government's "GreenTech" environmental technology atlas, which describes the technologies and lists companies that develop and build them, runs 500 pages.

In July, a Quebec company called 5N Plus will open a plant in Eisenhuttenstadt, a town on the German-Polish border southeast of Berlin. The plant, its first foreign operation , will employ 45 and make high-purity metals for thin-film PV panels. Jacques L'Ecuyer, the CEO, said he built there because of the incentives - Germany provided about one-third of the plant's 9.5-million euro cost - and because he wanted guaranteed access to the European market. "If we have a presence in Germany, it will be easier for us to do business in Germany and in Europe," he said.

Canada seems to have taken notice of the German example. Make that parts of Canada.

The West is still obsessed with oil. Quebec has few incentives for wind and solar power, probably because it has so much cheap (and renewable) hydro power, Mr. L'Ecuyer said.

But Ontario, battered by manufacturing job losses and the high dollar, has made renewable energy part of its industrial salvation plane. The province now has its own feed-in tariff for renewable energy and recently announced a five-year $1.15-billion program, called the Next Generation of Jobs Fund, to help finance everything from "green" auto research to pharmaceuticals manufacturing. Arise may tap into the jobs fund to expand in the Waterloo area, where it is building a plant to refine silicon for PV cells.

Ontario's new incentives, Mr. MacLellan said, "are not as attractive as Germany's but they're getting close." With Germany still on top, Arise is already making plans to add a second, and possibly third, PV factory, in Bischofswerda, next to the one opening in April. Arise has more than enough available land and the town, one of eastern Germany's Cold War victims, would welcome the jobs.

More foreign companies are bound to rush to Germany while the financial goodies last. Mr. Grigoleit said Invest In Germany is targeting other Canadian renewable energy companies. He won't say how close they are snagging them but seems confident they will be unable to resist what he calls the "magnet" effect.

Even if Canada decides it wants a renewable energy industry of its own, it will face formidable competition from Germany.

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Investigation underway to determine cause of Atlanta Airport blackout

Atlanta Airport Power Outage disrupts Hartsfield-Jackson as an underground fire cripples switchgear redundancy, canceling flights during holiday travel; Georgia Power restores electricity overnight while utility crews probe causes and monitor system resilience.

 

Key Points

A major Hartsfield-Jackson blackout from an underground fire; power restored as switchgear redundancy is investigated.

✅ Underground fire near Plane Train tunnel damaged switchgear systems

✅ Over 1,100 flights canceled; holiday travel severely disrupted

✅ Georgia Power restored service; redundancy and root cause under review

 

Power has been restored at the world’s busiest airport after a massive outage Sunday afternoon left planes and passengers stranded for hours, forced airlines to cancel more than 1,100 flights and created a logistical nightmare during the already-busy holiday travel season.

An underground fire caused a complete power outage Sunday afternoon at Hartsfield-Jackson Atlanta International Airport, resulting in thousands of canceled flights at the world's busiest terminal and affecting travelers worldwide.

The massive outage didn’t just leave passengers stranded overnight Sunday, it also affected travelers with flights Monday morning schedules.

According to Paul Bowers, the president and CEO of Georgia Power,  “From our standpoint, we apologize for the inconvenience,” he said. The utility restored power to the airport shortly before midnight.

Utility Crews are monitoring the fixes that restored power and investigating what caused the fire and why it was able to damage redundant systems. Bowers said the fire occurred in a tunnel that runs along the path of the underground Plane Train tunnel near Concourse E.

Sixteen highly trained utility personnel worked in the passageway to reconnect the network.“Our investigation is going through the process of what do we do to ensure we have the redundancy going back at the airport, because right now we are a single source feed,” Bowers said.

“We will have that complete by the end of the week, and then we will turn to what caused the failure of the switchgear.”

Though the cause isn’t yet known, he said foul play is not suspected.“There are two things that could happen,” he said.

“There are inner workings of the switchgear that could create the heat that caused the fire, or the splicing going into that switchgear -- that the cable had a failure on that going into the switch gear.”

When asked if age of the system could have been a failure, Bowers said his company conducts regular inspections.“We constantly inspect,” he said. “We inspect on an annual basis to ensure the reliability of the network, and that redundancy is protection for the airport.”Bowers said he is not familiar with any similar fire or outage at the airport.

“The issue for us is to ensure the reliability is here and that it doesn’t happen again and to ensure that our network is resilient enough to withstand any kind of fire,” he said. He added that Georgia Power will seek to determine what can be done in the future to avoid a similar event, such as those experienced during regional outages in other communities.

 

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Nearly $1 Trillion in Investments Estimated by 2030 as Power Sector Transitions to a More Decarbonized and Flexible System

Distributed Energy Resources (DER) are surging as solar PV, battery storage, and demand response decarbonize power, cut costs, and boost grid resilience for utilities, ESCOs, and C&I customers through 2030.

 

Key Points

DER are small-scale, grid-connected assets like solar PV, storage, and demand response that deliver flexible power.

✅ Investments in DER to rise 75% by 2030; $846B in assets, $285B in storage.

✅ Residential solar PV: 49.3% of spend; C&I solar PV: 38.9% by 2030.

✅ Drivers: favorable policy, falling costs, high demand charges, decarbonization.

 

Frost & Sullivan's recent analysis, Growth Opportunities in Distributed Energy, Forecast to 2030, finds that the rate of annual investment in distributed energy resources (DER) will increase by 75% by 2030, with the market set for a decade of high growth. Favorable regulations, declining project and technology costs, and high electricity and demand charges are key factors driving investments in DER across the globe, with rising European demand boosting US solar equipment makers prospects in export markets. The COVID-19 pandemic will reduce investment levels in the short term, but the market will recover. Throughout the decade, $846 billion will be invested in DER, supported by a further $285 billion that will be invested in battery storage, with record solar and storage growth anticipated as installations and investments accelerate.

"The DER business model will play an increasingly pivotal role in the global power mix, as highlighted by BNEF's 2050 outlook and as part of a wider effort to decarbonize the sector," said Maria Benintende, Senior Energy Analyst at Frost & Sullivan. "Additionally, solar photovoltaic (PV) will dominate throughout the decade. Residential solar PV will account for 49.3% of total investment ($419 billion), though policy moves like a potential Solar ITC extension could pressure the US wind market, with commercial and industrial solar PV accounting for a further 38.9% ($330 billion)."

Benintende added: "In developing economies, DER offers a chance to bridge the electricity supply gap that still exists in a number of country markets. Further, in developed markets, DER is a key part of the transition to a cleaner and more resilient energy system, consistent with IRENA's renewables decarbonization findings across the energy sector."

DER offers significant revenue growth prospects for all key market participants, including:

  • Technology original equipment manufacturers (OEMs): Offer flexible after-sales support, including digital solutions such as asset integrity and optimization services for their installed base.
  • System integrators and installers: Target household customers and provide efficient and trustworthy solutions with flexible financial models.
  • Energy service companies (ESCOs): ESCOs should focus on adding DER deployments, in line with US decarbonization pathways and policy goals, to expand and enhance their traditional role of providing energy savings and demand-side management services to customers.

Utility companies: Deployment of DER can create new revenue streams for utility companies, from real-time and flexibility markets, and rapid solar PV growth in China illustrates how momentum in renewables can shape utility strategies.
Growth Opportunities in Distributed Energy, Forecast to 2030 is the latest addition to Frost & Sullivan's Energy and Environment research and analyses available through the Frost & Sullivan Leadership Council, which helps organizations identify a continuous flow of growth opportunities to succeed in an unpredictable future.

 

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Costa Rica hits record electricity generation from 99% renewable sources

Costa Rica Renewable Energy Record highlights 99.99% clean power in May 2019, driven by hydropower, wind, solar, geothermal, and biomass, enabling ICE REM electricity exports and reduced rates from optimized generation totaling 984.19 GWh.

 

Key Points

May 2019 benchmark: Costa Rica generated 99.99% of 984.19 GWh from renewables, shifting from imports to regional exports.

✅ 99.99% renewable share across hydro, wind, solar, geothermal, biomass

✅ 984.19 GWh generated; ICE suspended imports and exported via REM

✅ Geothermal output increased to offset dry-season hydropower variability

 

During the whole month of May 2019, Costa Rica generated a total of 984.19 gigawatt hours of electricity, the highest in the country’s history. What makes this feat even more impressive is the fact that 99.99% of this energy came from a portfolio of renewable sources such as hydropower, wind, biomass, solar, and geothermal.

With such a high generation rate, the state power company Instituto Costariccense de Electricidad (ICE) were able to suspend energy imports from the first week of May and shifted to exports, while U.S. renewable electricity surpassed coal in 2022 domestically. To date, the power company continues to sell electricity to the Regional Electricity Market (REM) which generates revenues and is likely to reduce local electricity rates, a trend echoed in places like Idaho where a vast majority of electricity comes from renewables.

The record-breaking power generation was made possible by optimization of the country’s renewable sources, much as U.S. wind capacity surpassed hydro capacity at the end of 2016 to reshape portfolios. As the period coincided with the tail end of the dry season, the geothermal quota had to be increased.

Costa Rica remains a leader in renewable power generation, whereas U.S. wind generation has become the most-used renewable source in recent years. In 2015, more than 98% of the country’s electrical generation came from renewable sources, while U.S. renewables hit a record 28% in April in one recent benchmark. Through the years, this figure has remained fairly constant despite dry bouts caused by the El Niño phenomenon, and U.S. solar generation also continued to rise.

 

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Kenney holds the power as electricity sector faces profound change

Alberta Electricity Market Reform reshapes policy under the UCP, weighing a capacity market versus energy-only design, AESO reliability rules, renewables targets, coal phase-out, carbon pricing, consumer rates, and investment certainty before AUC decisions.

 

Key Points

Alberta Electricity Market Reform is the UCP plan to reassess capacity vs energy-only, renewables, and carbon pricing.

✅ Reviews capacity market timeline and AESO procurement

✅ Alters subsidies for renewables; slows wind and solar growth

✅ Adjusts industrial carbon levy; audits Balancing Pool losses

 

Hearings kicked off this week into the future of the province’s electricity market design, amid an electricity market reshuffle pledged by the province, but a high-stakes decision about the industry’s fate — affecting billions of dollars in investment and consumer costs — won’t be made inside the meeting room of the Alberta Utilities Commission.

Instead, it will take place in the office of Jason Kenney, as the incoming premier prepares to pivot away from the seismic reforms to Alberta’s electricity sector introduced by the Notley government.

The United Conservative Party has promised to adopt market-based policies, reflecting changes to how Alberta produces and pays for power, that will reset how the sector operates, from its approach to renewable energy and carbon pricing to re-evaluating the planned transition to an electricity “capacity market.”

“Every ball in electricity is up in the air right now,” Vittoria Bellissimo, of the Industrial Power Consumers Association of Alberta, said Tuesday during a break in the commission hearings.

Industry players are uncertain how quickly the UCP will change direction on power policies, but there’s little doubt Kenney’s government will take a strikingly different approach to the sector that keeps the lights on in Alberta.

“There’s some things they are going to change that are going to impact the electricity industry significantly,” said Duane Reid-Carlson, chief executive of consultancy EDC Associates.

“But I don’t think it’s going to be upheaval. I think the new government will proceed with caution because electricity is the foundation of our economy.”

Alberta’s electricity market has been turned on its head in recent years due to the recession, power prices dropping to near two-decade lows and several transformative policies initiated by the NDP.

The Notley government’s climate plan included an accelerated phase-out of all coal-fired generation and set targets for more renewable energy.

The most significant, but least-understood, move has been the planned shift to an electricity capacity market in 2021.

Under the strategy, generators will no longer solely be paid for the power produced and sold into the market; they will also receive payments for having electricity capacity available to the grid on demand.

The change was recommended by the Alberta Electric System Operator (AESO) as a way to reduce price volatility and provide more reliability than the current energy-only market, which some argue needs more competition to deliver better outcomes.

The independent system operator and industry officials have spent more than two years planning the transition since the switch was announced in late 2016. Proposed rules for the new system, outlining market changes, are now being discussed at the Alberta Utilities Commission hearings.

However, there is no ironclad guarantee the system remake will go ahead following the UCP’s election victory last week — amid calls to scrap the overhaul from a Calgary retailer — it plans to study the issue further — while other substantive electricity changes are already in store.

The UCP has promised to end “costly subsidies” to renewable energy developments and abandon the NDP’s pledge to have such energy sources make up 30 per cent of all power generation by 2030.

It will remove the planned phase-out of coal-fired electricity generation, although federal regulations for a 2030 prohibition remain in place.

It will also ask the auditor general to conduct a special audit of the massive losses sustained by the province’s Balancing Pool due to power purchase arrangements being handed back to the agency three years ago.

While Kenney has pledged to cancel the provincewide carbon tax, a levy on large industrial greenhouse gas emitters (such has power plants) will still be charged, although at a reduced rate of $20 a tonne.

The biggest unknown remains the power market’s structure, which underpins how the entire system operates.

The UCP has promised to consult on the shift to the capacity market and report back to Albertans within 90 days.

The complex issue may sound like an eye-glazer, but it will have a profound effect on industry investment, as well as how much consumers pay on their monthly electricity bills.

A number of industry players worry the capacity market will lead AESO to procure more power than is necessary, foisting unnecessary costs onto all Albertans.

“I still have concerns for what the impact on consumers is going to be,” said energy market consultant Sheldon Fulton. “I’d love to see the capacity market go away.”

An analysis by EDC Associates found the transition to a capacity market will procure additional electricity before it’s needed, requiring consumers to pay up to 40 per cent more — an extra $1.4 billion — for power in 2021-22 than under the existing market structure.

“I don’t think there’s any prejudged outcome,” said Blake Shaffer, former head trader at TransAlta Corp. and a fellow-in-residence at the C.D. Howe Institute.

“But it really matters about getting this right.”

Evan Bahry, executive director of the Independent Power Producers Society of Alberta, said the fact the UCP’s review was confined to just 90 days is helpful, as it avoids throwing the entire industry into a prolonged period of uncertainty.

As for the greening of Alberta’s power grid, amid growing attention to clean grids and storage, the demise of the NDP’s Renewable Electricity Program will likely slow down the rapid pace of wind and solar development. But it’s unlikely to stop the growth trend as costs continue to fall for such developments.

“Renewables over the last number of years have evolved to the point that they make sense on a subsidy-free basis,” said Dan Balaban, CEO of Greengate Power Corp., which has developed 480 MW of wind power in Alberta and Ontario.

“There is a path to clean electricity ahead.”

Chris Varcoe is a Calgary Herald columnist.

 

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Ontario Launches Largest Competitive Energy Procurement in Province’s History

Ontario Competitive Energy Procurement accelerates renewables, boosts grid reliability, and invites competitive bids across solar, wind, natural gas, and storage, driving innovation, lower costs, and decarbonization to meet rising electricity demand and ensure power supply.

 

Key Points

Ontario Competitive Energy Procurement is a competitive bidding program to deliver reliable, low-carbon electricity.

✅ Competitive bids from renewables, gas, and storage

✅ Targets grid reliability, affordability, and emissions

✅ Phased evaluations: technical, financial, environmental

 

Ontario has recently marked a significant milestone in its energy sector with the launch of what is being touted as the largest competitive energy procurement process in the province’s history. This ambitious initiative is set to transform the province’s energy landscape through a broader market overhaul that fosters innovation, enhances reliability, and addresses the growing demands of Ontario’s diverse population.

A New Era of Energy Procurement

The Ontario government’s move to initiate this massive competitive procurement process underscores a strategic shift towards modernizing and diversifying the province’s energy portfolio. This procurement exercise will invite bids from a broad spectrum of energy suppliers and technologies, ranging from traditional sources like natural gas to renewable energy options such as solar and wind power. The aim is to secure a reliable and cost-effective energy supply that aligns with Ontario’s long-term environmental and economic goals.

This historic procurement process represents a major leap from previous approaches by emphasizing a competitive marketplace where various energy providers can compete on an equal footing through electricity auctions and transparent bidding. By doing so, the government hopes to drive down costs, encourage technological advancements, and ensure that Ontarians benefit from a more dynamic and resilient energy system.

Key Objectives and Benefits

The primary objectives of this procurement initiative are multifaceted. First and foremost, it seeks to enhance the reliability of Ontario’s electricity grid. As the province experiences population growth and increased energy demands, maintaining a stable and dependable supply of electricity is crucial, and interprovincial imports through an electricity deal with Quebec can complement local generation. This procurement process will help identify and integrate new sources of power that can meet these demands effectively.

Another significant goal is to promote environmental sustainability. Ontario has committed to reducing its greenhouse gas emissions through Clean Electricity Regulations and transitioning to a cleaner energy mix. By inviting bids from renewable energy sources and innovative technologies, the government aims to support its climate action plan and contribute to the province’s carbon reduction targets.

Cost-effectiveness is also a central focus of the procurement process. By creating a competitive environment, the government anticipates that energy providers will strive to offer more attractive pricing structures and fair electricity cost allocation practices for ratepayers. This, in turn, could lead to lower energy costs for consumers and businesses, fostering economic growth and improving affordability.

The Competitive Landscape

The competitive energy procurement process will be structured to encourage participation from a wide range of energy providers. This includes not only established companies but also emerging players and startups with innovative technologies. By fostering a diverse pool of bidders, the government aims to ensure that all viable options are considered, ultimately leading to a more robust and adaptable energy system.

Additionally, the process will likely involve various stages of evaluation, including technical assessments, financial analyses, and environmental impact reviews. This thorough evaluation will help ensure that selected projects meet the highest standards of performance and sustainability.

Implications for Stakeholders

The implications of this procurement process extend beyond just energy providers and consumers. Local communities, businesses, and environmental organizations will all play a role in shaping the outcomes. For communities, this initiative could mean new job opportunities and economic development, particularly in regions where new energy projects are developed. For businesses, the potential for lower energy costs and access to innovative energy solutions, including demand-response initiatives like the Peak Perks program, could drive growth and competitiveness.

Environmental organizations will be keenly watching the process to ensure that it aligns with broader sustainability goals. The inclusion of renewable energy sources and advanced technologies will be a critical factor in evaluating the success of the initiative in meeting Ontario’s climate objectives.

Looking Ahead

As Ontario embarks on this unprecedented energy procurement journey, the outcomes will be closely watched by various stakeholders. The success of this initiative will depend on the quality and diversity of the bids received, the efficiency of the evaluation process, and the ability to integrate new energy sources into the existing grid, while advancing energy independence where feasible.

In conclusion, Ontario’s launch of the largest competitive energy procurement process in its history is a landmark event that holds promise for a more reliable, sustainable, and cost-effective energy future. By embracing competition and innovation, the province is setting a new standard for energy procurement that could serve as a model for other regions seeking to modernize their energy systems. The coming months will be crucial in determining how this bold initiative will shape Ontario’s energy landscape for years to come.

 

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Will Iraq have enough electricity for coming hot summer days?

Iraq Electricity Crisis intensifies as summer heat drives demand; households face power outages, reliance on private generators, distorted tariffs, and strained grid capacity despite government reforms, Siemens upgrades, and IEA warnings.

 

Key Points

A supply-demand gap causing outages, generator reliance, and grid inefficiencies across Iraq, worsened by summer peaks.

✅ Siemens deal to upgrade generation and grid

✅ Progressive tariffs to curb demand and waste

✅ Private generators fill gaps but raise costs

 

At a demonstration in June 2018, protesters in Basra loaded a black box resembling a coffin with the inscription “Electricity” onto the roof of a car. This was one demonstration of how much of a political issue electricity is in Iraq.

With what is likely to be another hot summer ahead, there is increasing pressure on the Baghdad government to improve access to electricity and water.

Many Iraqis blame the government for not providing adequate services despite the country’s oil wealth. Protests in southern Iraq last year turned violent, with demonstrators attacking governmental and political parties’ buildings; in neighboring Iran, blackouts also sparked protests over outages.

“It is very hard” to deal with the electricity issues, said Iraqi journalist Methaq al-Fayyadh, adding that the lack of reliable electricity was not a new problem and affects most parts of the country.

Dozens of people protested June 1 in Karbala against prices for new generators and demanded an improvement to the electricity situation.

In anticipation of high temperatures during Eid al-Fitr, the Electricity Ministry called on governorates to adhere to allocated quotas and told the public to ration electricity.

“Outages remain a daily occurrence for most households because increasing generating capacity has been outrun by increasing demand for electricity, as surging demand worldwide demonstrates,” noted the International Energy Agency (IAE) in April.

This is particularly the case, the authors said, as the hot summer months, when temperatures can top 50 degrees Celsius, drive up the use of air conditioning.

The Iraqi government has made improving the electricity supply one of its priorities, including nuclear power plans under consideration. The Electricity Ministry, headed by Luay al-Khatteeb, announced in May that national electricity production had reached 17 gigawatts.

Khatteeb presented comparative electricity data for May from 2018 and 2019, indicating production increases on every day of the month. IEA data indicate that available electricity supply has increased over the past five years and the gap between supply and demand has widened.

The government signed an agreement with German company Siemens this year to upgrade Iraq’s electricity grid, and in parallel deals with Iran to rehabilitate and develop the grid were finalized, according to Iranian officials. The agreement “includes the addition of new and highly efficient power generation capacity, rehabilitation and upgrade of existing plants and the expansion of transmission and distribution networks,” Siemens said.

The Iraqi prime minister’s office said the 4-year plan would be worth $15.7 billion. The first phase includes the installation of 13 transformer stations, cooling systems for power stations and building a 500-megawatt, gas-fired power plant south of Baghdad.

In an interview with Al-Monitor, Khatteeb said radical changes would happen in 2020, stating that the current situation was not “ideal” but “better” because of steps taken to create more energy, amid discussions on energy cooperation with Iran that could shape implementation.

Robert Tollast, of the Iraq Energy Institute, said the economics of the electricity system is distorted. Subsidies ensured that electricity provided by the national grid is almost free, he said. However, while the subsidies were designed to help the poor, the tariff system disadvantages them and does not create incentives to consume electricity more efficiently, he said.

A large part of families’ electricity expenditures goes to operators of privately owned generators, which run on fuel. These neighbourhood generators are used to close gaps in the electricity supply but are expensive, and regional fuel arrangements such as ENOC’s swap of Iraqi fuel have highlighted supply constraints. Generator operators have sometimes worked with armed groups to prevent upgrades to the grid that could hurt their business.

Until 1990, the Iraq electricity sector was considered among the best in the region. That legacy was destroyed by successive wars and international sanctions. With Iraq’s population growing at a rate of 1 million per year, peak demand is projected to double by 2030 if left unchecked, the IEA estimated.

Tollast said efforts to improve the distribution system and increase capacity are key but it is important “to tackle the problem from the demand side.” This entails implementing a progressive tariff scheme so users pay more if they consume more, he said. There is a “tremendous use of energy per capita in Iraq,” Tollast said.

In the current tariff structure, consumers pay a fixed price if they use more than 4,000-kilowatt hours per year, a relatively low amount, meaning the price per unit drops the more one consumes.

Any change to the tariff system must be accompanied by a “political campaign” to explain the changes, said Tollast, adding that more investment in the electricity sector and a “change in culture” of using electricity was needed. “The current system is unsustainable, even with high oil prices,” he said.

Fayyadh said people don’t expect the government will be able to fix the electricity issue before summer, having failed to do so in the past.

Tollast struck a more optimistic tone, saying it was unlikely that Iran, which supplies about 40% of Iraq’s power, would cut its export of electricity to Iraq this year as it did in 2018. He added that the water situation was better than last year when the country experienced drought. Iraq has also been processing more flare gas, which can be used to generate electricity.

“There is an expectation that this year might not be as bad as last year,” he concluded.

 

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