Swiss electricity getting cleaner, says energy report


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Switzerland Renewable Power Mix shows 62 percent renewables in 2016, led by hydropower, with solar, wind, and biomass growing as nuclear declines under Energy Strategy 2050, while unverified imports include fossil fueled European market electricity.

 

Key Points

2016 Swiss power mix: 62% renewables led by hydropower, with nuclear declining and solar, wind, and biomass rising.

✅ Hydropower supplies 56% of electricity consumption.

✅ Other renewables total 5.9%: solar, wind, biomass.

✅ Nuclear share fell to 17% as phaseout advances.

 

The electricity consumed in Switzerland is ever greener, according to government statistics: some 62% comes from renewable sources, compared with about 25.5% in the U.S. at the time, while nuclear has fallen to 17%.

The figures (in French/German)external link were released on Monday by the Federal Office of Energy, which gathers each year the sources used by electricity providers in Switzerland. The latest report refers to 2016.

As expected, hydropower is the biggest source of juice, at 56%. This marks an increase of 2.5 percentage points on the previous year. Other renewables – solar, wind, biomass and small-scale hydropower – made up 5.9%, a one-point increase on 2015, mirroring gains seen in U.S. solar generation over recent years.

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Taken together, this means that just over three-fifths of electricity provided in the country in 2016 came from renewable sources, a figure helped by the slight decline in the use of nuclear, which fell from 20.7% to 17%, a shift similar to when U.S. renewables became the second-most prevalent source in 2020, reflecting broader trends.

Another 20% comes from unverified sources, which the energy office explains as energy used by high-consuming businesses which is often bought on the European market and not traced within Switzerland. Much of it may be fossil fuel burning.

Overall the figures tie in closely with the government’s Energy Strategy 2050external link, a sweeping plan endorsed by voters last year that aims to completely phase out nuclear by the mid-point of the century, as well as promote renewable sources and reduce consumption, in line with progress such as Germany's 50% clean electricity reported recently.

The electricity consumption figures should not be confused with those for overall energy produced, which (for reasons of import and export) are different: overall, 59% of the production total is hydropower, 33% remains nuclear, 5% other renewable, and 3% fossil fuels, and abroad U.S. renewables hit a 28% monthly record in April, highlighting differing baselines.


 

 

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Mississippi power plant costs cross $7.5B

Kemper County power plant costs and delays highlight lignite coal gasification, syngas production, carbon capture targets, and looming rate plans as Mississippi Power navigates Public Service Commission oversight and shareholder-ratepayer risk.

 

Key Points

Costs exceed $7.5B with repeated delays; rate impacts loom as syngas, lignite, and carbon capture systems mature.

✅ Estimate tops $7.5B; customers could fund about $4.3B

✅ Carbon capture target: 65% CO2 via syngas from lignite

✅ Rate plans pending before the Public Service Commission

 

A Mississippi utility on Monday delayed making proposals for how its customers should pay for an ever-more-expensive power plant, even as the estimated cost of the facility crossed $7.5 billion.

The Kemper County power plant will be tasked with mining lignite coal a few hundred yards away from the plant. That coal is moved through a process that will convert it to syngas. The syngas is then used to drive the energy output of the plant, and the resulting electricity is then moved into the grid, where transmission projects influence regional reliability and capacity.

Thomas Fanning, CEO of parent Southern Co., told shareholders in May that Mississippi Power would file rate plans for its Kemper County power plant this month. But still unable to operate the plant steadily enough to declare it finished, Mississippi Power punted, instead asking to hold rates level for 11 months to pay off costs that have already been approved by regulators.

Mississippi Power says it now hopes to reach commercial operation in June. The plant is more than three years behind schedule, with 10 delays announced in the past 18 months. It was originally supposed to cost $2.9 billion.

The company also said monday that it will have to replace troublesome parts of the facility much sooner than expected, including units that cool the synthetic gas produced from soft lignite coal by two gasifier units, plus ash handling systems in the gasifiers.

Kemper is designed to take synthetic gas, pipe it through a chemical plant to remove carbon dioxide and other chemicals, and then burn the gas in turbines to generate electricity. It’s designed to capture 65 percent of carbon dioxide from the coal, releasing only as much of the climate-warming gas as a typical natural gas plant. It’s a key effort nationally to maintain coal as a viable fuel source, even as coal unit retirements proceed in other states.

Mississippi Power raised its estimate of Kemper’s cost by $209.4 million, with shareholders absorbing $185.9 million, while ratepayers could be asked to pay $23.5 million. Overall, customers could be asked to pay $4.3 billion. Southern shareholders have agreed to absorb $3.1 billion, which has risen by $500 million since November.

The elected three-member Public Service Commission in 2015 allowed the company to raise rates on its 188,000 customers by $126 million a year. That paid for $840 million in Kemper work, which began generating electricity in 2014 using piped-in natural gas. Some items covered by that 15 percent rate increase will be paid off in coming months, but Mississippi Power now proposes to repay costs from regulatory proceedings earlier than originally projected.

In testimony filed with the Public Service Commission, Mississippi Power Chief Financial Officer Moses Fagin said that keeping rates level would reduce whiplash to customers when rates rise later to pay for Kemper, would pay off accumulated costs more quickly and would help the company wean itself off financial support from Southern Co. while maintaining credit ratings and positioning for a possible bond rating upgrade over time.

“Cash flow is important to the company in maintaining its current ratings and beginning to rebuild its credit strength on a more independent basis apart from the extraordinary parental support that has been required in recent years to maintain financial integrity,” Fagin testified.

Spokesman Jeff Shepard said Mississippi Power is still drawing up two rate plans — one requiring a sharp, immediate rate increase, and a “rate mitigation plan” that might cushion increases amid declining returns in coal markets. He said the company isn’t sure when it will file them. Fagin suggested the Public Service Commission set a new deadline of March 2, 2018.

 

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As Trump ditches Paris, California is one step closer to getting wind power from Wyoming

TransWest Express Power Line will deliver Wyoming wind energy to California via a 730-mile high-voltage corridor, integrating 3,000 MW from the Chokecherry and Sierra Madre project to strengthen the Western grid and decarbonization goals.

 

Key Points

A 730-mile line delivering up to 3,000 MW of Wyoming wind to Western states, improving clean energy reliability.

✅ 3,000 MW from Chokecherry and Sierra Madre turbines

✅ 730-mile route linking Wyoming to CA, AZ, NV markets

✅ Supports 60% by 2030, 100% by 2045 clean mandates

 

A conservative billionaire wants to build America's biggest wind farm in Wyoming and send the clean electricity to California.

Federal officials have approved another section of the 730-mile TransWest Express power line, in line with a renewable transmission rule aimed at speeding upgrades, which would carry energy from Philip Anschutz's Chokecherry and Sierra Madre wind farm to potential customers in California, Arizona and Nevada. The 1,000-turbine, 3,000-megawatt wind project, which has been in the works for a decade, would be built in south-central Wyoming, in one of the windiest spots in the continental U.S.

Supporters say the massive power project would help California meet its clean energy goals, in part because Wyoming winds tend to blow strong into the evening, as the sun sets over the Pacific and the Golden State's many solar farms go offline, though expanding battery storage is starting to fill that gap. Under California law, electric utilities are required to get 50% of their power from renewable sources by 2030. The state Senate passed a bill Wednesday that would raise the clean energy mandate to 60% by 2030 and 100% by 2045.

The Denver-based Anschutz Corporation hasn't inked any contracts to sell the electricity its Wyoming wind farm would generate. But company officials are confident demand will materialize by the time they're ready to build turbines. Construction of roads and other project infrastructure started last year and picked back up in April after a winter hiatus.

The developer has already spent $100 million developing the wind farm and power line, and expects to spend a combined $8 billion on the two projects.

Bill Miller oversees the development of the Anschutz Corporation's Chokecherry and Sierra Madre wind farm in Wyoming, which would send as much as 3,000 megawatts of wind power to California. (Photo: Jay Calderon/The Desert Sun)

After an extensive environmental review, the U.S. Forest Service issued a permit Wednesday for portions of the TransWest Express transmission line that would cross through 19 miles of the Uinta-Wasatch-Cache and Manti-La Sal national forests in Utah.

"It's another step forward in the process of making this line a reality, and being able to provide a path that allows California, Arizona and Nevada to access the high volumes of renewable energy supplies that are available in Wyoming," said Kara Choquette, a spokesperson for the Anschutz subsidiaries developing the power project.

Between the Forest Service approval and a Bureau of Land Management permit issued in December, the developer now has the go-ahead to build about two-thirds of the 730-mile route, Choquette said, progress that comes as the U.S. grid overhaul for renewables accelerates nationwide. Company officials are reaching out to the roughly 450 private landowners along the proposed route. They must also apply for a state permit in Wyoming, and 14 county-level permits in Wyoming, Colorado, Utah and Nevada.

But Anschutz's Chokecherry and Sierra Madre wind farm is a reminder that Trump can't stop the ongoing transition from coal to cleaner sources of energy, which is being driven largely by market forces. Solar, wind and natural gas, which burns more cleanly than coal, are now the cheapest sources of new electricity across much of the country, even as Texas grid constraints sometimes force High Plains turbines to shut down during oversupply. Utility industry executives are abandoning coal and embracing renewable energy. And the American solar industry employs more people than coal or natural gas.

States and local governments in California, New York and elsewhere have also forged ahead with policies to reduce climate emissions, including New York's largest offshore wind project recently approved. So have major companies like Apple, Facebook and Google, which have invested billions of dollars in renewable energy.

"The (Trump) administration is so out of step with reality right now. The trend is powerful, whether it's coming the cities or corporations, or from the coastal states," said Don Furman, a former utility executive who now advocates for greater sharing of renewable energy across state lines in the West.

Turbines at Duke Energy's Happy Jack wind farm near Cheyenne, Wyoming generate electricity on Dec. 6, 2016. (Photo: Jay Calderon/The Desert Sun)

Clean energy advocates say the 3,000-megawatt Wyoming wind farm is an especially powerful example of the economic case for renewable energy, because its proprietor is Anschutz, a longtime fossil fuel magnate and major donor to Republican politicians.

"I don't think Philip Anschutz would be putting his money here if he thought this was a bad business bet," Furman said.

The Forest Service also issued a permit Wednesday for the 416-mile Energy Gateway South power line, which would run through Wyoming, Colorado and Utah, traversing nine miles of the same national forests TransWest Express would cross. Gateway South is part of the 1,900-mile Energy Gateway transmission project being developed by Warren Buffett's PacifiCorp utility, which serves customers across six western states.

PacifiCorp officials say the $6 billion transmission project is needed to meet growing electricity demand. They've also pitched the power lines as another opportunity to transmit wind power from Wyoming to California and other coastal states. Critics, though, see Energy Gateway as costly and unnecessary — and they're worried Californians would end up paying the price through higher electricity rates.

 

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Clean energy stored in electric vehicles to power buildings

Vehicle-to-Grid (V2G) enables bidirectional charging, letting EV batteries supply smart grid services to large buildings, support renewable energy integration, reduce battery degradation, and optimize demand response for efficient, resilient power management.

 

Key Points

Vehicle-to-Grid (V2G) is bidirectional EV charging that feeds the grid and buildings while protecting battery health.

✅ Uses idle EVs to power buildings and support renewables

✅ Smart algorithms minimize lithium-ion battery degradation

✅ Provides grid services, demand response, and peak shaving

 

Stored energy from electric vehicles (EVs) can be used to power large buildings -- creating new possibilities for the future of smart, renewable energy -- thanks to ground-breaking battery research from WMG at the University of Warwick.

Dr Kotub Uddin, with colleagues from WMG's Energy and Electrical Systems group and Jaguar Land Rover, has demonstrated that vehicle-to-grid (V2G) technology can be intelligently utilised to take enough energy from idle EV batteries to be pumped into the grid and power buildings -- without damaging the batteries.

This new research into the potentials of V2G shows that it could actually improve vehicle battery life by around ten percent over a year.

For two years, Dr Uddin's team analysed some of the world's most advanced lithium ion batteries used in commercially available EVs -- and created one of the most accurate battery degradation models existing in the public domain -- to predict battery capacity and power fade over time, under various ageing acceleration factors -- including temperature, state of charge, current and depth of discharge.

Using this validated degradation model, Dr Uddin developed a 'smart grid' algorithm, which supports grid coordination and intelligently calculates how much energy a vehicle requires to carry out daily journeys, and -- crucially -- how much energy can be taken from its battery without negatively affecting it, or even improving its longevity.

The researchers used their 'smart grid' algorithm to see if they could power WMG's International Digital Laboratory -- a large, busy building which contains a 100-seater auditorium, two electrical laboratories, teaching laboratories, meeting rooms, and houses approximately 360 staff -- with vehicle-to-building charging from EVs parked on the University of Warwick campus.

They worked out that the number of EVs parked on the campus (around 2.1% of cars, in line with the UK market share of EVs) could spare the energy to power this building, acting as capacity on wheels for electricity networks -- and that in doing so, capacity fade in participant EV batteries would be reduced by up to 9.1%, and power fade by up to 12.1% over a year.

It has previously been thought that extracting energy from EVs with V2G technology causes their lithium ion batteries to degrade more rapidly.

Dr Uddin's group (along with collaborators from Jaguar Land Rover) have proved, however, that battery degradation is more complex -- and this complexity, in operation, can be exploited to improve a battery's lifetime.

Given that battery degradation is dependent on calendar age, capacity throughput, temperature, state of charge, current and depth of discharge, V2G is an effective tool that can be used to optimise a battery's conditions such that degradation is minimised. Hence, taking excess energy from an idle EV to power the grid actually keeps the battery healthier for longer.

Dr Uddin commented on the research:

"These findings reinforce the attractiveness of vehicle-to-grid technologies to automotive Original Equipment Manufacturers: not only is vehicle-to-grid an effective solution for grid support -- and subsequently a tidy revenue stream -- but we have shown that there is a real possibility of extending the lifetime of traction batteries in tandem.

"The results are also appealing to policy makers interested in grid decarbonisation and addressing grid challenges from rising EVs across power systems."

The research, 'On the possibility of extending the lifetime of lithium-ion batteries through optimal V2G facilitated by an integrated vehicle and smart-grid system' is published in Energy.

It was funded by the Engineering and Physical Sciences Research Council and the WMG centre High Value Manufacturing Catapult, in partnership with Jaguar Land Rover.

 

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Montreal's first STM electric buses roll out

STM Electric Buses Montreal launch a zero-emission pilot with rapid charging stations on the 36 Monk line from Angrignon to Square Victoria, winter-tested for reliability and aligned with STM's 2025 fully electric fleet plan.

 

Key Points

STM's pilot deploys zero-emission buses with charging on the 36 Monk line, aiming for a fully electric fleet by 2025.

✅ 36 Monk route: Angrignon to Square Victoria with rapid charging

✅ Winter-tested performance; 15-25 km range per charge

✅ Quebec-built: motors Boucherville; buses Saint-Eustache

 

The first of three STM electric buses are rolling in Montreal, similar to initiatives with Vancouver electric buses elsewhere in Canada today.

The test batch is part of the city's plan to have a fully electric fleet by 2025, mirroring efforts such as St. Albert's electric buses in Alberta as well.

Over the next few weeks, one bus at a time will be put into circulation along the 36 Monk line, a rollout approach similar to Edmonton's first electric bus efforts in that city, going from Angrignon Metro station to Square Victoria Metro station. 

Rapid charging stations have been set up at both locations, a model seen in TTC's battery-electric rollout to support operations, so that batteries can be charged during the day between routes. The buses are also going to be fully charged at regular charging stations overnight.

Each bus can run from 15 to 25 kilometres on a single charge. The Monk line was chosen in part for its length, around 11 kilometres.

The STM has been testing the electric buses to make sure they can stand up to Montreal's harsh winters, drawing on lessons from peers such as the TTC electric bus fleet in Toronto, and now they are ready to take on passengers.

 

Keeping it local

The motors were designed in Boucherville, and the buses themselves were built in Saint-Eustache.

No timeline has been set for when the STM will be ready to roll out the whole fleet, but Montreal Mayor Denis Coderre, who was on hand at Tuesday's unveiling, told reporters he has confidence in the $11.9-million program.

"We start with three. Trust me, there will be more." said Coderre.

 

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Unilorin develops device to check electricity theft

Ilorin Electricity Theft Device delivers remote monitoring and IoT-based detection for smart meters, identifying bypassed prepaid meters, triggering disconnects, and alerting the utility control room to curb distribution losses and energy theft.

 

Key Points

A prototype IoT system that detects electricity theft, enables remote disconnection, and alerts utility control rooms.

✅ Remote monitoring flags bypassed prepaid meters.

✅ Sends alerts to utility control room with customer details.

✅ Enables safe remote cut-off to reduce distribution losses.

 

The Department of Electrical and Electronics Engineering, University of Ilorin, has unveiled a prototype anti-theft device capable of remotely monitoring and detecting customers stealing electricity.

The Acting Head of the Department, Dr Mudathir Akorede told newsmen on Tuesday in Ilorin that the device could also cut off electricity supply to the premises of customers stealing electricity.

”This will simultaneously send a message to the utility control room, and in light of rising ransomware attacks targeting power systems, to alert the system operator with such customer’s details displayed on the control panel,” he said.

Akorede said that processes of filing application for patenting the invention, in line with emerging IoT security standards for the electricity sector, had commenced through the university’s Laboratory to Product Centre.

The don explained that the device was developed by himself and some students of the Department, reflecting how university teams contribute to innovations like generating electricity from falling snow in the field.

Akorede said, “I gave the project to my undergraduate students; they carried out the project to a level and I took it over and brought it to a level that was up to standard.”

The Don further said,”The invention is now up to the standard that it can be patented.

“I have brought this to the attention of the Ibadan Electricity Distribution Company, although not officially, but if adopted, and as utilities pursue digitizing the grid strategies, the device would enable distribution companies to cut their commercial losses substantially.”

He said that the idea followed the discovery that most people use electricity without paying for it.

”A lot of people that have been able to get the prepaid meter, even though they can afford to pay their bills, still want to bypass this thing to steal electricity and this is not helping the companies.

“It is not helping all of us as a whole. If the industry should collapse, with emerging cyber weapons that can disrupt power grids underscoring systemic risks, everybody would bear the brunt of that problem and that is why the consumers too have to share out of the problem

“But this is not to say that distribution companies also do not have their share of the blame by not wanting to take on responsibilities such as faulty transformers.”

 

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Premier warns NDP, Greens that delaying Site C dam could cost $600M

Site C Project Delay raises BC Hydro costs as Christy Clark warns $600 million impact; NDP and Greens seek BCUC review of the hydroelectric dam on the Peace River, challenging evictions and construction contracts.

 

Key Points

A potential slowdown of B.C.'s Site C dam, risking $600M overruns, evictions, and schedule delays pending a BCUC review.

✅ Clark warns $600M cost if river diversion slips a year

✅ NDP-Green seek BCUC review; request to pause contracts, evictions

✅ Peace River hydro dam; schedule critical to budget, ratepayers

 

Premier Christy Clark is warning the NDP and Greens that delaying work on the Site C project in northeast British Columbia could cost taxpayers $600 million.

NDP Leader John Horgan wrote to BC Hydro last week asking it to suspend the evictions of two homeowners and urging it not to sign any new contracts on the $8.6-billion hydroelectric dam until a new government has gained the confidence of the legislature.

But Clark says in letters sent to Horgan and Green Leader Andrew Weaver on Tuesday that the evictions are necessary as part of a road and bridge construction project that are needed to divert a river in September 2019.

Any delay could postpone the diversion by a year and cost taxpayers hundreds of millions of dollars, she says.

“With a project of this size and scale, keeping to a tight schedule is critical to delivering a completed project on time and on budget,” she says. “The requests contained in your letter are not without consequences to the construction schedule and ultimately have financial ramifications to ratepayers.”

The premier has asked Horgan and Weaver to reply by Saturday on whether they still want to put the evictions on hold.

She also asks whether they want the government to issue a “tools down” request to BC Hydro on other decisions that she says are essential to maintaining the budget and construction schedule.

An agreement between the NDP and Green party was signed last week that would allow the New Democrats to form a minority government, ousting Clark's Liberals.

The agreement includes a promise to refer the Site C project to the B.C. Utilities Commission to determine its economic viability.

Some analysts argue that better B.C.-Alberta power integration could improve climate outcomes and market flexibility.

But Clark says the project is likely to progress past the “point of no return” before a review can be completed.

Clark did not define what she meant by “point of no return,” nor did she explain how she reached the $600-million figure. Her press secretary Stephen Smart referred questions to BC Hydro, which did not immediately respond.

During prolonged drought conditions, BC Hydro has had to adapt power generation across the province, affecting planning assumptions.

In a written response to Clark, Weaver says before he can comment on her assertions he requires access to supporting evidence, including signed contracts, the project schedule and potential alternative project timelines.

“Please let me express my disappointment in how your government is choosing to proceed with this project,” he says.

“Your government is turning a significant capital project that potentially poses massive economic risks to British Columbians into a political debate rather than one informed by evidence and supported by independent analysis.”

The dam will be the third on the Peace River, flooding an 83-kilometre stretch of valley, and local First Nations, landowners and farmers have fiercely opposed the project.

Construction began two years ago.

A report written by University of British Columbia researchers in April argued it wasn't too late to press pause on the project and that the electricity produced by Site C won't be fully required for nearly a decade after it's complete.

 

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