Commission panel to review Eastshore plant

Global Coal Power Decline 2019 signals a record fall in coal-fired electricity as China plateaus, India dips, and the EU and US accelerate renewables, curbing carbon emissions and advancing the global energy transition.

Key Points

A record 2019 drop in global coal power as renewables rise and demand slows across China, India, the EU, and the US.

✅ 3% global fall in coal-fired electricity in 2019.

✅ China plateaus; India declines for first time in decades.

✅ EU and US shift to renewables and gas, cutting emissions.

The world’s use of coal-fired electricity is on track for its biggest annual fall on record this year after more than four decades of near-uninterrupted growth that has stoked the global climate crisis.

Data shows that coal-fired electricity is expected to fall by 3% in 2019, or more than the combined coal generation in Germany, Spain and the UK last year and could help stall the world’s rising carbon emissions this year.

The steepest global slump on record is likely to emerge in 2019 as India’s reliance on coal power falls for the first time in at least three decades this year, and China’s coal power demand plateaus, reflecting the broader global energy transition underway.

Both developing nations are using less coal-fired electricity due to slowing economic growth in Asia as well as the rise of cleaner energy alternatives. There is also expected to be unprecedented coal declines across the EU and the US as developed economies turn to clean forms of energy such as low-cost solar power to replace ageing coal plants.

In almost 40 years the world’s annual coal generation has fallen only twice before: in 2009, in the wake of the global financial crisis, and in 2015, following a slowdown in China’s coal plants amid rising levels of deadly air pollution.

The research was undertaken by the Centre for Research on Energy and Clean Air , the Institute for Energy Economics and Financial Analysis and the UK climate thinktank Sandbag.

The researchers found that China’s coal-fired power generation was flatlining, despite an increase in the number of coal plants being built, because they were running at record low rates. China builds the equivalent of one large new coal plant every two weeks, according to the report, but its coal plants run for only 48.6% of the time, compared with a global utilisation rate of 54% on average.

The findings come after a report from Global Energy Monitor found that the number of coal-fired power plants in the world is growing, because China is building new coal plants five times faster than the rest of the world is reducing their coal-fired power capacity.

The report found that in other countries coal-fired power capacity fell by 8GW in the 18 months to June but over the same period China increased its capacity by 42.9GW.

In a paper for the industry journal Carbon Brief, the researchers said: “A 3% reduction in power sector coal use could imply zero growth in global CO2 emissions, if emissions changes in other sectors mirror those during 2018.”

However, the authors of the report have warned that despite the record coal power slump the world’s use of coal remained far too high to meet the climate goals of the Paris agreement, and some countries are still seeing increases, such as Australia’s emissions rise amid increased pollution from electricity and transport.

The US – which is backing out of the Paris agreement – has made the deepest cuts to coal power of any developed country this year by shutting coal plants down in favour of gas power and renewable energy, with utilities such as Duke Energy facing investor pressure to disclose climate plans. By the end of August the US had reduced coal by almost 14% over the year compared with the same months in 2018.

The EU reported a record slump in coal-fired electricity use in the first half of the year of almost a fifth compared with the same months last year. This trend is expected to accelerate over the second half of the year to average a 23% fall over 2019 as a whole. The EU is using less coal power in favour of gas-fired electricity – which can have roughly half the carbon footprint of coal – and renewable energy, helped by policies such as the UK carbon tax that have slashed coal-fired generation.

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COVID-19 Impact on US Renewable Energy disrupts solar and wind projects, dries up tax equity financing, strains supply chains, delays construction, and slows jobs growth amid limited federal stimulus and uncertain investor appetite.

Key Points

COVID-19 has slowed US clean energy growth by curbing tax equity, disrupting supply chains, and delaying projects.

✅ Tax equity dries up as investor profits fall

✅ Supply chain and construction face pandemic delays

✅ Policy aid and credit extensions sought by industry

Swinerton Renewable Energy had everything it needed to build a promising new solar farm in Texas. It lined up more than 2,000 acres for the $109 million project estimated to generate 400 jobs while under construction. By its completion date, the solar farm was expected to produce 200 megawatts of energy — enough to power about 25,000 homes — and generate big tax breaks for its investors as part of a government program to incentivize clean energy.

But the coronavirus pandemic put everything on hold. The solar farm’s backers aren’t sure they will make enough money from other investments during the pandemic-fueled downturn for those tax breaks to be worth it. So the project has been delayed at least six months.

“This is not a shortage of materials. It is not a pricing issue,” said George Hershman, president of Swinerton Renewable Energy. “Everything was pointing to successful projects.”

The coronavirus crisis is not only battering the oil and gas industry. It’s drying up capital and disrupting supply chains for businesses trying to move the country toward cleaner sources of energy.

While President Trump has promised lifelines for airlines and oil companies struggling with a drastic decrease in demand as Americans remain under stay-at-home orders, there is little focus in Washington on economic relief for this sector, despite a power coalition's call for action to address the pandemic — unlike during the Great Recession a decade ago, when Congress and the Obama administration earmarked an unprecedented sum for renewable energy and more efficient automobiles in a stimulus bill.

“We don’t want to lose our great oil companies,” Trump said during an April 1 news briefing. He so far has not made a similar promise to help wind and solar firms, and none of the four economic rescue and stimulus packages that Congress has passed to respond to the coronavirus crisis set aside any money for renewable energy specifically.

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The impact of the crisis is already clear: About 106,000 clean-energy workers have already filed for unemployment in March alone, according to an analysis of Bureau of Labor Statistics data by Environmental Entrepreneurs, an advocacy group.

The layoffs are a blow to a sector that has prided itself on official projections that solar installers and wind turbine technicians would be the two fastest growing occupations over the next decade.

The job losses include not just wind and solar construction workers, but also those assembling electric cars and installing energy-efficient appliances, lighting, heating and air conditioning.

“These aren’t left-wing coastal hippies,” said Bob Keefe, executive director of Environmental Entrepreneurs. “These are construction workers who get up every day and lace up their boots and pull on their gloves and go to work putting insulation in our attics.”

Despite the economic turmoil, climate experts say the coronavirus pandemic could be an opportunity to make drastic shifts in the energy landscape, with green investments potentially driving a robust recovery. They say governments around the world should help fund renewable energy and use the turmoil in energy markets to remake the industry and slash carbon dioxide emissions, which will tumble 8 percent this year, according to the International Energy Agency.

The agency said that while global energy demand fell 3.8 percent in the first quarter, renewables were the only source to post an increase in demand, rising 1.5 percent thanks to new renewable power plants, low operating costs and priority on some electricity grids.

But many investors, who rely on a broad mix of investments, are spooked. “Everything is quiet because people want to see where we land with the current crisis, and people are holding on to cash,” said Daniel Klier, the global head of sustainable finance at HSBC bank. “As soon as people have a bit of confidence that the market is recovering, they can get projects going.”

Social distancing and the country’s stay-at-home orders are also having a deep effect on daily operations. The areas hardest hit are installing solar panels on rooftops and adding energy-efficiency measures inside homes — work that often requires face-to-face interactions. Sungevity, once one of the nation’s leading solar-installation companies, laid off 377 workers, most of its workforce, in late March, according to filings with California’s Employment Development Department. The company, which had emerged from a 2017 bankruptcy, cited economic conditions.

The push to promote a more fuel-efficient automobile fleet has also veered off track. The electric car maker Tesla was forced to shut down its factory in Fremont, Calif., just as it was turning up production on its new crossover vehicle, the Model Y.

Lockdown orders across the country led Tesla’s outspoken chief executive, Elon Musk, to launch into an expletive-laden rant during an earnings call last week in which Tesla posted a lukewarm profit of $16 million.

“To say that they cannot leave their house and they will be arrested if they do,” Musk said, “this is fascist.”

Sungevity and Tesla represent only a sliver of the economic pain in this sector across the country. The Solar Energy Industries Association had anticipated a growth in solar jobs, from 250,000 to 300,000, over the course of the year, said the group’s president, Abigail Ross Hopper. Now, she said, half the workforce is at risk.

“Shelter in place puts limitations on how people can work,” she said. “Literally, people don’t want other people inside their houses to fix electrical boxes. And there are no door-to-door sales.”

Bigger projects are also grappling with the pandemic economy, though not as severely. Hopper said the industry was geared up to increase the number of new solar farms, in part to take advantage of federal tax credits. “We were on track to do almost 20 gigawatts, which would have been the highest year yet,” Hopper said. That would have been enough to power about 3.7 million homes. Now she expects new projects will come closer to last year’s 13.27 gigawatts’ worth of new construction, after a report on utility-scale solar delays warned of widespread slowdowns, enough to run approximately 2.5 million homes.

Wind energy companies, too, are bracing for lost progress unless the federal government steps in. The American Wind Energy Association said projects that would add 25 gigawatts of wind power to the U.S. grid are at risk of being scaled back or canceled outright over the next two years because of the pandemic. Altogether, that work represents about 35,000 jobs.

“2019 was a good year for the wind industry,” said Tom Kiernan, the association’s chief executive. “We were expecting 2020 to be an even stronger year.”

One project put on the back burner: an enormous 9 gigawatt offshore wind venture led by the New York State Energy Research and Development Authority set to be completed by 2035.

With New York City besieged by coronavirus cases, the authority said it would comply with an executive order from Gov. Andrew M. Cuomo (D), “pausing” all on-site work on clean-energy projects until at least May 15. Michigan, New Jersey and Pennsylvania also delayed wind turbine projects by deeming construction on them nonessential.

The Danish offshore wind firm Orsted said that plans for offshore U.S. wind installations would move “at a slower pace than originally expected due to a combination of the Bureau of Ocean Energy Management’s prolonged analysis of the cumulative impacts from the build-out of US offshore wind projects, and now also COVID-19 effects.” The company told investors it expects delays on projects off the coasts of New York, New Jersey and Rhode Island totaling almost 3 gigawatts.

The supply chains have also taken a hit during the pandemic: Even if contractors can get the money to erect wind turbines or lay solar arrays, that doesn’t mean they will have the parts. At least two factories that make wind turbine parts — one in North Dakota and another in Iowa — were forced to pause production because of coronavirus outbreaks. Factory shutdowns in China have constrained solar supplies, too.

The key reason for delaying most big solar and wind projects is the use of tax credits known as “tax equity.” These allow investors, such as banks, to use the credits to directly offset their overall tax burdens. But if an investor doesn’t have enough profit to offset the credits, the tax equity could become worthless.

“If your profitability is going down, you don’t have the same appetite,” Hopper said.

Solar and wind industry leaders are pressing Congress and the Trump administration to extend the eligibility period for tax credits that are due to expire, with senators urging support for clean energy in relief packages, and to make the tax credits refundable, meaning the government would issue a check to investors who do not have enough profit to justify their investments.

Currently, big wind turbines get a 1.5 cents per kilowatt hour tax credit if construction begins before the end of this year. Tax credits for residential renewable energy — solar panels and small wind — phase out by the end of 2021, and debate over a potential solar ITC extension continues to shape expectations in the wind market.

The lack of attention to renewables in Congress’s relief efforts so far is in stark contrast to 2009, when the United States spent $112 billion to boost “green” energy, according to the World Resources Institute. The government’s package then provided a mixture of grants and loans for a variety of renewable energy ventures — including a $465 million loan Tesla used to get its Fremont factory off the ground.

This year, a handful of clean-energy firms, including a Connecticut-based manufacturer of fuel cells and an Ohio-based maker of energy-efficient lighting systems, took money from a federal small-business lending program, before funds ran dry in the middle of last month. Broadwind Energy, a maker of steel wind energy towers based outside Chicago, received $9.5 million in small-business loans, one of the biggest totals in the program.

So far, the Trump administration has shown far more eagerness to help American petroleum producers that the president said were “ravaged” by a sharp drop in energy demand. Last month, Trump met with oil executives at the White House, and Energy Secretary Dan Brouillette has floated the idea of bridge loans for struggling oil firms.

During negotiations for the last relief package, congressional Democrats tried to strike a deal to refill the nation’s Strategic Petroleum Reserve in exchange for extending the clean-energy incentives, but Senate Majority Leader Mitch McConnell (R-Ky.) rebuffed those calls.

“Democrats won’t let us fund hospitals or save small businesses unless they get to dust off the Green New Deal,” McConnell said in March.

Already, Democrats are signaling they will make a push again in the next round of stimulus spending.

“Relief and recovery legislation will shape our society for years to come,” said Rep. A. Donald McEachin (D-Va.), vice chair of the House Sustainable Energy and Environment Coalition, a caucus that supports renewable energy resources. “We must use these bills to build in a climate-smart way.”

But it remains unclear how much appetite the GOP will have for a deal. “I just don’t know how to handicap that at this point,” said Grant Carlisle, an analyst at the Natural Resources Defense Council, a major environmental group.

Kiernan, the head of the American Wind Energy Association, said his group has “gotten a very good reception with the administration and with the Hill” when it comes to coronavirus relief, but he declined to go into specifics.

In other parts of the world, governments have been providing support for renewables. The European Union has its own Green New Deal, and China is expected to support wind and solar to get the economy moving more quickly.

Some energy analysts note that big oil companies don’t have to wait for government stimulus. The price of oil is so low that they would be better off investing in wind and solar, they say.

“For all these oil companies, the returns on these renewable projects are better than what they can do in the oil and gas industry,” said Sarah Ladislaw, director of the energy program at the Center for Strategic and International Studies. “Now is a good time to do that and tell their investors.”

This fits in with their broader goals, analysts contend. After all, Royal Dutch Shell recently matched BP’s earlier promise to aim to be net-zero for carbon emissions by 2050.

Shell’s chief executive Ben van Beurden has said the company would try to protect its low-carbon Integrated Gas and New Energies division from the largest spending cuts as it sought to weather the pandemic. “We must maintain focus on the long term,” he said in a video message. “Society expects nothing less.”

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BC Utilities Commission Site C Dam Questions press BC Hydro on geotechnical risks, stability issues, cost overruns, oversight gaps, seeking transparency for ratepayers and clarity on contracts, mitigation, and the powerhouse and spillway foundations.

Key Points

Inquiry seeking explanations from BC Hydro on geotechnical risks, costs, timelines and oversight for Site C.

✅ Timeline of studies, monitoring, and mitigation actions

✅ Rationale for contracts, costs, and right bank construction

✅ Implications for ratepayers, oversight, and project stability

The watchdog B.C. Utilities Commission has sent BC Hydro 70 questions about the troubled Site C dam, asking when geotechnical risks were first identified and when the project’s assurance board was first made aware of potential issues related to the dam’s stability. 

“I think they’ve come to the conclusion — but they don’t say it — that there’s been a cover-up by BC Hydro and by the government of British Columbia,” former BC Hydro CEO Marc Eliesen told The Narwhal. 

On Oct. 21, The Narwhal reported that two top B.C. civil servants, including the senior bureaucrat who prepares Site C dam documents for cabinet, knew in May 2019 that the project faced serious geotechnical problems due to its “weak foundation” and the stability of the dam was “a significant risk.” 

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“They [the civil servants] would have reported to their ministers and to the government in general,” said Eliesen, who is among 18 prominent Canadians calling for a halt to Site C work until an independent team of experts can determine if the geotechnical problems can be resolved and at what cost.  

“It’s disingenuous for Premier [John] Horgan to try to suggest, ‘Well, I just found out about it recently.’ If that’s the case, he should fire the public servants who are representing the province.” 

The public only found out about significant issues with the Site C dam at the end of July, when BC Hydro released overdue reports saying the project faces unknown cost overruns, schedule delays and, even as it achieved a transmission line milestone earlier, such profound geotechnical troubles that its overall health is classified as ‘red,’ meaning it is in serious trouble. 

“The geotechnical challenges have been there all these years.”

The Site C dam is the largest publicly funded infrastructure project in B.C.’s history. If completed, it will flood 128 kilometres of the Peace River and its tributaries, forcing families from their homes and destroying Indigenous gravesites, hundreds of protected archeological sites, some of Canada’s best farmland and habitat for more than 100 species vulnerable to extinction.

Eliesen said geotechnical risks were a key reason BC Hydro’s board of directors rejected the project in the early 1990s, when he was at the helm of BC Hydro.

“The geotechnical challenges have been there all these years,” said Eliesen, who is also the former Chair and CEO of Ontario Hydro, where Ontario First Nations have urged intervention on a critical electricity line, the former Chair of Manitoba Hydro and the former Chair and CEO of the Manitoba Energy Authority.

Elsewhere, a Manitoba Hydro line to Minnesota has faced potential delays, highlighting broader grid planning challenges.

The B.C. Utilities Commission is an independent watchdog that makes sure ratepayers — including BC Hydro customers — receive safe and reliable energy services, as utilities adapt to climate change risks, “at fair rates.”

The commission’s questions to BC Hydro include 14 about the “foundational enhancements” BC Hydro now says are necessary to shore up the Site C dam, powerhouse and spillways. 

The commission is asking BC Hydro to provide a timeline and overview of all geotechnical engineering studies and monitoring activities for the powerhouse, spillway and dam core areas, and to explain what specific risk management and mitigation practices were put into effect once risks were identified.

The commission also wants to know why construction activities continued on the right bank of the Peace River, where the powerhouse would be located, “after geotechnical risks materialized.” 

It’s asking if geotechnical risks played a role in BC Hydro’s decision in March “to suspend or not resume work” on any components of the generating station and spillways.

The commission also wants BC Hydro to provide an itemized breakdown of a $690 million increase in the main civil works contract — held by Spain’s Acciona S.A. and the South Korean multinational conglomerate Samsung C&T Corp. — and to explain the rationale for awarding a no-bid contract to an unnamed First Nation and if other parties were made aware of that contract. 

Peace River Jewels of the Peace Site C The Narwhal
Islands in the Peace River, known as the ‘jewels of the Peace’ will be destroyed for fill for the Site C dam or will be submerged underwater by the dam’s reservoir, a loss that opponents are sharing with northerners in community discussions. Photo: Byron Dueck

B.C. Utilities Commission chair and CEO David Morton said it’s not the first time the commission has requested additional information after receiving BC Hydro’s quarterly progress reports on the Site C dam. 

“Our staff reads them to make sure they understand them and if there’s anything in then that’s not clear we go then we do go through this, we call it the IR — information request — process,” Morton said in an interview.

“There are things reported in here that we felt required a little more clarity, and we needed a little more understanding of them, so that’s why we asked the questions.”

The questions were sent to BC Hydro on Oct. 23, the day before the provincial election, but Morton said the commission is extraordinarily busy this year and that’s just a coincidence. 

“Our resources are fairly strained. It would have been nice if it could have been done faster, it would be nice if everything could be done faster.” 

“These questions are not politically motivated,” Morton said. “They’re not political questions. There’s no reason not to issue them when they’re ready.”

The commission has asked BC Hydro to respond by Nov. 19.

Read more: Top B.C. government officials knew Site C dam was in serious trouble over a year ago: FOI docs

Morton said the independent commission’s jurisdiction is limited because the B.C. government removed it from oversight of the project. 

The commission, which would normally determine if a large dam like the Site C project is in the public’s financial interest, first examined BC Hydro’s proposal to build the dam in the early 1980s.

After almost two years of hearings, including testimony under oath, the commission concluded B.C. did not need the electricity. It found the Site C dam would have negative social and environmental impacts and said geothermal power should be investigated to meet future energy needs. 

The project was revived in 2010 by the BC Liberal government, which touted energy from the Site C dam as a potential source of electricity for California and a way to supply B.C.’s future LNG industry with cheap power.

Not willing to countenance another rejection from the utilities commission, the government changed the law, stripping the commission of oversight for the project. The NDP government, which came to power in 2017, chose not to restore that oversight.

“The approval of the project was exempt from our oversight,” Morton said. “We can’t come along and say ‘there’s something we don’t like about what you’re doing, we’re going to stop construction.’ We’re not in that position and that’s not the focus of these questions.” 

But the commission still retains oversight for the cost of construction once the project is complete, Morton said. 

“The cost of construction has to be recovered in [hydro] rates. That means BC Hydro will need our approval to recover their construction cost in rates, and those are not insignificant amounts, more than $10.7 billion, in all likelihood.” 

In order to recover the cost from ratepayers, the commission needs to be satisfied BC Hydro didn’t spend more money than necessary on the project, Morton said. 

“As you can imagine, that’s not a straight forward review to do after the fact, after a 10-year construction project or whatever it ends up being … so we’re using these quarterly reports as an opportunity to try to stay on top of it and to flag any areas where we think there may be areas we need to look into in the future.”

The price tag for the Site C dam was $10.7 billion before BC Hydro’s announcement at the end of July — a leap from $6.6 billion when the project was first announced in 2010 and $8.8 billion when construction began in 2015. 

Eliesen said the utilities commission should have been asking tough questions about the Site C dam far earlier. 

“They’ve been remiss in their due diligence activities … They should have been quicker in raising questions with BC Hydro, rather than allowing BC Hydro to be exceptionally late in submitting their reports.” 

BC Hydro is late in filing another Site C quarterly report, covering the period from April 1 to June 30. 

The quarterly reports provide the B.C. public with rare glimpses of a project that international hydro expert Harvey Elwin described as being more secretive than any hydro project he has encountered in five decades working on large dams around the world, including in China.

Read more: Site C dam secrecy ‘extraordinary’, international hydro construction expert tells court proceeding

Morton said the commission could have ordered regular reporting for the Site C project if it had its previous oversight capability.

“Then we would have had the ability to follow up and ultimately order any delinquent reports to be filed. In this circumstance, they are being filed voluntarily. They can file it as late as they choose. We don’t have any jurisdiction.” 

In addition to the six dozen questions, the commission has also filed confidential questions with BC Hydro. Morton said confidential information could include things such as competitive bid information. “BC Hydro itself may be under a confidentiality agreement not to disclose it.” 

With oversight, the commission would also have been able to drill down into specific project elements,  Morton said. 

“We would have wanted to ensure that the construction followed what was approved. BC Hydro wouldn’t have the ability to make significant changes to the design and nature of the project as they went along.”

BC Hydro has been criticized for changing the design of the Site C dam to an L-shape, which Eliesen said “has never been done anywhere in the world for an earthen dam.” 

Morton said an empowered commission could have opted to hold a public hearing about the design change and engage its own technical consultants, as it did in 2017 when the new NDP government asked it to conduct a fast-tracked review of the project’s economics. 

Construction Site C Dam
A recent report by a U.S. energy economist found cancelling the Site C dam project would save BC Hydro customers an initial $116 million a year, with increasing savings growing over time. Photo: Garth Lenz / The Narwhal

The commission’s final report found the dam could cost more than $12 billion, that BC Hydro had a historical pattern of overestimating energy demand and that the same amount of energy could be produced by a suite of renewables, including wind and proposed pumped storage such as the Meaford project, for $8.8 billion or less. 

The NDP government, under pressure from construction trade unions, opted to continue the project, refusing to disclose key financial information related to its decision. 

When the geotechnical problems were revealed in July, the government announced the appointment of former deputy finance minister Peter Milburn as a special Site C project advisor who will work with BC Hydro and the Site C project assurance board to examine the project and provide the government with independent advice.

Eliesen said BC Hydro and the B.C. government should never have allowed the recent diversion of the Peace River to take place given the tremendous geotechnical challenges the project faces and its unknown cost and schedule for completion. 

“It’s a disgrace and scandalous,” he said. “You can halt the river diversion, but you’ve got another four or five years left in construction of the dam. What are you going to do about all the cement you’ve poured if you’ve got stability problems?”

He said it’s counter-productive to continue with advice “from the same people who have been wrong, wrong, wrong,” without calling in independent global experts to examine the geotechnical problems. 

“If you stop construction, whether it takes three or six months, that’s the time that’s required in order to give yourself a comfort level. But continuing to do what you’ve been doing is not the right course. You should have to sit back.”

Eliesen said it reminded him of the Pete Seeger song Waist Deep in the Big Muddy, which tells the story of a captain ordering his troops to keep slogging through a river because they will soon be on dry ground. After the captain drowns, the troops turn around.

“It’s a reflection of the fact that if you don’t look at what’s new, you just keep on doing what you’ve been doing in the past and that, unfortunately, is what’s happening here in this province with this project.”

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Washington State Hybrid-Electric Ferries advance green maritime transit with battery-diesel propulsion, lower emissions, and fleet modernization, integrating charging infrastructure and reliable operations across WSF routes to meet climate goals and reduce fuel consumption.

Key Points

New WSF vessels using diesel-battery propulsion to cut emissions, improve efficiency, and sustain reliable ferry service.

✅ Hybrid diesel-battery propulsion reduces fuel use and CO2

✅ Larger vessels with efficient batteries and charging upgrades

✅ Compatible with WSF docks, maintenance, and safety standards

Washington State is embarking on an ambitious update to its ferry fleet, introducing hybrid-electric boats that represent a significant leap toward greener and more sustainable transportation. The state’s updated plans reflect a commitment to reducing carbon emissions and enhancing environmental stewardship while maintaining the efficiency and reliability of its vital ferry services.

The Washington State Ferries (WSF) system, one of the largest in the world, has long been a critical component of the state’s transportation network, linking various islands and coastal communities with the mainland. Traditionally powered by diesel engines, the ferries are responsible for significant greenhouse gas emissions. In response to growing environmental concerns and legislative pressure, WSF is now turning to hybrid-electric technology similar to battery-electric high-speed ferries seen elsewhere to modernize its fleet and reduce its carbon footprint.

The updated plans for the hybrid-electric boats build on earlier efforts to introduce cleaner technologies into the ferry system. The new designs incorporate advanced hybrid-electric propulsion systems that combine traditional diesel engines with electric batteries. This hybrid approach allows the ferries to operate on electric power during certain segments of their routes, reducing reliance on diesel fuel and cutting emissions as electric ships on the B.C. coast have demonstrated during similar operations.

One of the key features of the updated plans is the inclusion of larger and more capable hybrid-electric ferries, echoing BC Ferries hybrid ships now entering service in the region. These vessels are designed to handle the demanding operational requirements of the Washington State Ferries system while significantly reducing environmental impact. The new boats will be equipped with state-of-the-art battery systems that can store and utilize electric power more efficiently, leading to improved fuel economy and lower overall emissions.

The transition to hybrid-electric ferries is driven by both environmental and economic considerations. On the environmental side, the move aligns with Washington State’s broader goals to combat climate change and reduce greenhouse gas emissions, including programs like electric vehicle rebate program that encourage cleaner travel across the state. The state has set ambitious targets for reducing carbon emissions across various sectors, and upgrading the ferry fleet is a crucial component of achieving these goals.

From an economic perspective, hybrid-electric ferries offer the potential for long-term cost savings. Although the initial investment in new technology can be substantial, with financing models like CIB support for B.C. electric ferries helping spur adoption and reduce barriers for agencies, the reduced fuel consumption and lower maintenance costs associated with hybrid-electric systems are expected to lead to significant savings over the lifespan of the vessels. Additionally, the introduction of greener technology aligns with public expectations for more sustainable transportation options.

The updated plans also emphasize the importance of integrating hybrid-electric technology with existing infrastructure. Washington State Ferries is working to ensure that the new vessels are compatible with current docking facilities and maintenance practices. This involves updating docking systems, as seen with Kootenay Lake electric-ready ferry preparations, to accommodate the specific needs of hybrid-electric ferries and training personnel to handle the new technology.

Public response to the hybrid-electric ferry initiative has been largely positive, with many residents and environmental advocates expressing support for the move towards greener transportation. The new boats are seen as a tangible step toward reducing the environmental impact of one of the state’s most iconic transportation services. The project also highlights Washington State’s commitment to innovation and leadership in sustainable transportation, alongside global examples like Berlin's electric flying ferry that push the envelope in maritime transit.

However, the transition to hybrid-electric ferries is not without its challenges. Implementing new technology requires careful planning and coordination, including addressing potential technical issues and ensuring that the vessels meet all safety and operational standards. Additionally, there may be logistical challenges associated with integrating the new ferries into the existing fleet and managing the transition without disrupting service.

Despite these challenges, the updated plans for hybrid-electric boats represent a significant advancement in Washington State’s efforts to modernize its transportation system. The initiative reflects a growing trend among transportation agencies to embrace sustainable technologies and address the environmental impact of traditional transportation methods.

In summary, Washington State’s updated plans for hybrid-electric ferries mark a crucial step towards a more sustainable and environmentally friendly transportation network. By incorporating advanced hybrid-electric technology, the state aims to reduce carbon emissions, improve fuel efficiency, and align with its broader climate goals. While challenges remain, the initiative demonstrates a commitment to innovation and underscores the importance of transitioning to greener technologies in the quest for a more sustainable future.

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BC Hydro Rate Increase proposes a 2.3% hike from April, with BCUC review, aligning below inflation and funding clean energy, electrification, and grid upgrades across British Columbia while keeping electricity prices among North America's lowest.

Key Points

A proposed 2.3% BC Hydro hike from April, under BCUC review, funds clean energy and keeps average bills below inflation.

✅ Adds about $2 per month to average residential bill

✅ Sixth straight increase below inflation since 2018

✅ Supports renewable projects and grid modernization

The British Columbia government says the province’s Crown power utility is applying for a 2.3-per-cent rate increase starting in April, with higher BC Hydro rates previously outlined, adding about $2 a month to the average residential bill.

A statement from the Energy Ministry says it’s the sixth year in a row that BC Hydro has applied for an increase below the rate of inflation, similar to a 3 per cent rise noted in a separate approval, which still trailed inflation.

It says rates are currently 15.6 per cent lower than the cumulative rate of inflation over the last seven years, starting in 2017-2018, with a provincial rate freeze among past measures, and 12.4 per cent lower than the 10-year rates plan established by the previous government in 2013.

The ministry says the “modest” rate increase application comes after consideration of a variety of options and their long-term impacts, including scenarios like a 3.75% two-year path evaluated alongside others, and the B.C. Utilities Commission is expected to decide on the plan by the end of February.

Chris O’Riley, president of BC Hydro, says the rates application would keep electricity costs in the province among the lowest in North America, even as a BC Hydro fund surplus prompted calls for changes, while supporting investments in clean energy to power vehicles, homes and businesses.

Energy Minister Josie Osborne says it’s more important than ever to keep electricity bills down, especially as Ontario hydro rates increase in a separate jurisdiction, as the cost of living rises at rates that are unsustainable for many.

“Affordable, stable BC Hydro rates are good for people, businesses and climate as we work together to power our growing economy with renewable energy instead of fossil fuels,” Osborne says in a statement issued Monday.

Earlier this year, the ministry said BC Hydro provided $315 million in cost-of-living bill credits, while in another province Manitoba Hydro scaled back an increase to ease pressure, to families and small businesses in the province, including those who receive their electricity service from FortisBC or a municipal utility.

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California Rooftop Solar Cost Shift examines PG&E rate hikes, net metering changes, and utility infrastructure spending impacts on low-income households, distributed generation, and clean energy adoption, potentially raising bills and undermining grid resilience.

Key Points

A claim that rooftop solar shifts fixed grid costs to others; critics cite PG&E rates, avoided costs, and impacts.

✅ PG&E rates outpace national average, underscoring cost drivers.

✅ Net metering cuts risk burdening low- and middle-income homes.

✅ Distributed generation avoids infrastructure spend and grid strain.

California is grappling with soaring electricity prices across the state, with Pacific Gas & Electric (PG&E) rates more than double the national average and increasing at an average of 12.5% annually over the past six years. In response, Governor Gavin Newsom issued an executive order directing state energy agencies to identify ways to reduce power costs. However, recent policy shifts targeting rooftop solar users may exacerbate the problem rather than alleviate it.

The "Cost Shift" Theory

A central justification for these pricing changes is the "cost shift" theory. This theory posits that homeowners with rooftop solar panels reduce their electricity consumption from the grid, thereby shifting the fixed costs of maintaining and operating the electrical grid onto non-solar customers. Proponents argue that this leads to higher rates for those without solar installations.

However, this theory is based on a flawed assumption: that PG&E owns 100% of the electricity generated by its customers and is entitled to full profits even for energy it does not deliver. In reality, rooftop solar users supply only about half of their energy needs and still pay for the rest. Moreover, their investments in solar infrastructure reduce grid strain and save ratepayers billions by avoiding costly infrastructure projects and reducing energy demand growth, aligning with efforts to revamp electricity rates to clean the grid as well.

Impact on Low- and Middle-Income Households

The majority of rooftop solar users are low- and middle-income households. These individuals often invest in solar panels to lower their energy bills and reduce their carbon footprint. Policy changes that undermine the financial viability of rooftop solar disproportionately affect these communities, and efforts to overturn income-based charges add uncertainty about affordability and access.

For instance, Assembly Bill 942 proposes to retroactively alter contracts for millions of solar consumers, cutting the compensation they receive from providing energy to the grid, raising questions about major changes to your electric bill that could follow if their home is sold or transferred. This would force those with solar leases—predominantly lower-income individuals—to buy out their contracts when selling their homes, potentially incurring significant financial burdens.

The Real Drivers of Rising Energy Costs

While rooftop solar users are being blamed for rising electricity rates, calls for action have mounted as the true culprits lie elsewhere. Unchecked utility infrastructure spending has been a significant factor in escalating costs. For example, PG&E's rates have increased rapidly, yet the utility's spending on infrastructure projects has often been criticized for inefficiency and lack of accountability. Instead of targeting solar users, policymakers should scrutinize utility profit motives and infrastructure investments to identify areas where costs can be reduced without sacrificing service quality.

California's approach to addressing rising electricity costs by targeting rooftop solar users is misguided. The "cost shift" theory is based on flawed assumptions and overlooks the substantial benefits that rooftop solar provides to the grid and ratepayers. To achieve a sustainable and equitable energy future, the state must focus on controlling utility spending, promoting clean energy access for all, especially as it exports its energy policies across the West, and ensuring that policies support—not undermine—the adoption of renewable energy technologies.

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