Committee chair sets high carbon reduction goal

By Reuters


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The chairman of a key committee in the House of Representatives is proposing climate change legislation that would cut greenhouse gas emissions at a rate that is somewhat more aggressive than proposals by President Barack Obama, sources said.

The legislation by House Energy and Commerce Committee Chairman Henry Waxman would require that U.S. carbon emissions be reduced by 20 percent from 2005 levels by the year 2020, 42 percent by 2030 and 83 percent by 2050, according to House Democratic aides who asked not to be identified.

The U.S. "cap and trade" emission control regime would not begin to take effect until 2012, when a 3 percent reduction from 2005 levels would be required, the aides said.

Obama has asked Congress for legislation that would bring reductions of around 15 percent by 2020 and over 80 percent by 2050. Waxman just unveiled his draft legislation.

Under its cap and trade plan, the Obama administration has proposed raising $646 billion by selling permits to power plants, oil refineries and other industrial facilities that would limit the greenhouse gases they could emit. Some of the money would go back to consumers to help them pay for higher energy costs, as well as supporting alternative energy initiatives.

Waxman, a California Democrat, hopes to get his bill, with some revisions, passed by the panel by the end of May as part of a push by the majority Democrats in Congress to enact this major Obama initiative this year or next.

But several other House panels also will have to review the controversial legislation before the full House could vote. The bill must also be passed by the Senate before Obama can sign it into law.

Other key provisions to be included in Waxman's bill, which will be a starting point for writing climate control legislation in the House this year, include, according to the aides:

• 25 percent of the country's electricity supply would have to come from renewable sources, such as solar and wind, by 2025;

• still to be determined is the percentage of polluting permits under the cap and trade system that would be auctioned to industry versus how much might be given to those firms;

• utilities would be encouraged to reduce electricity consumption by 15 percent by 2020 and 10 percent for natural gas by 2020;

• the Waxman measure would cover 85 percent of total U.S. emissions of carbon dioxide and other pollutants that scientists have linked to global warming.

Many Republicans are expected to oppose any climate change bill Democrats advance, claiming the initiative would significantly increase consumers' energy costs as the country is trying to climb out of a steep economic recession.

Senate Republican leader Mitch McConnell said Obama's climate control ideas would cost households $3,100 a year "just for doing the same things people have always done, like turning on the lights and doing laundry."

But Democrats are also expected to include provisions that would try to ease the impact on consumers, possibly with some form of tax rebate, especially for the poor.

Obama and Democrats in Congress are arguing that tackling climate change will have benefits beyond helping the environment, such as creating new jobs in the energy sector and reducing U.S. reliance on foreign oil.

Industry and environmental groups have received briefings on Waxman's plans. Their support will be vital to any legislation being enacted.

Waxman's draft plan will "follow very closely" the climate change goals of the U.S. Climate Action Partnership, a coalition of key corporate and environmental groups, one of the House aides said.

Representative Chris Van Hollen, a member of the House Democratic leadership who is active on climate control legislation, said it is too soon to know whether cap and trade legislation will be signed into law this year.

"I think it's... too early to predict whether you're going to see final passage, but what you are going to see for sure is a very serious effort," Van Hollen told Reuters. "I think you're going to see substantial progress and very possibly see some legislation emerge at least from the House."

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California's solar energy gains go up in wildfire smoke

California Wildfire Smoke Impact on Solar reduces photovoltaic output, as particulate pollution, soot, and haze dim sunlight and foul panels, cutting utility-scale generation and grid reliability across CAISO during peak demand and heatwaves.

 

Key Points

How smoke and soot cut solar irradiance and foul panels, slashing PV generation and straining CAISO grid operations.

✅ Smoke blocks sunlight; soot deposition reduces panel efficiency.

✅ CAISO reported ~30% drop versus July during peak smoke.

✅ Longer fire seasons threaten solar reliability and capacity planning.

 

Smoke from California’s unprecedented wildfires was so bad that it cut a significant chunk of solar power production in the state, even as U.S. solar generation rose in 2022 nationwide. Solar power generation dropped off by nearly a third in early September as wildfires darkened the skies with smoke, according to the US Energy Information Administration.

Those fires create thick smoke, laden with particles that block sunlight both when they’re in the air and when they settle onto solar panels. In the first two weeks of September, soot and smoke caused solar-powered electricity generation to fall 30 percent compared to the July average, according to the California Independent System Operator (CAISO), which oversees nearly all utility-scale solar energy in California, where wind and solar curtailments have been rising amid grid constraints. It was a 13.4 percent decrease from the same period last year, even though solar capacity in the state has grown about 5 percent since September 2019.

California depends on solar installations for nearly 20 percent of its electricity generation, and has more solar capacity than the next five US states trailing it combined as it works to manage its solar boom sustainably. It will need even more renewable power to meet its goal of 100 percent clean electricity generation by 2045, building on a recent near-100% renewable milestone that underscored the transition. The state’s emphasis on solar power is part of its long-term efforts to avoid more devastating effects of climate change. But in the short term, California’s renewables are already grappling with rising temperatures.

Two records were smashed early this September that contributed to the loss of solar power. California surpassed 2 million acres burned in a single fire season for the first time (1.7 million more acres have burned since then). And on September 15th, small particle pollution reached the highest levels recorded since 2000, according to the California Air Resources Board. Winds that stoked the flames also drove pollution from the largest fires in Northern California to Southern California, where there are more solar farms.

Smaller residential and commercial solar systems were affected, too, and solar panels during grid blackouts typically shut off for safety, although smoke was the primary issue here. “A lot of my systems were producing zero power,” Steve Pariani, founder of the solar installation company Solar Pro Energy Systems, told the San Mateo Daily Journal in September.

As the planet heats up, California’s fire seasons have grown longer, and blazes are tearing through more land than ever before, while grid operators are also seeing rising curtailments as they integrate more renewables. For both utilities and smaller solar efforts, wildfire smoke will continue to darken solar energy’s otherwise bright future, even as it becomes the No. 3 renewable source in the U.S. by generation.

 

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Yukon receives funding for new wind turbines

Yukon Renewable Energy Funding backs wind turbines, grid-scale battery storage, and transmission line upgrades, cutting diesel dependence, lowering greenhouse gas emissions, and strengthening Yukon Energy's isolated grid for remote communities, local jobs, and future growth.

 

Key Points

Federal support for Yukon projects adding wind, battery storage, and grid upgrades to cut diesel use and emissions.

✅ Three 100 kW wind turbines will power Destruction Bay.

✅ 8 MW battery storage smooths peaks and reduces diesel.

✅ Mayo-McQuesten 138 kV line upgrade boosts reliability.

 

Kluane First Nation in Yukon will receive a total of $3.1 million in funding from the federal government to install and operate wind turbines that will help reduce the community’s diesel reliance.

According to a release, the community will integrate three 100-kilowatt turbines in Destruction Bay, Yukon, providing a renewable energy source for their local power grid that will reduce greenhouse gas emissions and create local jobs in the community.

A $2-million investment from Natural Resources Canada came from the Clean Energy for Rural and Remote Communities Program, part of the Government of Canada’s Investing in Canada infrastructure plan, which supports green energy solutions across jurisdictions. Crown-Indigenous Relations’ and Northern Affairs Canada also contributed a $1.1-million investment from the Northern REACHE Program.

Also, the Government of Canada announced more than $39.2 million in funding for two Yukon Energy projects that will increase the reliability of Yukon’s electrical grid, including exploration of a potential connection to the B.C. grid to bolster resiliency, and help build the robust energy system needed to support future growth. The investment comes from the government’s Green Infrastructure Stream (GIS) of the Investing in Canada infrastructure plan.

 

Project 1: Grid-scale battery storage

The federal government is investing $16.5 million in Yukon Energy’s construction of a new battery storage system in Yukon. Once completed, the 8 MW battery will be the largest grid-connected battery in the North, and one of the largest in Canada, alongside major Ontario battery projects underway.

The new battery is a critical investment in Yukon Energy’s ability to meet growing demands for power and securing Yukon’s energy future. As an isolated grid, one of the largest challenges Yukon Energy faces is meeting peak demands for power during winter months, as electrification grows with EV adoption in the N.W.T. and beyond.

When complete, the new system will store excess electricity generated during off-peak periods, complementing emerging vehicle-to-grid integration approaches, and provide Yukoners with access to more power during peak periods. This new energy storage system will create a more reliable power supply and help reduce the territory’s reliance on diesel fuel. Over the 20-year life of project, the new battery is expected to reduce carbon emissions in Yukon by more than 20,000 tonnes.

A location for the new battery energy storage system has not been identified. Yukon Energy will begin permitting of the project in 2020 with construction targeted to be complete by mid-2023.

 

Project 2: Replacing and upgrading the Mayo to McQuesten Transmission Line

Yukon Energy has received $22.7 million in federal funding to proceed with Stage 1 of the Stewart to Keno City Transmission Project – replacing and upgrading the 65 year-old transmission line between Mayo and McQuesten. The project also includes the addition of system protection equipment at the Stewart Crossing South substation. The Yukon government, through the Yukon Development Corporation, has already provided $3.5 million towards planning for the project.

Replacing the Mayo to McQuesten transmission line is critical to Yukon Energy’s ability to deliver safe and reliable electricity to customers in the Mayo and Keno regions, mirroring broader regional transmission initiatives that enhance grid resilience, and to support economic growth in Yukon. The transmission line has reached end-of-life and become increasingly unreliable for customers in the area.

The First Nation of Na-Cho Nyak Dun has expressed their support of this project. The project has also been approved by the Yukon Environmental and Socio-Economic Assessment Board.

Yukon Energy will begin replacing and upgrading the 31 km transmission line between Mayo and McQuesten in 2020. Construction is expected to be complete in late 2020. When finished, the new 138 kV transmission line will provide more reliable electricity to customers in the Mayo and Keno regions and be equipped to support industrial growth and development in the area, including the Victoria Gold Mine, with renewable power from the Yukon grid.

Planning work for the remainder of the Stewart to Keno City Transmission Project has been completed. Yukon Energy continues to explore funding opportunities that are needed to proceed with other stages of the project.

 

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Frustration Mounts as Houston's Power Outage Extends

Houston Power Outage Heatwave intensifies a prolonged blackout, straining the grid and infrastructure resilience; emergency response, cooling centers, and power restoration efforts race to protect vulnerable residents amid extreme temperatures and climate risks.

 

Key Points

A multi-day blackout and heatwave straining Houston's grid, limiting cooling, and prompting emergency response.

✅ Fourth day without power amid dangerous heat

✅ Grid failures expose infrastructure vulnerabilities

✅ Cooling centers, aid groups support vulnerable residents

 

Houston is enduring significant frustration and hardship as a power outage stretches into its fourth day amid a sweltering heatwave. The extended blackout has exacerbated the challenges faced by residents in one of the nation’s largest and most dynamic cities, underscoring the critical need for reliable infrastructure and effective emergency response systems.

The power outage began early in the week, coinciding with a severe heatwave that has driven temperatures to dangerous levels. With the city experiencing some of the highest temperatures of the year, the lack of electricity has left residents without essential cooling, contributing to widespread discomfort and health risks. The heatwave has placed an added strain on Houston's already overburdened power grid, which has struggled to cope with the soaring demand for air conditioning and cooling.

The prolonged outage has led to escalating frustration among residents. Many households are grappling with sweltering indoor temperatures, leading to uncomfortable living conditions and concerns about the impact on vulnerable populations, including the elderly, young children, and individuals with pre-existing health conditions. The lack of power has also disrupted daily routines, as morning routine disruptions in London demonstrate, including access to refrigeration for food, which has led to spoilage and further complications.

Emergency services and utility companies have been working around the clock to restore power, but progress has been slow, echoing how Texas utilities struggled to restore power during Hurricane Harvey, as crews contended with access constraints. The complexity of the situation, combined with the high demand for repairs and the challenging weather conditions, has made it difficult to address the widespread outages efficiently. As the days pass, the situation has become increasingly dire, with residents growing more impatient and anxious about when they might see a resolution.

Local officials and utility providers have been actively communicating with the public, providing updates on the status of repairs and efforts to restore power. However, the communication has not always been timely or clear, leading to further frustration among those affected. The sense of uncertainty and lack of reliable information has compounded the difficulties faced by residents, who are left to manage the impacts of the outage with limited guidance.

The situation has also raised questions about the resilience of Houston’s power infrastructure. The outage has highlighted vulnerabilities in the city's energy grid, similar to how a recent windstorm caused significant outages elsewhere, which has faced previous challenges but has not experienced an extended failure of this magnitude in recent years. The inability of the grid to withstand the extreme heat and maintain service during a critical time underscores the need for infrastructure improvements and upgrades to better handle similar situations in the future.

In response to the crisis, community organizations and local businesses have stepped up to provide support to those in need, much like Toronto's cleanup after severe flooding mobilized volunteers and services, in order to aid affected residents. Cooling centers have been established to offer relief from the heat, providing a respite for individuals who are struggling to stay cool at home. Additionally, local food banks and charitable organizations are distributing essential supplies to those affected by food spoilage and other challenges caused by the power outage.

The power outage and heatwave have also sparked broader discussions about climate resilience and preparedness. Extreme weather events and prolonged heatwaves are becoming increasingly common due to climate change, as strong winds knocked out power across the Miami Valley recently, raising concerns about how cities and infrastructure systems can adapt to these new realities. The current situation in Houston serves as a stark reminder of the importance of investing in resilient infrastructure and developing comprehensive emergency response plans to mitigate the impacts of such events.

As the outage continues, there is a growing call for improved strategies to manage power grid failures, with examples like the North Seattle outage affecting 13,000 underscoring the need, and better support for residents during crises. Advocates are urging for a reevaluation of emergency response protocols, increased investment in infrastructure upgrades, and enhanced communication systems to ensure that the public receives timely and accurate information during emergencies.

In summary, Houston's power outage, now extending into its fourth day amid extreme heat, has caused significant frustration and hardship for residents. The prolonged disruption has underscored the need for more resilient energy infrastructure, as seen when power outages persisted for hundreds in Toronto, and effective emergency response measures. With temperatures soaring and the situation continuing to unfold, the city faces a critical challenge in restoring power, managing the impacts on its residents, and preparing for future emergencies. The crisis highlights broader issues related to infrastructure resilience and climate adaptation, emphasizing the need for comprehensive strategies to address and mitigate the effects of extreme weather events.

 

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27 giant parts from China to be transported to wind farm in Saskatchewan

Port of Vancouver Wind Turbine Blades arrive from China for a Saskatchewan wind farm, showcasing record oversized cargo logistics, tandem crane handling, renewable energy capacity, and North America's longest blades from Goldwind.

 

Key Points

Record-length blades for a Canadian wind farm, boosting renewable energy and requiring heavy-lift logistics at the port.

✅ 27 blades unloaded via tandem cranes with cage supports

✅ 50 turbines headed to Assiniboia over 21 weeks

✅ Largest 250 ft blades to arrive; reduced CO2 vs coal

 

A set of 220-foot-long wind turbine blades arrived at the Port of Vancouver from China over the weekend as part a shipment bound for a wind farm in Canada, alongside BC generating stations coming online in the region.

They’re the largest blades ever handled by the port, and this summer, even larger blades will arrive as companies expand production such as GE’s blade factory in France to meet demand — the largest North America has ever seen.

Alex Strogen described the scene as crews used two tandem cranes to unload 27 giant white blades from the MV Star Kilimanjaro, which picked up the wind turbine assemblies in China. They were manufactured by Goldwind Co.

“When you see these things come off and put onto these trailers, it’s exceptional in the sheer length of them,” Strogen said. “It looks as long as an airplane.”

In fact, each blade is about as long as the wingspan of a Boeing 747.

Groups of longshoremen attached the cranes to each blade and hoisted it into the air and onto a waiting truck. Metal cage-like devices on both ends kept the blades from touching the ground. Once loaded onto the trucks, the blades and shaft parts head to a terminal to be unloaded by another group of workers.

Another fleet of trucks will drive the wind turbines, towers and blades to Assiniboia, Saskatchewan, Canada, over the course of 21 weeks. Potentia Renewables of Toronto is erecting the turbines on 34,000 acres of leased agriculture land, amid wind farm expansion in PEI elsewhere in the country, according to a news release from the Port of Vancouver.

Potentia’s project, called the Golden South Wind Project, will generate approximately 900,000 megawatt-hours of electricity. It also has greatly reduced CO2 emissions compared with a coal-fired plant, and complements tidal power in Nova Scotia in Canada’s clean energy mix, according to the news release.

The project is expected to be operating in 2021, similar to major UK offshore wind additions coming online.

The Port of Vancouver will receive 50 full turbines of two models for the project, as Manitoba invests in new turbines across Canada. In August, the larger of the models, with blades measuring 250 feet, will arrive. They’ll be the longest blades ever imported into any port in North America.

“It’s an exciting year for the port,” said Ryan Hart, chief external affairs officer.

The Port of Vancouver is following all the recommended safety precautions during the COVID-19 pandemic, including social distancing and face masks, Strogen said, with support from initiatives like Bruce Power’s PPE donation across Canada.
As for crews onboard the ships, the U.S. Coast Guard is the agency in charge, and it is monitoring the last port-of-call for all vessels seeking to enter the Columbia River, Hart wrote in an email.

Vessel masters on each ship are responsible for monitoring the health of the crew and are required to report sick or ill crew members to the USCG prior to arrival or face fines and potential arrest.

 

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Hydro One shares jump 5.7 per cent after U.S. regulators reject $6.7B takeover

Hydro One Avista takeover rejection signals Washington regulators blocking a utility acquisition over governance risk, EPS dilution, and balance sheet impact, as investors applaud share price gains and a potential US$103M break fee.

 

Key Points

A regulator-led block of Hydro One's Avista bid, citing EPS dilution, balance sheet risk, and governance concerns.

✅ Washington denies approval; Idaho, Oregon decisions pending.

✅ EPS dilution avoided; balance sheet strength preserved.

✅ Shares rise 5.7%; US$103M break fee if deal collapses.

 

Opposition politicians may not like it but investors are applauding the rejection of Hydro One Ltd.'s $6.7-billion Avista takeover of U.S.-based utility Avista Corp.

Shares in the power company controlled by the Ontario government, which has also proposed a bill redesign to simplify statements, closed at $21.53, up $1.16 or 5.7 per cent, on the Toronto Stock Exchange on Thursday.

On Wednesday, Washington State regulators said they would not allow Ontario's largest utility to buy Avista over concerns about political risk that the provincial government, which owns 47 per cent of Hydro One's shares, might meddle in Avista's operations.

Financial analysts had predicted investors would welcome the news because the deal, announced in July 2017, would have eroded earnings per share and weakened Hydro One's balance sheet.

"The Washington regulator's denial of Avista is a positive development for the shares, in our opinion," said analyst Ben Pham of BMO Capital Markets in a report on Wednesday.

"While this may sound odd, we note that the Avista deal is expected to be EPS dilutive and result in a weaker balance sheet for (Hydro One). Not acquiring Avista and refocusing its attention on its core Ontario franchise ... along with related interprovincial arrangements such as the Ontario-Quebec electricity deal under discussion would likely be viewed positively if the deal ultimately breaks."

Decisions are yet to come from Idaho and Oregon state regulators, but Washington was probably the most important as the state contains customers making up about 60 per cent of Avista's rate base, Pham said.

He pointed out that a US$103-million break fee is to be paid to Avista if the deal collapses due to a failure to obtain regulatory approval.

CIBC analyst Robert Catellier raised his 12-month Hydro One target price by 25 cents and said many shareholders will feel "relieved" that the deal had failed.

He warned that the company's earnings power could deteriorate as the province seeks to reduce power bills by 12 per cent, despite an Ontario-Quebec hydro deal that may not lower costs.

 

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BC Hydro Rates to Rise by 3.75% Over Two Years

British Columbia electricity rate increase will raise BC Hydro bills 3.75% over 2025-2026 to fund infrastructure, Site C, and clean energy, balancing affordability, reliability, and energy security while keeping prices below the North American average.

 

Key Points

BC will raise BC Hydro rates 3.75% in 2025-2026, about $3.75/month, to fund grid upgrades, Site C, and clean energy.

✅ 3.75% over 2025-2026; about $3.75/month on $100 average bill

✅ Funds Site C, grid maintenance, and clean energy capacity

✅ Keeps BC Hydro rates below North American averages

 

British Columbia's electricity rates will experience a 3.75% increase over the next two years, following an earlier 3% rate increase approval that set the stage, as confirmed by the provincial government on March 17, 2025. The announcement was made by Minister of Energy and Climate Solutions, Adrian Dix, who emphasized the decision's necessity for maintaining BC Hydro’s infrastructure while balancing affordability for residents.

For most households, the increase will amount to an additional $3.75 per month, based on an average BC Hydro bill of $100, though some coverage framed an earlier phase as a BC Hydro $2/month proposal that later evolved. While this may seem modest, the increase reflects a broader strategy to stabilize the utility's rates amidst economic challenges and ensure long-term energy security for the province.

Reasons Behind the Rate Hike

The rate increase comes during a period of rising costs in both global markets and local economies. According to Dix, the economic uncertainty stemming from trade dynamics and inflation has forced the government to act. Despite these pressures, and after a prior B.C. rate freeze to moderate impacts, the increase remains below cumulative inflation over the last several years, a move designed to shield consumers from the full force of these economic changes.

Dix also noted that, when adjusted for inflation, electricity rates in British Columbia in 2025 are effectively at the same price they were four decades ago. This stability, he argued, underscores the provincial government’s commitment to keeping rates as low as possible for residents, even as operating costs rise.

“We must take urgent action to protect British Columbians from the uncertainty posed by rising costs while building a strong, resilient electricity system for the long-term benefit of B.C.’s energy independence,” Dix said. He also highlighted the government's approach to minimizing the financial burden on consumers by keeping electricity costs well below the North American average.

Infrastructure and Maintenance Costs

The primary justification for the rate increase is to allow BC Hydro to continue its critical infrastructure development, including the Site C hydroelectric project, which is expected to become operational in the coming years. The increased costs of maintaining and upgrading the province's electricity grid also contribute to the need for higher rates.

The Site C project, a massive hydroelectric dam under construction on the Peace River, is expected to provide a substantial increase in clean, renewable energy capacity. However, such large-scale projects require significant investment and maintenance, both of which have contributed to the increased operating costs for BC Hydro.

A Strategic Move for Rate Stability

The provincial government has been clear that the rate increase will allow for a continuation of infrastructure development while keeping the rates manageable for consumers. The 3.75% increase will be spread across two years, with the first hike scheduled for April 1, 2025, reflecting the typical April rate changes BC Hydro implements, and the second for April 1, 2026.

Dix confirmed that the rate hike would still keep electricity costs among the lowest in North America, noting that British Columbians pay about half of what residents in Alberta pay for electricity. This is part of a broader effort by the provincial government to provide stable energy pricing while bolstering the transition to clean energy solutions, such as the Site C project and other renewable energy initiatives.

Addressing Public Concerns

Although the government has framed the increase as a necessary measure to ensure the province's long-term energy independence and reliability, the rate hikes are likely to face scrutiny from residents, particularly those already struggling with the rising cost of living, even as provinces like Ontario face their own Ontario hydro rate increase pressures this fall.

Public reactions to utility rate increases are often contentious, as residents feel the pressure of rising prices across various sectors, from housing to healthcare. However, the government has promised that the new rates will remain manageable, especially considering the relatively low rate increases compared to inflation and other regions where Manitoba Hydro scaled back a planned increase to temper impacts.

Furthermore, the increase comes as part of a broader strategy that aims to keep the overall impact on consumers as low as possible. Minister Dix emphasized that these rate increases were intended to ensure the continued reliability of BC Hydro’s services, without overwhelming ratepayers.

Long-Term Goals

Looking ahead, the province's strategy centers on not only maintaining affordable electricity rates but also reinforcing the importance of renewable energy, while some jurisdictions consider a 2.5% annual increase plan over multiple years to stabilize their grids. As climate change becomes an increasingly pressing issue, BC’s investments in clean energy projects like Site C aim to provide sustainable power for generations to come.

The government’s long-term vision involves building a resilient, energy-independent province that can weather future economic and environmental challenges. In this context, the rate increases are framed not just as a response to immediate inflationary pressures but as a necessary step in preparing BC’s energy infrastructure for the future.

The 3.75% rate increase set for 2025 and 2026 represents a balancing act between managing the financial health of BC Hydro and protecting consumers from higher costs. While the increase will have a modest effect on household bills, the long-term goal is to build a more robust and sustainable electricity system for British Columbia’s future. Through investments in clean energy and strategic infrastructure development, the province aims to keep electricity rates competitive while positioning itself as a leader in energy independence and climate action.

 

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