Japan closes Hamaoka nuclear plant

Hydro-Québec Carillon Refurbishment delivers a $750M hydropower modernization, replacing six turbines and upgrading civil works, water passageways, and grid equipment to extend run-of-river, renewable energy output for peak demand near Montréal.

Key Points

A $750M project replacing six units and upgrading civil, water and electrical systems to supply power for 50 years.

✅ Replaces six generating units with Andritz turbines.

✅ Upgrades civil works, water passageways, and electrical gear.

✅ Extends run-of-river output for 50 years; boosts peak supply.

Hydro-Québec will invest $750 million to refurbish its Carillon generating station with a major powerhouse upgrade that will mainly replace six generating units. The investment also covers the cost of civil engineering work, including making adjustments to water passageways, upgrading electrical equipment and replacing the station roof. Work will start in 2021, aligning with Hydro-Québec's capacity expansion plans for 2021, and continue until 2027.

Carillon generating station is a run-of-river power plant consisting of 14 generating units with a total installed capacity of 753 MW. Built in the early 1960s, it is a key part of Hydro-Québec's hydroelectric generating fleet, which includes the La Romaine complex as well. The station is close to the greater Montréal area and feeds power into the grid to support industrial demand growth during peak consumption periods.

The selected supplier, turbine manufacturer Andritz, has been asked to maximize the project's economic spinoffs in Québec, as Canada continues investing in new turbines across the country to modernize assets. Once the work is completed, the new generating units will be able to provide clean, renewable energy, supporting Hydro-Québec's strategy to reduce fossil fuel reliance for the next 50 years.

"Carillon generating station is a symbol of our hydroelectric development and plays a strategic role in our production fleet. However, most of the generating units' main components date back to the station's original construction from 1959 to 1962. Hydropower generating stations have long service lives - with this refurbishment, Carillon will be producing clean renewable energy for decades to come." said David Murray, Chief Innovation Officer and President, Hydro-Québec Production.

"In light of today's economic situation, this is an important announcement that clearly reaffirms Hydro-Québec's role in relaunching Québec's economy and strengthening interprovincial electricity partnerships that open new markets. Over 600,000 hours of work will be required for everything from the engineering work to component assembly, creating many new high-quality skilled jobs for Québec industries."

Related News

• Electricity Forum News

• Power Generation News

California Grid Modernization Funding will upgrade transmission and distribution, boost grid resilience, enable renewable energy integration, expand energy storage, and deploy smart grid controls statewide with over $500 million in federal infrastructure investment.

Key Points

Federal support to harden California's grid, integrate renewables, add storage, and deploy smart upgrades for reliability.

✅ Strengthens transmission and distribution for wildfire and heat resilience

✅ Integrates solar and wind with storage and advanced grid controls

✅ Deploys smart meters, DER management, and modern cybersecurity

California has recently been awarded over $500 million in federal funds to significantly improve and modernize its power grid. This substantial investment marks a pivotal step in addressing the state’s ongoing energy challenges, enhancing grid resilience, and supporting its ambitious climate goals. The funding, announced by federal and state officials, is set to bolster California’s efforts to upgrade its electrical infrastructure, integrate renewable energy sources, and ensure a more reliable and sustainable energy system for its residents.

California's power grid has faced numerous challenges in recent years, including extreme weather events, high energy demand, and an increasing reliance on renewable energy sources. The state's electrical infrastructure has struggled to keep pace with these demands, leading to concerns about reliability, efficiency, and the capacity to handle new energy technologies. The recent federal funding is a critical component of a broader strategy to address these issues and prepare the grid for future demands.

The $500 million in federal funds is part of a larger initiative to support energy infrastructure projects across the United States, including a Washington state grant that strengthens regional infrastructure. The investment aims to modernize aging grid systems, improve energy efficiency, and enhance the integration of renewable energy sources. For California, this funding represents a significant opportunity to address several key areas of concern in its power grid.

One of the primary objectives of the funding is to enhance the resilience of the power grid. California has experienced a series of extreme weather events, including wildfires and heatwaves, driven in part by climate change impacts across the U.S., which have put considerable strain on the electrical infrastructure. The new investment will support projects designed to strengthen the grid’s ability to withstand and recover from these events. This includes upgrading infrastructure to make it more robust and less susceptible to damage from natural disasters.

Another key focus of the funding is the integration of renewable energy sources. California is a leader in the adoption of solar and wind energy, and the state has set ambitious goals for increasing its use of clean energy. However, integrating these variable energy sources into the grid presents technical challenges, including ensuring a stable and reliable power supply. The federal funds will be used to develop and deploy advanced technologies that can better manage and store renewable energy, such as battery storage systems, improving the overall efficiency and effectiveness of the grid.

In addition to resilience and renewable integration, the funding will also support efforts to modernize grid infrastructure. This includes upgrading transmission and distribution systems, implementing smarter electricity infrastructure and smart grid technologies, and enhancing grid management and control systems. These improvements are essential for creating a more flexible and responsive power grid that can meet the evolving needs of California’s energy landscape.

The investment in grid modernization also aligns with California’s broader climate goals. The state has set targets to reduce greenhouse gas emissions and increase the use of clean energy sources as it navigates keeping the lights on during its energy transition. By improving the power grid and supporting the integration of renewable energy, California is making progress toward achieving these goals while also creating jobs and stimulating economic growth.

The allocation of federal funds comes at a crucial time for California. The state has faced significant challenges in recent years, including power outages, energy reliability issues, and increasing energy costs that make repairing California's grid especially complex today. The new funding is expected to address many of these concerns by supporting critical infrastructure improvements and ensuring that the state’s power grid can meet current and future demands.

Federal and state officials have expressed strong support for the funding and its potential impact. The investment is seen as a major step forward in creating a more resilient and sustainable energy system for California. It is also expected to serve as a model for other states facing similar challenges in modernizing their power grids and integrating renewable energy sources.

The federal funding is part of a broader push to address infrastructure needs across the country. The Biden administration has prioritized investment in energy infrastructure, including a $34 million DOE initiative supporting grid improvements, as part of its broader agenda to combat climate change and build a more sustainable economy. The funding for California’s power grid is a reflection of this commitment and an example of how federal resources can support state and local efforts to improve infrastructure and address pressing energy challenges.

In summary, California’s receipt of over $500 million in federal funds represents a significant investment in the state’s power grid. The funding will support efforts to enhance grid resilience, integrate renewable energy sources, and modernize infrastructure. As California continues to face challenges related to extreme weather, energy reliability, and climate goals, this investment will play a crucial role in building a more reliable, efficient, and sustainable energy system. The initiative also highlights the importance of federal support in addressing infrastructure needs and advancing environmental and economic goals.

Related News

• Electricity Forum News

• Grid Technologies News

EIA U.S. Power Outlook 2023-2024 forecasts lower electricity demand, softer wholesale prices, and faster renewable growth from solar and wind, with steady natural gas, reduced coal generation, slight nuclear gains, and ERCOT market moderation.

Key Points

An EIA forecast of a 2023 demand dip, 2024 rebound, lower prices, and a higher renewable share in the U.S. power mix.

✅ Demand dips to 4,000 billion kWh in 2023; rebounds in 2024.

✅ ERCOT on-peak prices average about $35/MWh versus $80/MWh in 2022.

✅ Renewables grow to 24% share; coal falls to 17%; nuclear edges up.

U.S. power consumption is expected to slip about 1% in 2023 from the previous year as milder weather slows usage from the record high hit in 2022, consistent with recent U.S. consumption trends observed over the past several years, the U.S. Energy Information Administration (EIA) said in its Short-Term Energy Outlook (STEO).

EIA projected that electricity demand is on track to slide to 4,000 billion kilowatt-hours (kWh) in 2023 from a historic high of 4,048 billion kilowatt-hours (kWh) in 2022, reflecting patterns seen during COVID-19 demand shifts in prior years, before rising to 4,062 billion kWh in 2024 as economic growth ramps up.

Less demand coupled with more electricity generation from cheap renewable power sources and lower natural gas prices is forecast to slash wholesale power prices this year, the EIA said.

The on-peak wholesale price at the North hub in Texas’ ERCOT power market is expected to average about $35 per megawatt-hour (MWh) in 2023 compared with an average of nearly $80/MWh in 2022 after the 2022 price surge in power markets.

As capacity for renewables like solar and wind ramp up and as natural gas prices ease amid the broader energy crisis pressures, the EIA said it expects coal-fired power generation to be 17% less in the spring of 2023 than in the spring of 2022.

Coal will provide an average of 17% of total U.S. generation this year, down from 20% last year, as utilities shift investments toward electricity delivery and away from new power production, the EIA said.

The share of total generation supplied by natural gas is seen remaining at about the same this year at 39%. The nuclear share of generation is seen rising slightly to 20% this year from 19% in 2022. Generation from renewable energy sources grows the most in the forecast, increasing to 24% this year from a share of 22% last year, even as residential electricity bills rose in 2022 across the U.S.

Related News

• Electricity Forum News

• Energy Policy News

SaskPower Summer Power Demand Record hits 3,520 MW as heat waves drive electricity consumption; grid capacity, renewables expansion, and energy efficiency tips highlight efforts to curb greenhouse gas emissions while meeting Saskatchewan's growing load.

Key Points

The latest summer peak load in Saskatchewan: 3,520 MW, driven by heat, with plans to expand capacity and lower emissions.

✅ New peak surpasses last August by 50 MW to 3,520 MW.

✅ Capacity target: 7,000 MW by 2030 with more renewables.

✅ Tips: AC settings, close blinds, delay heat-producing chores.

As the mercury continues to climb in Saskatchewan, where Alberta's summer electricity record offers a regional comparison, SaskPower says the province has set a new summer power demand record.

The Crown says the new record is 3,520 megawatts. It’s an increase of 50 megawatts over the previous record, or enough electricity for 50,000 homes.

“We’ve seen both summer and winter records set every year for a good while now. And if last summer is any indication, we could very well see another record before temperatures cool off heading into the fall,” said SaskPower Vice President of Transmission and Industrial Services Kory Hayko in a written release. “It’s not impossible we’ll break this record again in the coming days. It’s SaskPower’s responsibility to ensure that Saskatchewan people and businesses have the power they need to thrive. That’s what drives our investment of $1 billion every year, as outlined in our annual report, to modernize and grow the province’s electrical system.”

The previous summer consumption record of 3,740 megawatts was set last August, and similar extremes in the Yukon electricity demand highlight broader demand pressures this year. The winter demand record remains higher at 3,792 megawatts, set on Dec. 29, 2017.

SaskPower says it plans to expand its generation capacity from 4,500 megawatts now to 7,000 megawatts in 2030, with a focus on decreasing greenhouse gas emissions and doubling renewable electricity by 2030 as part of its strategy.

To reduce power bills, the Crown suggests turning down or programming air conditioning when residents aren’t home, inspecting the air conditioner to make sure it is operating efficiently, keeping blinds closed to keep out direct sunlight, delaying chores that produce heat and making sure electronics are turned off when people leave the room.

The new record beats the previous summer peak of 3,470 MW, set last August after also being broken twice in July. The winter demand record is still higher at 3,792 MW, which was set on December 29, 2017. To meet growing power demand, and amid projections that Manitoba's electrical demand could double in the next 20 years, SaskPower is expanding its generation capacity from approximately 4,500 MW now to 7,000 MW by 2030 while also reducing greenhouse gas emissions by 40 per cent from 2005 levels. To accomplish this, we will be significantly increasing the amount of renewables on our system.

Cooling and heating represents approximately a quarter of residential power bills. To reduce consumption and power bills during heat waves, SaskPower’s customers can:

Turn down or program the air conditioning when no one is home (for every degree that air conditioning is lowered for an eight-hour period, customers can save up to two per cent on their power costs);

Consider having their air conditioning unit inspected to make sure it is operating efficiently;

Keep the heat out by closing blinds and drapes, especially those with direct sunlight;

Delay chores that produce heat and moisture, like dishwashing and laundering, until the cooler parts of the day or evening; and

As with any time of the year, make sure lights, televisions and other electronics are turned off when no one's in the room. For example, a modern gaming console can use as much power as a refrigerator.

Related News

• Electricity Forum News

• Power Generation News

Texas PUC Electricity Market Reforms aim to boost grid reliability, support ERCOT resilience, pay standby generators, require capacity procurement, and mitigate blackout risk, though analysts warn higher consumer bills and winter reserve margin deficits.

Key Points

PUC proposals to bolster ERCOT reliability via standby capacity, capacity procurement, and measures to reduce blackout risk.

✅ Pays generators for standby capacity during grid stress

✅ Requires capacity procurement to meet forecast demand

✅ Could raise consumer bills despite reliability gains

The Public Utility Commission of Texas is discussing major reforms to the state’s electricity market with the purpose to avoid a repeat of the power failures and blackouts during the February 2021 winter storm, which led to the death of more than 100 people and left over 11 million residents without electricity for days.

The regulator is discussing at a meeting on Thursday around a dozen proposals to make the grid more stable and reliable in case of emergencies. Proposals include paying power generators that are on standby when the grid needs backup, and requiring companies to pre-emptively buy capacity to meet future demand.

It is not clear yet how many and which of the proposals for electricity market reforms PUC will endorse today, while Texans vote on funding to modernize electricity generation later this year.

Analysts and consumer protection bodies warn that the measures will raise the energy bills for consumers, as some electricity market bailout ideas shift costs to ratepayers as well.

“Customers will be paying for more, but will they be getting more reliability?” Michael Jewell, an attorney with Jewell & Associates PLLC who represents clients at PUC proceedings, told Bloomberg.

“This is going to take us further down a path that’s going to increase cost to consumers, we better be darn sure these are the right choices,” Tim Morstad, Associate State Director, AARP Texas, told FOX 4 NEWS.

Last month, a report by the North American Electric Reliability Corp warned that the Texas power grid remained vulnerable to blackouts in case of a repeat of this year’s February Freeze.

Beyond Texas, electricity blackout risks have been identified across the U.S., underscoring the stakes for grid planning.

According to the 2021-2022 Winter Reliability Assessment report, Texas risks a 37-percent reserve margin deficit in case of a harsh winter, with ERCOT moving to procure capacity to address winter concerns, NERC said.

A reserve margin is the reserve of power generation capacity comparative to demand. The expected reserve margin for Texas for this winter, according to NERC, is 41.9 percent. Yet if another cold spell hits the state, it would affect this spare capacity, pushing the margin deeply into negative territory.

Related News

• Electricity Forum News

• Energy Policy News

Montreal Power Outage linked to Hydro-Que9bec infrastructure after an underground explosion and manhole fire in Rosemont–La Petite–Patrie, disrupting the STM Blue Line and forcing strategic, cold-weather grid restoration on Be9langer Street.

Key Points

Outage from an underground blast and manhole fire disrupted STM service; Hydro-Que9bec restored the grid in cold weather.

✅ Peak impact: 41,000 customers; 10,981 still without power by 7:00 p.m.

✅ STM Blue Line restored after afternoon shutdown; Be9langer Street reopened.

✅ Hydro-Que9bec pacing restoration to avoid grid overload in cold weather.

Hydro-Québec says a power outage affecting Montreal is connected to an underground explosion and a fire in a manhole in Rosemont—La Petite–Patrie. 

The fire started in underground pipes belonging to Hydro-Québec on Bélanger Street between Boyer and Saint-André streets, according to Montreal firefighters, who arrived on the scene at 12:18 p.m.

The electricity had to be cut so that firefighters could get into the manhole where the equipment was located.

At the peak of the shutdown, nearly 41,000 customers were without power across Montreal.  As of 7:00 p.m., 10,981 clients still had no power.

In similar storms, Toronto power outages have persisted for hundreds, underscoring restoration challenges.

Hydro-Québec spokesperson Louis-Olivier Batty said the utility is being strategic about how it restores power across the grid. 

Because of the cold, and patterns seen during freezing rain outages, it anticipates that people will crank up the heat as soon as they get their electricity back, and that could trigger an overload somewhere else on the network, Batty said.

The Metro's Blue line was down much of the afternoon, but the STM announced the line was back up and running just after 4:30 p.m.

Bélanger Street was blocked to traffic much of the afternoon, however, it has now been reopened.

Batty said once the smoke clears, Hydro-Québec workers will take a look at the equipment to see what failed. 

Related News

• Electricity Forum News

• Utility Operations News