Helix Electric completes project for new UNLV Greenspun College

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Helix Electric, one of the largest open shop electrical contractors in the nation, has announced that it has completed the electrical subcontracting work the University of Nevada, Las Vegas Greenspun College of Urban Affairs in Las Vegas.

The Greenspun Family Foundation donated $37 million for the state-of-the-art building, the largest single donation in UNLV history, and one of the largest in state history.

Helix provided the fire alarm, a value engineered lighting system, UPS, general set theatrical lighting, rigging and an air acuity system, which detects unhealthy chemicals in the building.

The Greenspun College of Urban Affairs offers unparalleled opportunities for students who want to make a difference in their communities and in the lives of others. A Leadership in Energy and Environmental Design (LEED) project, the Greenspun College of Urban Affairs building is home to classrooms, an auditorium, two television studios, a radio station and offices.

The LEED designation is the result of a Green Building Rating System, which gauges building sustainability and efficiency through the use of alternative and renewable energy technologies. Innovative energy features for the building include chilled beams for heating and cooling, extensive use of natural light and a comprehensive photovoltaic array that will account for more than 15 percent of the total annual energy.

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Japan to host one of world's largest biomass power plants

eRex Biomass Power Plant will deliver 300 MW in Japan, offering stable baseload renewable energy, coal-cost parity, and feed-in tariff independence through economies of scale, efficient fuel procurement, and utility-scale operations supporting RE100 demand.

 

Key Points

A 300 MW Japan biomass project targeting coal-cost parity and FIT-free, stable baseload renewable power.

✅ 300 MW capacity; enough for about 700,000 households

✅ Aims to skip feed-in tariff via economies of scale

✅ Targets coal-cost parity with stable, dispatchable output

 

Power supplier eRex will build its largest biomass power plant to date in Japan, hoping the facility's scale will provide healthy margins, a strategy increasingly seen among renewable developers pursuing diverse energy sources, and a means of skipping the government's feed-in tariff program.

The Tokyo-based electric company is in the process of selecting a location, most likely in eastern Japan. It aims to open the plant around 2024 or 2025 following a feasibility study. The facility will cost an estimated 90 billion yen ($812 million) or so, and have an output of 300 megawatts -- enough to supply about 700,000 households. ERex may work with a regional utility or other partner

The biggest biomass power plant operating in Japan currently has an output of 100 MW. With roughly triple that output, the new facility will rank among the world's largest, reflecting momentum toward 100% renewable energy globally that is shaping investment decisions.

Nearly all biomass power facilities in Japan sell their output through the government-mediated feed-in tariff program, which requires utilities to buy renewable energy at a fixed price. For large biomass plants that burn wood or agricultural waste, the rate is set at 21 yen per kilowatt-hour. But the program costs the Japanese public more than 2 trillion yen a year, and is said to hamper price competition.

ERex aims to forgo the feed-in tariff with its new plant by reaping economies of scale in operation and fuel procurement. The goal is to make the undertaking as economical as coal energy, which costs around 12 yen per kilowatt-hour, even as solar's rise in the U.S. underscores evolving benchmarks for competitive renewables.

Much of the renewable energy available in Japan is solar power, which fluctuates widely according to weather conditions, though power prediction accuracy has improved at Japanese PV projects. Biomass plants, which use such materials as wood chips and palm kernel shells as fuel, offer a more stable alternative.

Demand for reliable sources of renewable energy is on the rise in the business world, as shown by the RE100 initiative, in which 100 of the world's biggest companies, such as Olympus, have announced their commitment to get 100% of their power from renewable sources. ERex's new facility may spur competition.

 

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Wind Leading Power

UK Wind Power Surpasses Gas as offshore wind and solar drive record electricity generation, National Grid milestones, and net zero progress, despite grid capacity bottlenecks, onshore planning reforms, demand from heat pumps and transport electrification.

 

Key Points

A milestone where wind turbines generated more UK electricity than gas, advancing progress toward a net zero grid.

✅ Offshore wind delivered the majority of UK wind generation

✅ Grid connection delays stall billions in green projects

✅ Planning reforms may restart onshore wind development

 

Wind turbines have generated more electricity than gas, as wind becomes the main source for the first time in the UK.

In the first three months of this year a third of the country's electricity came from wind farms, as the UK set a wind generation record that underscored the trend, research from Imperial College London has shown.

National Grid has also confirmed that April saw a record period of solar energy generation, and wind and solar outproduced nuclear in earlier milestones.

By 2035 the UK aims for all of its electricity to have net zero emissions, after a 2019 stall in low-carbon generation highlighted the challenge.

"There are still many hurdles to reaching a completely fossil fuel-free grid, but wind out-supplying gas for the first time is a genuine milestone event," said Iain Staffell, energy researcher at Imperial College and lead author of the report.

The research was commissioned by Drax Electrical Insights, which is funded by Drax energy company.

The majority of the UK's wind power has come from offshore wind farms, and the country leads the G20 for wind's electricity share according to recent analyses. Installing new onshore wind turbines has effectively been banned since 2015 in England.

Under current planning rules, companies can only apply to build onshore wind turbines on land specifically identified for development in the land-use plans drawn up by local councils. Prime Minister Rishi Sunak agreed in December to relax these planning restrictions to speed up development.

Scientists say switching to renewable power is crucial to curb the impacts of climate change, which are already being felt, including in the UK, which last year recorded its hottest year since records began.

Solar and wind have seen significant growth in the UK, with wind surpassing coal in 2016 as a milestone. In the first quarter of 2023, 42% of the UK's electricity came from renewable energy, with 33% coming from fossil fuels like gas and coal.

But BBC research revealed on Thursday that billions of pounds' worth of green energy projects are stuck on hold due to delays with getting connections to the grid, as peak power prices also climbed amid system pressures.

Some new solar and wind sites are waiting up to 10 to 15 years to be connected because of a lack of capacity in the electricity system.

And electricity only accounts for 18% of the UK's total power needs. There are many demands for energy which electricity is not meeting, such as heating our homes, manufacturing and transport.

Currently the majority of UK homes use gas for their heating - the government is seeking to move households away from gas boilers and on to heat pumps which use electricity.

 

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Canada's Ambitious Electric Vehicle Goals

Canada 2035 Gasoline Car Ban accelerates EV adoption, zero-emission transport, and climate action, with charging infrastructure, rebates, and industry investment supporting net-zero goals while addressing affordability, range anxiety, and consumer acceptance nationwide.

 

Key Points

A federal policy to end new gas car sales by 2035, boosting EV adoption, emissions goals, and charging infrastructure.

✅ Ends new gas car and light-truck sales by 2035

✅ Expands charging infrastructure and grid readiness

✅ Incentives, rebates, and industry investment drive adoption

 

Canada has set its sights on a bold and transformative goal: to ban the sale of new gasoline-powered passenger cars and light-duty trucks by the year 2035. This ambitious target, announced by the federal government, underscores Canada's commitment to combating climate change and accelerating the adoption of electric vehicles (EVs) nationwide, supported by forthcoming EV sales regulations from Ottawa.

The Federal Initiative

Under the leadership of Prime Minister Justin Trudeau, Canada aims to significantly reduce greenhouse gas emissions from the transportation sector, which accounts for a substantial portion of the country's carbon footprint. The initiative aligns with Canada's broader climate objectives, including achieving net-zero emissions by 2050.

Driving Forces Behind the Decision

The decision to phase out internal combustion engine vehicles reflects growing recognition of the urgency to transition towards cleaner transportation alternatives, even as 2019 electricity from fossil fuels still powered a notable share of Canada's grid. Minister of Environment and Climate Change Jonathan Wilkinson emphasizes the environmental benefits of electric vehicles, citing their potential to lower emissions and improve air quality in urban centers across the country.

Challenges and Opportunities

While the move towards electric vehicles presents promising opportunities for reducing emissions, it also poses challenges. Key considerations include infrastructure development, affordability, and consumer acceptance of EV technology, amid EV shortages and wait times that can influence buying decisions. Addressing these hurdles will require coordinated efforts from government, industry stakeholders, and consumers alike.

Industry Response

The automotive industry plays a crucial role in realizing Canada's EV ambitions. Automakers are increasingly investing in electric vehicle production and innovation to meet evolving consumer demand and regulatory requirements, including cross-border Canada-U.S. collaboration on supply chains. The transition offers opportunities for job creation, technological advancement, and economic growth in the clean energy sector.

Provincial Perspectives

Provinces across Canada are pivotal in facilitating the transition to electric vehicles. Some provinces have already implemented incentives such as rebates for EV purchases, charging infrastructure investments, and policy frameworks to support emissions reduction targets, even as Quebec's EV dominance push faces scrutiny from experts. Collaborative efforts between federal and provincial governments are essential in ensuring a cohesive approach to achieving national EV goals.

Consumer Considerations

For consumers, the shift towards electric vehicles represents a paradigm shift in transportation choices. Factors such as range anxiety, charging infrastructure availability, and upfront costs, with one EV cost survey citing price as the main barrier, remain considerations for prospective buyers. Government incentives and subsidies aim to alleviate some of these concerns and promote widespread EV adoption.

Looking Ahead

As Canada navigates towards a future without gasoline-powered vehicles, stakeholders must work together to overcome challenges and capitalize on opportunities presented by the electric vehicle revolution, even as critics of the 2035 mandate question its feasibility. Continued investments in infrastructure, innovation, and consumer education will be critical in paving the way for a sustainable and prosperous automotive industry.

Conclusion

Canada's commitment to phasing out gasoline-powered vehicles by 2035 marks a pivotal moment in the country's climate action agenda. By embracing electric vehicles, Canada aims to lead by example in combatting climate change, fostering innovation, and building a greener future for generations to come. The success of this ambitious initiative hinges on collective efforts to transform the automotive landscape and accelerate towards a sustainable transportation future.

 

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Germany's Call for Hydrogen-Ready Power Plants

Germany Hydrogen-Ready Power Plants Tender accelerates the energy transition by enabling clean energy generation, decarbonization, and green hydrogen integration through retrofit and new-build capacity, resilient infrastructure, flexible storage, and grid reliability provisions.

 

Key Points

Germany tender to build or convert plants for hydrogen, advancing decarbonization, energy security, and clean power.

✅ Hydrogen-ready retrofits and new-build generation capacity

✅ Supports decarbonization, grid reliability, and flexible storage

✅ Future-proof design for green hydrogen supply integration

 

Germany, a global leader in energy transition and environmental sustainability, has recently launched an ambitious call for tenders aimed at developing hydrogen-ready power plants. This initiative is a significant step in the country's strategy to transform its energy infrastructure and support the broader goal of a greener economy. The move underscores Germany’s commitment to reducing greenhouse gas emissions and advancing clean energy technologies.

The Need for Hydrogen-Ready Power Plants

Hydrogen, often hailed as a key player in the future of clean energy, offers a promising solution for decarbonizing various sectors, including power generation. Unlike fossil fuels, hydrogen produces zero carbon emissions when used in fuel cells or burned. This makes it an ideal candidate for replacing conventional energy sources that contribute to climate change.

Germany’s push for hydrogen-ready power plants reflects the country’s recognition of hydrogen’s potential in achieving its climate goals. Traditional power plants, which typically rely on coal, natural gas, or oil, emit substantial amounts of CO2. Transitioning these plants to utilize hydrogen can significantly reduce their carbon footprint and align with Germany's climate targets.

The Details of the Tender

The recent tender call is part of Germany's broader strategy to incorporate hydrogen into its energy mix, amid a nuclear option debate in climate policy. The tender seeks proposals for power plants that can either be converted to use hydrogen or be built with hydrogen capability from the outset. This approach allows for flexibility and innovation in how hydrogen technology is integrated into existing and new energy infrastructures.

One of the critical aspects of this initiative is the focus on “hydrogen readiness.” This means that power plants must be designed or retrofitted to operate with hydrogen either exclusively or in combination with other fuels. The goal is to ensure that these facilities can adapt to the growing availability of hydrogen and seamlessly transition from conventional fuels without significant additional modifications.

By setting such requirements, Germany aims to stimulate the development of technologies that can handle hydrogen’s unique properties and ensure that the infrastructure is future-proofed. This includes addressing challenges related to hydrogen storage, transportation, and combustion, and exploring concepts like storing electricity in natural gas pipes for system flexibility.

Strategic Implications for Germany

Germany’s call for hydrogen-ready power plants has several strategic implications. First and foremost, it aligns with the country’s broader energy strategy, which emphasizes the need for a transition from fossil fuels to cleaner alternatives, building on its decision to phase out coal and nuclear domestically. As part of its commitment to the Paris Agreement and its own climate action plans, Germany has set ambitious targets for reducing greenhouse gas emissions and increasing the share of renewable energy in its energy mix.

Hydrogen plays a crucial role in this strategy, particularly for sectors where direct electrification is challenging. For instance, heavy industry and certain industrial processes, such as green steel production, require high-temperature heat that is difficult to achieve with electricity alone. Hydrogen can fill this gap, providing a cleaner alternative to natural gas and coal.

Moreover, this initiative helps Germany bolster its leadership in green technology and innovation. By investing in hydrogen infrastructure, Germany positions itself as a pioneer in the global energy transition, potentially influencing international standards and practices. The development of hydrogen-ready power plants also opens up new economic opportunities, including job creation in engineering, construction, and technology sectors.

Challenges and Opportunities

While the push for hydrogen-ready power plants presents significant opportunities, it also comes with challenges. Hydrogen production, especially green hydrogen produced from renewable sources, remains relatively expensive compared to conventional fuels. Scaling up production and reducing costs are critical for making hydrogen a viable alternative for widespread use.

Furthermore, integrating hydrogen into existing power infrastructure, alongside electricity grid expansion, requires careful planning and investment. Issues such as retrofitting existing plants, ensuring safe handling of hydrogen, and developing efficient storage and transportation systems must be addressed.

Despite these challenges, the long-term benefits of hydrogen integration are substantial, and a net-zero roadmap indicates electricity costs could fall by a third. Hydrogen can enhance energy security, reduce reliance on imported fossil fuels, and support global climate goals. For Germany, this initiative is a step towards realizing its vision of a sustainable, low-carbon energy system.

Conclusion

Germany’s call for hydrogen-ready power plants is a forward-thinking move that reflects its commitment to sustainability and innovation. By encouraging the development of infrastructure capable of using hydrogen, Germany is taking a significant step towards a cleaner energy future. While challenges remain, the strategic focus on hydrogen underscores Germany’s leadership in the global transition to a low-carbon economy. As the world grapples with the urgent need to address climate change, Germany’s approach serves as a model for integrating emerging technologies into national energy strategies.

 

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N.L., Ottawa agree to shield ratepayers from Muskrat Falls cost overruns

Muskrat Falls Financing Restructuring redirects megadam benefits to ratepayers, stabilizes electricity rates, and overhauls federal provincial loan guarantees for the hydro project, addressing cost overruns flagged by the Public Utilities Board in Newfoundland and Labrador.

 

Key Points

A revised funding model shifting benefits to ratepayers to curb rate hikes linked to Muskrat Falls cost overruns.

✅ Shields ratepayers from megadam cost overruns

✅ Revises federal provincial loan guarantees

✅ Targets stable electricity rates by 2021 and beyond

 

Ottawa and Newfoundland and Labrador say they will rewrite the financial structure of the Muskrat Falls hydro project to shield ratepayers from paying for the megadam's cost overruns.

Federal Natural Resources Minister Seamus O'Regan and Premier Dwight Ball announced Monday that their two governments would scrap the financial structure agreed upon in past federal-provincial loan agreements, moving to a model that redirects benefits, such as a lump sum credit, to ratepayers.

Both politicians called the announcement, which was light on dollar figures, a major milestone in easing residents' fears that electricity rates will spike sharply, as seen with Nova Scotia's debated 14% hike, when the over-budget dam comes fully online next year.
"We are in a far better place today thanks to this comprehensive plan," Ball said.

Ball has said the issue of electricity rates is a top priority for his government, and he has pledged to keep rates near existing levels, but rate mitigation talks with Ottawa have dragged on since April.

A report by the province's Public Utilities Board released Friday forecast an "unprecedented" 75 per cent increase in average domestic rates for island residents in 2021, while Nova Scotia's regulator approved a 14% hike, and reported concerns from industrial customers about their ability to remain competitive.

Costs of the Muskrat Falls megadam on Labrador's Lower Churchill River have ballooned to more than $12.7 billion since the project was approved in 2012, according to the latest estimate of Crown corporation Nalcor Energy.

The dam is set to produce more power than the province can sell. Its existing financial structure would have left electricity ratepayers paying for Muskrat Falls to make up the difference starting in 2021, an issue both governments said Monday has been resolved with the relaunch of financing talks.

"Essentially, you won't pay this on your monthly light bills," Ball said.

But details of how the project will meet financing requirements in coming decades to make up the gap in funds are still to be worked out.

Both Ball and O'Regan criticized previous governments for sanctioning the poorly planned development and again pledged their commitment to easing the burden on residents.

"We promised we would be there to help, and we will be," O'Regan said before announcing a "relaunch" of negotiations around the project's financial structure.

He did not say how much the new setup might cost the federal government, despite earlier federal funding commitments, stressing that the new focus will be on the project's long-term sustainability. "There's no single piece of policy ... that can resolve such a large and complicated mess," O'Regan said.

The two governments also said they will work towards electrifying federal buildings to reduce an anticipated power surplus in the province.

In the short term, the federal government said it would allow for "flexibility" in upcoming cash requirements related to debt servicing, allowing deferral of payments if necessary.

Ball said that flexibility was built in to ensure the plan would still be applicable if costs continue to rise before Muskrat Falls is commissioned.

Political opponents criticized Monday's plan as lacking detail.

"What I heard talked about was an agreement that in the future, there's going to be an agreement," said Progressive Conservative Leader Ches Crosbie. "This was an occasion to reassure people that there's a plan in place to make life here affordable, and I didn't see that happen today."

Others addressed the lingering questions about the project's final cost.

Nalcor's latest financial update has remained unchanged since 2017, though the Muskrat Falls project has seen additional delays related to staffing and software issues.

Dennis Browne, the province's consumer advocate, said the switch to a cost of service model is a significant move that will benefit ratepayers, but he said it's impossible to truly restructure the project while it's a work in progress. "We need to know what the figures are, and we don't have them," he said.

 

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Major U.S. utilities spending more on electricity delivery, less on power production

U.S. Utility Spending Shift highlights rising transmission and distribution costs, grid modernization, and smart meters, while generation expenses decline amid fuel price volatility, capital and labor pressures, and renewable integration across the power sector.

 

Key Points

A decade-long trend where utilities spend more on delivery and grid upgrades, and less on electricity generation costs.

✅ Delivery O&M, wires, poles, and meters drive rising costs

✅ Generation spending declines amid fuel price changes and PPI

✅ Grid upgrades add reliability, resilience, and renewable integration

 

Over the past decade, major utilities in the United States have been spending more on delivering electricity to customers and less on producing that electricity, a shift occurring as electricity demand is flat across many regions.

After adjusting for inflation, major utilities spent 2.6 cents per kilowatthour (kWh) on electricity delivery in 2010, using 2020 dollars. In comparison, spending on delivery was 65% higher in 2020 at 4.3 cents/kWh, and residential bills rose in 2022 as inflation persisted. Conversely, utility spending on power production decreased from 6.8 cents/kWh in 2010 (using 2020 dollars) to 4.6 cents/kWh in 2020.

Utility spending on electricity delivery includes the money spent to build, operate, and maintain the electric wires, poles, towers, and meters that make up the transmission and distribution system. In real 2020 dollar terms, spending on electricity delivery increased every year from 1998 to 2020 as utilities worked to replace aging equipment, build transmission infrastructure to accommodate new wind and solar generation amid clean energy transition challenges that affect costs, and install new technologies such as smart meters to increase the efficiency, reliability, resilience, and security of the U.S. power grid.

Spending on power production includes the money spent to build, operate, fuel, and maintain power plants, as well as the cost to purchase power in cases where the utility either does not own generators or does not generate enough to fulfill customer demand. Spending on electricity production includes the cost of fuels including natural gas prices alongside capital, labor, and building materials, as well as the type of generators being built.

Other utility spending on electricity includes general and administrative expenses, general infrastructure such as office space, and spending on intangible goods such as licenses and franchise fees, even as electricity sales declined in recent years.

The retail price of electricity reflects the cost to produce and deliver power, the rate of return on investment that regulated utilities are allowed, and profits for unregulated power suppliers, and, as electricity prices at 41-year high have been reported, these components have drawn increased scrutiny.

In 2021, demand for consumer goods and the energy needed to produce them has been outpacing supply, though power demand sliding in 2023 with milder weather has also been noted. This difference has contributed to higher prices for fuels used by electric generators, especially natural gas. The increased cost for fuel, capital, labor, and building materials, as seen in the U.S. Bureau of Labor Statistics’ Producer Price Index, is increasing the cost of power production for 2021. U.S. average electricity prices have been higher every month of this year compared with 2020, according to our Monthly Electric Power Industry Report.

 

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