CaliforniaÂ’s energy may be Wyoming-made

By Los Angeles Daily News


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Wyoming leaders say they're hopeful after visiting California that Wyoming coal can help supply the Golden State's energy needs.

Gov. Dave Freudenthal and the leaders of the state House and Senate flew to Los Angeles to meet with the California Public Utilities Commission and executives of two major utilities.

The delegation sought assurances that California would use electricity from power plants fueled by Wyoming coal, provided the plants meet California's carbon dioxide emissions standards.

"The bottom line is, if Wyoming electricity met California environmental standards, they would probably accept our electricity," said state Rep. Tom Lubnau, R-Gillette, who went on the trip.

California has strict standards for emissions of carbon dioxide, a gas blamed for contributing to global warming. Similar regulations have caused utilities to pull plans for dozens of coal-fired power plants nationwide.

The Wyoming delegation brought draft legislation for encouraging the underground storage of carbon dioxide emitted from Wyoming power plants.

Rob Hurless, Freudenthal's adviser on energy issues, compared the delegation's meeting with California Public Utility Chairman Michael Peevey, Southern California Edison CEO Al Fohrer and San Diego Gas and Electric CEO Debra Reed to visiting a foreign energy minister.

"I would say it's a discussion that is an important discussion and that's why we did it the way we did and took the people we did," he said.

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A new nuclear reactor in the U.S. starts up. It's the first in nearly seven years

Vogtle Unit 3 Initial Criticality marks the startup of a new U.S. nuclear reactor, initiating fission to produce heat, steam, and electricity, supporting clean energy goals, grid reliability, and carbon-free baseload power.

 

Key Points

Vogtle Unit 3 Initial Criticality is the first fission startup, launching power generation at a new U.S. reactor.

✅ First new U.S. reactor to reach criticality since 2016

✅ Generates carbon-free baseload power for the grid

✅ Faced cost overruns and delays during construction

 

For the first time in almost seven years, a new nuclear reactor has started up in the United States.

On Monday, Georgia Power announced that the Vogtle nuclear reactor Unit 3 has started a nuclear reaction inside the reactor as part of the first new reactors in decades now taking shape at the plant.

Technically, this is called “initial criticality.” It’s when the nuclear fission process starts splitting atoms and generating heat, Georgia Power said in a written announcement.

The heat generated in the nuclear reactor causes water to boil. The resulting steam spins a turbine that’s connected to a generator that creates electricity.

Vogtle’s Unit 3 reactor will be fully in service in May or June, Georgia Power said.

The last time a nuclear reactor reached the same milestone was almost seven years ago in May 2016 when the Tennessee Valley Authority started splitting atoms at the Watts Bar Unit 2 reactor in Tennessee, Scott Burnell, a spokesperson for the Nuclear Regulatory Commission, told CNBC.

“This is a truly exciting time as we prepare to bring online a new nuclear unit that will serve our state with clean and emission-free energy for the next 60 to 80 years,” Chris Womack, CEO of Georgia Power, said in a written statement. 

Including the newly turned-on Vogtle Unit 3 reactor, there are currently 93 nuclear reactors operating in the United States and, collectively, they generate 20% of the electricity in the country, although a South Carolina plant leak recently showed how outages can sideline a unit for weeks.

Nuclear reactors, which help combat global warming and support net-zero emissions goals, generate about half of the clean, carbon-free electricity generated in the U.S.

Most of the nuclear power reactors in the United States were constructed between 1970 and 1990, but construction slowed significantly after the accident at Three Mile Island near Middletown, Pennsylvania, on March 28, 1979, even as interest in next-gen nuclear power has grown in recent years. From 1979 through 1988, 67 nuclear reactor construction projects were canceled, according to the U.S. Energy Information Administration.

However, because nuclear energy is generated without releasing carbon dioxide emissions, which cause global warming, the increased sense of urgency in responding to climate change has given nuclear energy a chance at a renaissance as atomic energy heats up again globally.

The cost associated with building nuclear reactors is a major barrier to a potential resurgence in nuclear energy, however, even as nuclear generation costs have fallen to a ten-year low. And the new builds at Vogtle have become an epitome of that charge: The construction of the two Vogtle reactors has been plagued by cost overruns and delays.
 

 

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Federal Government announces funding for Manitoba-Saskatchewan power line

Birtle Transmission Line connects Manitoba Hydro to SaskPower, enabling 215 MW of clean hydroelectricity, improving grid reliability, supporting affordable rates, and advancing Green Infrastructure goals under the Investing in Canada Plan across Manitoba and Saskatchewan.

 

Key Points

A 46 km line moving up to 215 MW from Manitoba Hydro to SaskPower, improving reliability and supplying cleaner power.

✅ Enables interprovincial grid tie between Manitoba and Saskatchewan

✅ Delivers up to 215 MW of renewable hydroelectricity

✅ Supports affordable rates and lower GHG emissions

 

The federal government announced funding for the Birtle Transmission Line Monday morning.

The project will help Manitoba Hydro build a transmission line from Birtle South Station in the Municipality of Prairie View to the Manitoba–Saskatchewan border 46 kilometres northwest. Once completed, the new line will allow up to 215 megawatts of hydroelectricity to flow from the Manitoba Hydro power grid to the SaskPower power grid, similar to the Great Northern Transmission Line connecting Manitoba and Minnesota today.

The government said the transmission line would create a more stable energy supply, keep energy rates affordable and help Saskatchewan's efforts to reduce cumulative greenhouse-gas emissions in that province.

"The Government of Canada is proud to be working with Manitoba to support projects that create jobs and improve people's lives across the province. The Birtle Transmission Line will provide the region with reliable and greener energy, as seen with Canadian hydropower to New York projects, that will help protect our environment while laying the groundwork for clean economic growth," said Jim Carr, member of Parliament for Winnipeg South Centre, on behalf of Catherine McKenna, minister of infrastructure and communities.

The Government of Canada is investing more than $18.7 million, and the government of Manitoba is contributing more than $42 million in this project through the Green Infrastructure Stream of the Investing in Canada Plan, which also supports Atlantic grid improvements nationwide.

"The Province of Manitoba has one of the cleanest electricity grids in Canada and the world with over 99 per cent of our electricity generated from clean, renewable sources, rooted in Manitoba's hydro history," said Central Services Minister Reg Helwer. "The Made-in-Manitoba Climate and Green Plan is good not only for Manitoba but for Canada and globally."

Jay Grewal, president, and CEO of Manitoba Hydro said the funding is a great example of co-operation between the provincial and federal governments, including investments in smart grid technology that modernize local networks.

"We are very pleased that Manitoba Hydro's Birtle Transmission Project is among the first projects to receive funding under the Canada Infrastructure Program, and we would like to thank both levels of governments for recognizing the importance of the project as we strengthen ties with our neighbours in Saskatchewan, as U.S.-Canada transmission approvals advance elsewhere," said Grewal.

A spokesperson for Manitoba Hydro said it’s too early to say how many jobs will be created during construction, as final contracts have not yet been awarded.

 

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Energy-insecure households in the U.S. pay 27% more for electricity than others

Community Solar for Low-Income Homes expands energy equity by delivering renewable energy access, predictable bill savings, and tax credit benefits to renters and energy-insecure households, accelerating distributed generation and storage adoption nationwide.

 

Key Points

A program model enabling renters and LMI households to subscribe to off-site solar and save on utility bills.

✅ Earn bill credits from shared solar generation.

✅ Expands access for renters and LMI subscribers.

✅ Often paired with storage and IRA tax credit adders.

 

On a square-foot basis, the issue of inequality is made worse by higher costs for energy usage in the nation. Efforts like community solar programs such as Maryland community solar are underway to boost low-income participation in the cost benefits of renewable energy.

The Energy Information Administration (EIA) shows that households that are considered energy insecure, or those that have the inability to adequately meet basic household energy costs, are paying more for electricity than their wealthier counterparts. 

On average in the United States in 2020, households were billed about $1.04 per square foot for all energy sources. For homes that did not report energy insecurity, that average was $0.98 per square foot, while homes with energy insecurity issues paid an average of $1.24 per square foot for energy. This means that U.S. residents that need the most support on their energy bills are stuck with costs 27% higher than their neighbors on square-foot-basis.

EIA said energy-insecure households have reduced or forgone basic necessities to pay energy bills, kept their houses at unsafe temperatures because of energy cost concerns, or been unable to repair heating or cooling equipment because of cost.

In 2020, households with income less than $10,000 a year were billed an average of $1.31 per square foot for energy, while households making $100,000 or more were billed an average of $0.96 per square foot, said EIA. Renters paid considerably more ($1.28 per square foot) than owners ($0.98 per square foot). There were also considerable differences between regions, with New England solar growth sparking grid upgrade debates, ethnic groups and races, and insulation levels, as seen below.

The energy transition toward renewables like solar has offered price stability, amid record solar and storage growth nationwide, but thus far energy-insecure communities have relatively been left behind. A recent Berkeley Lab report, Residential Solar-Adopter Income and Demographic Trends, indicates that even though the rate of solar adoption among low-income residents is increasing (from 5% in 2010 to 11% in 2021), that segment of energy consumers remains under-represented among solar adopters, relative to its share of the population.


Community solar efforts

As such, the United States is targeting communities most impacted by energy costs that have not benefitted from the transition, highlighting “Energy Communities” that are eligible for an additional 10% tax credit through funds made possible by the Inflation Reduction Act.

Additionally, a push for community solar development is taking place nationwide to extend access to affordable solar energy to renters and other residents that aren’t able to leverage finances to invest in predictable, low-cost residential solar systems. The Biden Administration set a goal this year to sign up 5 million community solar households, achieving $1 billion in bill savings by 2025. The community solar model only represents about 8% of the total distributed solar capacity in the nation. This target would entail a jump from 3 GW installed capacity to 20 GW by the target year. The Department of Energy estimates community solar subscribers save an average of 20% on their bills.

California this year passed AB 2316, the Community Renewable Energy Act takes aim at four acute problems in the state’s power market: reliability amid rising outage risks, rates, climate and equity. The law creates a community renewable energy program, including community solar-plus-storage, supported by cheaper batteries, to overcome access barriers for nearly half of Californians who rent or have low incomes. Community solar typically involves customers subscribing to an off-site solar facility, receiving a utility bill credit for the power it generates.

“Community renewable energy is a proven powerful tool to help close California’s clean energy gap, bringing much needed relief to millions struggling with high housing costs and utility debt,” said Alexis Sutterman, energy equity program manager at the California Environmental Justice Alliance.

The program has energy equity baked into its structure, working to make sure Californians of all income levels participate in the benefits of the energy transition. Not only does it open solar access to renters, the law ensures that at least 51% of subscribers are low-income customers, which is expected to make projects eligible for a 10% tax credit adder under the IRA.

“The money’s on the table now,” said Jeff Cramer, president and chief executive of the Coalition for Community Solar Access. “While there are groups pushing for solar access for all, and states with strong legislation, there are other pockets of interest in surprising places in the United States. For example, Louisiana has no policy for community solar or support for low-income residents going solar but the city of New Orleans has its own utility commission with a community solar program. In Nebraska, forward-looking co-operatives have created community solar projects.

Community solar markets are active in 22 states, with more expected to come online in the future as states pursue 100% clean energy targets across the country. However, the market is expected to require strong community outreach efforts to foster trust and gain subscribers.

“There is a distrust of community solar initially in LMI communities as many have been burned before by retail energy false promises,” said Eric LaMora, executive director, community solar, Nautilus Solar on a panel at the Solar Energy Industries Association Finance, Tax, and Buyers seminar. “People are suspicious but there really are no hooks with community solar.”

LMI residents are leery to provide tax records or much documents at all in order to sign up for community solar, LaMora said. “We were surprised to see less of a default rate with LMI residents. We attribute this to the fact that they see significant savings on their electric bill, making it easier to pay each month,” he said.

 

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Powering Towards Net Zero: The UK Grid's Transformation Challenge

UK Electricity Grid Investment underpins net zero, reinforcing transmission and distribution networks to integrate wind, solar, EV charging, and heat pumps, while Ofgem balances investor returns, debt risks, price controls, resilience, and consumer bills.

 

Key Points

Capital to reinforce grids for net zero, integrating wind, solar, EVs and heat pumps while balancing returns and bills.

✅ 170bn-210bn GBP by 2050 to reinforce cables, pylons, capacity.

✅ Ofgem to add investability metric while protecting consumers.

✅ Integrates wind, solar, EVs, heat pumps; manages grid resilience.

 

Prime Minister Sunak's recent upgrade to his home's electricity grid, designed to power his heated swimming pool, serves as a microcosm of a much larger challenge facing the UK: transforming the nation's entire electricity network for net zero emissions, amid Europe's electrification push across the continent.

This transition requires a monumental £170bn-£210bn investment by 2050, earmarked for reinforcing and expanding onshore cables and pylons that deliver electricity from power stations to homes and businesses. This overhaul is crucial to accommodate the planned switch from fossil fuels to clean energy sources - wind and solar farms - powering homes with electric cars, as EV demand on the grid rises, and heat pumps.

The UK government's Climate Change Committee warns of potentially doubled electricity demand by 2050, the target date for net zero, even though managing EV charging can ease local peaks. This translates to a significant financial burden for companies like National Grid, SSE, and Scottish Power who own the main transmission networks and some regional distribution networks.

Balancing investor needs for returns and ensuring affordable energy bills for consumers presents a delicate tightrope act for regulators like Ofgem. The National Audit Office criticized Ofgem in 2020 for allowing network owners excessive returns, prompting concerns about potential bill hikes, especially after lessons from 2021 reshaped market dynamics.

Think-tank Common Wealth reported that distribution networks paid out a staggering £3.6bn to their owners between 2017 and 2021, raising questions about the balance between profitability and affordability, amid UK EV affordability concerns among consumers.

However, Ofgem acknowledges the need for substantial investment to finance network upgrades, repairs, and the clean energy transition. To this end, they are considering incorporating an "investability" metric, recognizing how big battery rule changes can erode confidence elsewhere, in the next price controls for transmission networks, ensuring these entities remain attractive for equity fundraising without overburdening consumers.

This proposal, while welcomed by the industry, has drawn criticism from consumer advocacy groups like Citizens Advice, who fear it could contribute to unfairly high bills. With energy bills already hitting record highs, public trust in the net-zero transition hinges on ensuring affordability.

High debt levels and potential credit rating downgrades further complicate the picture, potentially impacting companies' ability to raise investment funds. Ofgem is exploring measures to address this, such as stricter debt structure reporting requirements for regional distribution companies.

Lawrence Slade, CEO of the Energy Networks Association, emphasizes the critical role of investment in achieving net zero. He highlights the need for "bold" policies and regulations that balance ambitious goals with investor confidence and ensure efficient resource allocation, drawing on B.C.'s power supply challenges as a cautionary example.

The challenge lies in striking a delicate balance between attracting investment, ensuring network resilience, and maintaining affordable energy bills. As Andy Manning from Citizens Advice warns, "Without public confidence, net zero won't be delivered."

The UK's journey to net zero hinges on navigating this complex landscape. By carefully calibrating regulations, fostering investor confidence, and prioritizing affordability, the country can ensure its electricity grid is not just robust enough to power heated swimming pools, but also a thriving green economy for all.

 

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Alberta Faces Challenges with Solar Energy Expansion

Alberta Solar Energy Expansion confronts high installation costs, grid integration and storage needs, and environmental impact, while incentives, infrastructure upgrades, and renewable targets aim to balance reliability, land use, and emissions reductions provincewide.

 

Key Points

Alberta Solar Energy Expansion is growth in solar tempered by costs, grid limits, environmental impact, and incentives.

✅ High capex and financing challenge utility-scale projects

✅ Grid integration needs storage, transmission, and flexibility

✅ Site selection must mitigate land and wildlife impacts

 

Alberta's push towards expanding solar power is encountering significant financial and environmental hurdles. The province's ambitious plans to boost solar power generation have been met with both enthusiasm and skepticism as stakeholders grapple with the complexities of integrating large-scale solar projects into the existing energy framework.

The Alberta government has been actively promoting solar energy as part of its strategy to diversify the energy mix in a province that is a powerhouse for both green energy and fossil fuels today and reduce greenhouse gas emissions. Recent developments have highlighted the potential of solar power to contribute to Alberta's clean energy goals. However, the path forward is fraught with challenges related to costs, environmental impact, and infrastructure needs.

One of the primary issues facing the solar energy sector in Alberta is the high cost of solar installations. Despite decreasing costs for solar technology in recent years, the upfront investment required for large-scale solar farms remains substantial, even as some facilities have been contracted at lower cost than natural gas in Alberta today. This financial barrier has led to concerns about the economic viability of solar projects and their ability to compete with other forms of energy, such as natural gas and oil, which have traditionally dominated Alberta's energy landscape.

Additionally, there are environmental concerns associated with the development of solar farms. While solar energy is considered a clean and renewable resource, the construction of large solar installations can have environmental implications. These include potential impacts on local wildlife habitats, land use changes, where approaches like agrivoltaics can co-locate farming and solar, and the ecological effects of large-scale land clearing. As solar projects expand, balancing the benefits of renewable energy with the need to protect natural ecosystems becomes increasingly important.

Another significant challenge is the integration of solar power into Alberta's existing energy grid. Solar energy production is variable and dependent on weather conditions, especially with Alberta's limited hydro capacity for flexibility, which can create difficulties in maintaining a stable and reliable energy supply. The need for infrastructure upgrades and energy storage solutions is crucial to address these challenges and ensure that solar power can be effectively utilized alongside other energy sources.

Despite these challenges, the Alberta government remains committed to advancing solar energy as a key component of its renewable energy strategy. Recent initiatives include financial incentives and support programs aimed at encouraging investment in solar projects and supporting a renewable energy surge that could power thousands of jobs across Alberta today. These measures are designed to help offset the high costs associated with solar installations and make the technology more accessible to businesses and homeowners alike.

Local communities and businesses are also playing a role in the growth of solar energy in Alberta. Many are exploring opportunities to invest in solar power as a means of reducing energy costs and supporting sustainability efforts and, increasingly, to sell renewable energy into the market as demand grows. These smaller-scale projects contribute to the overall expansion of solar energy and demonstrate the potential for widespread adoption across the province.

The Alberta government has also been working to address the environmental concerns associated with solar energy development. Efforts are underway to implement best practices for minimizing environmental impacts and ensuring that solar projects are developed in an environmentally responsible manner. This includes conducting environmental assessments and working with stakeholders to address potential issues before projects are approved and built.

In summary, while Alberta's solar energy initiatives hold promise for advancing the province's clean energy goals, they are also met with significant financial and environmental challenges. Addressing these issues will be crucial to the successful expansion of solar power in Alberta. The government's ongoing efforts to support solar projects through incentives and infrastructure improvements, coupled with responsible environmental practices, will play a key role in determining the future of solar energy in the province.

 

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New York State to investigate sites for offshore wind projects

NYSERDA Offshore Wind Data initiative funds geophysical and geotechnical surveys, seabed and soil studies on New York's shelf to accelerate siting, optimize foundation design, reduce costs, and advance clean energy deployment.

 

Key Points

State funding to support surveys and soil studies guiding offshore wind siting, design, and cost reduction.

✅ Up to $5.5M for geophysical and geotechnical data collection

✅ Focus on seabed soils, shelf geology, and foundation design inputs

✅ Accelerates siting, reduces risk, and lowers offshore wind costs

 

The New York State Energy Research and Development Authority (NYSERDA) is investing up to $5.5 million for the collection of geophysical and geotechnical data to determine future offshore wind development sites.

The funding is to look at seabed soil and geological data for the preliminary design and installation requirements for future offshore wind projects. Its part of N.Y. Gov. Andrew Cuomos plan to develop 9,000 megawatts of offshore wind energy by 2035.

Todays announcement is another step in Governor Cuomos steadfast march to achieving 9,000 megawatts of offshore wind by 2035, putting New York in a clear national leadership position when it comes to advancing this new industry through large-scale energy projects across the state. The surveys NYSERDA will be funding under this solicitation will expand the offshore wind industrys access to geophysical and geotechnical data that will provide the foundation for future offshore wind development in these areas, and accelerate project development while driving down costs, NYSERDA President and CEO Alicia Barton said.

NYSERDA will select one or more contractors to do the investigations, while recent DOE wind energy awards support complementary research, and develop a model for describing geophysical and geotechnical conditions. NYSERDA will also select a contractor to support project management and host the data that is collected. The submission deadline is Jan. 21, 2020.

Todays announcement builds on the data collected in a Geotechnical and Geophysical Desktop Study also released today, which includes information on the middle continental shelf off the shore of New York and New Jersey, where BOEM lease requests are shaping activity, creating a regional overview of the seafloor and sub-seafloor environment as it relates to offshore wind development.

Strong knowledge of environmental conditions and factors, including seabed soil conditions, are essential for the installation of offshore projects, such as Long Island proposals, but only a limited amount of soil sampling and testing has been undertaken to date.

The collection of geophysical and geotechnical data from areas off of New Yorks Atlantic coast is yet another demonstration of New Yorks leadership promoting the responsible development of offshore wind. The data generated by this initiative will ultimately lead to better projects, lower cost, and enhanced safety. New York is leading the way to a clean energy future, as the state finalizes renewable project contracts that expand capacity, and relying on data collection and sound science to get us there, New York Offshore Wind Alliance Director Joe Martens said.

 

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