Wind power on smaller scale carries potential

By SanLuisObispo.com


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If Abigail Stutzman has anything to say about it, small wind turbines will someday dot backyards across the Midwest.

The fifth-grader at Starside Elementary School in De Soto, Kan., has an interest in the environment, including helping to recycle much of her family's trash. But she has bigger plans, inspired by her school's recent installation of a turbine.

"When I grow up, I want to live off the grid," she said.

Much of the attention given to wind energy is for large utility-scale wind farms full of huge, three-blade generators. That's where most wind power is likely to be generated.

But the idea of producing wind energy just for a home, business or small town continues to fire the imagination of those seeking self-sufficiency.

Small wind turbines have blades from 12 to 56 feet in diameter. One popular model for smaller homes has 12-foot blades, which can produce about 30 percent of the home's power.

Small-scale wind projects accounted for less than 1 percent of installed wind capacity in 2009. But the concept has plenty of supporters who believe small turbines can provide an important supplement to utility-provided electricity.

Small projects can face big obstacles, and progress has been much slower than many hoped. Initial costs can be daunting and take more than 15 years for a homeowner to recover.

Turbines need more maintenance than some other types of renewable energy, such as solar panels. And the trees and buildings in urban areas like Kansas City, Mo., mean that a standard-style turbine, to take full advantage of the wind, could need a tower more than 100 feet tall, increasing costs and possibly violating zoning laws.

The turbines also can be noisy, another strike against them in urban neighborhoods.

August Huber III, CEO of commercial building company A.L. Huber, said small turbines eventually would find their place. He has installed a wind turbine at his company's Overland Park, Kan., offices.

The turbine, which uses scoops instead of blades to gather the wind, is designed for slower wind speeds in urban areas and is quieter than a traditional small turbine.

Similarly, DST Realty, a major Kansas City real estate developer, is planning a demonstration project at 18th Street and Broadway that will have two turbines designed for urban areas. A traditional turbine has a horizontal generating axis, designed for stronger winds. But the DST project's turbines each will have a vertical axis.

As to how well they will work, DST Realty Vice President Steve Taylor said, "We'll see."

Prospects look brighter in more sparsely populated areas.

August Spencer and his wife, a retired couple who live in eastern Jackson County, Kan., bought a traditional small turbine more than a year ago. The Spencers had enough land to put their turbine on a 45-foot-tall tower, which should give the average eight- to 14-mile-an-hour winds needed to be efficient.

"It can be real good like today, when I'm receiving 20-mile winds," Spencer said recently.

That experience can be replicated, said the experts, if you want to make the investment and do your homework.

Susan Brown is manager of business development for the Energy Savings Store in Lenexa, Kan., which sells solar collectors and wind turbines. Brown, who once helped lead opposition to the coal-fired plant that KCP&L is now building near Weston, has a wind turbine at her home north of Platte City, Mo. She said the benefits go beyond the economic.

"Every kilowatt I'm producing, I'm not giving asthma to a child," she said.

But she discourages many with an initial interest in buying a wind turbine. Despite the Midwest's wind resources, a turbine can be a worse buy than a solar-energy system, depending on location and on tax credits and other incentives.

An installed 2.4-kilowatt wind system for an average residence can cost about $20,000 and supply about a third of the home's demand for electricity. Despite a 30 percent federal tax credit, Brown figures repaying the cost would take roughly 16 years.

That can make it competitive with a solar-energy system, which also qualifies for the federal tax credit. But solar gets the edge when Kansas City Power & Light's solar rebate is included. This can knock 20 to 25 percent more off the price. Check your city's utilities to see if they offer additional rebates.

"We usually don't recommend wind turbines for Kansas City," Brown said.

However, a growing number of schools are showing interest in turbines, although producing power often is a secondary reason. The Starside Elementary turbine in De Soto will recharge batteries and run an electric train, but its main purpose is teaching students about renewable energy. Students asked for the turbine and helped raise money for it.

"We worked long and hard for these things, and the kids are really proud of it," said Paula Henderson, a counselor at the school.

Kansas City Kansas Community College is slightly more ambitious, with a wind turbine that can produce about $100 worth of electricity in four days. It also is used to train students who want jobs repairing wind turbines.

The potential of small wind is clearer in places like Beloit, Kan., northwest of Salina, Kan., and in the heart of wind country. This is where All Things Exterior - which sells siding, roofing and windows - has invested in its own turbine.

By taking advantage of the brisk wind and the renewable-energy tax credits, along with depreciation rules that reduce the price for businesses, the company expects a payback in seven to eight years, said Troy Odle, the company's account manager.

All Things Exterior believes there is enough of a market for small turbines that it is planning to sell them.

"It's not because we want to be tree huggers, but it's the right thing for America," Odle said.

Small-town America, in fact, has had success with smaller wind projects.

Rock Port, Mo., and Greensburg, Kan., don't own turbines, but they do get electricity from wind-generation projects developed for them. The Greensburg project produces enough power for 4,000 homes.

The projects were developed or financed by John Deere Wind Energy, which had been a major developer of wind energy for small towns but recently announced it was getting out of the business. The John Deere subsidiary, which has offices in Johnston, Iowa, declined to reveal what was behind the decision.

Interested small towns could buy and operate wind turbines on their own. This has been done across the country, including once in Kansas with mixed results.

Jetmore, north of Dodge City in western Kansas, had $250,000 gathering little interest in a bank account and decided to buy two reconditioned turbines to provide some power to town residents.

They began operating last year, but after a few months the blades fell off one turbine, which more recently has had vibration problems. The company that sold the turbines is making repairs, but the town no longer expects a payback in seven to 10 years.

"We found out why no one else had done one of these," said Lea Ann Seiler, director of economic development for Jetmore. "But I still think it was worthwhile."

What could be the future is companies like BTI Wind Energy in Greensburg, the Kansas town that was destroyed by a tornado in 2007. The community is emphasizing the use of renewable energy as it rebuilds.

Brad Estes and his family had the town's John Deere dealership, and they decided to buy a wind turbine as they rebuilt. That experience led them to start BTI, which sells turbines and aims to help others get into wind energy.

BTI now extends into several states, offering help to homeowners, businesses and schools.

"In the wide open spaces of Kansas, we should be able to do this all day long," Estes said.

How small-scale wind energy stacks up in the Midwest:

- Strength: Consistently strong wind in many rural and semi-rural areas.

- Drawbacks: Buildings and trees make wind less efficient in urban areas. Wind systems can be relatively high maintenance. Connecting to the grid to sell back any excess power can be tricky.

- Cost considerations: A homeowner could need more than 15 years to recoup a system's initial costs. But a 30 percent federal tax credit helps, and depreciation provisions help businesses further. Stable institutions such as schools also can get long-term financing to spread out the costs.

- Short-term potential: Limited in cities, but alternate turbines designed for urban areas are being tested.

- Long-term potential: Better in rural areas.

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Duke Energy will spend US$25bn to modernise its US grid

Duke Energy Clean Energy Strategy targets smart grid upgrades, wind and solar expansion, efficient gas, and high-reliability nuclear, cutting CO2, boosting decarbonization, and advancing energy efficiency and reliability for the Carolinas.

 

Key Points

A plan investing in smart grids, renewables, gas, and nuclear to cut CO2 and enhance reliability and efficiency by 2030.

✅ US$25bn smart grid upgrades; US$11bn renewables and gas

✅ 40% CO2 reduction and >80% low-/zero-carbon generation by 2030

✅ 2017 nuclear fleet 95.64% capacity factor; ~90 TWh carbon-free

 

The US power group Duke Energy plans to invest US$25bn on grid modernization over the 2017-2026 period, including the implementation of smart grid technologies to cope with the development of renewable energies, along with US$11bn on the expansion of renewable (wind and solar) and gas-fired power generation capacities.

The company will modernize its fleet and expects more than 80% of its power generation mix to come from zero and lower CO2 emitting sources, aligning with nuclear and net-zero goals, by 2030. Its current strategy focuses on cutting down CO2 emissions by 40% by 2030. Duke Energy will also promote energy efficiency and expects cumulative energy savings - based on the expansion of existing programmes - to grow to 22 TWh by 2030, i.e. the equivalent to the annual usage of 1.8 million households.

#google#

Duke Energy’s 11 nuclear generating units posted strong operating performance in 2017, as U.S. nuclear costs hit a ten-year low, providing the Carolinas with nearly 90 billion kilowatt-hours of carbon-free electricity – enough to power more than 7 million homes.

Globally, China's nuclear program remains on a steady development track, underscoring broader industry momentum.

“Much of our 2017 success is due to our focus on safety and work efficiencies identified by our nuclear employees, along with ongoing emphasis on planning and executing refueling outages to increase our fleet’s availability for producing electricity,” said Preston Gillespie, Duke Energy chief nuclear officer.

Some of the nuclear fleet’s 2017 accomplishments include, as a new U.S. reactor comes online nationally:

  • The 11 units achieved a combined capacity factor of 95.64 percent, second only to the fleet’s 2016 record of 95.72 percent, marking the 19th consecutive year of attaining a 90-plus percent capacity factor (a measure of reliability).
  • The two units at Catawba Nuclear Station produced more than 19 billion kilowatt-hours of electricity, and the single unit at Harris Nuclear Plant generated more than 8 billion kilowatt-hours, both setting 12-month records.
  • Brunswick Nuclear Plant unit 2 achieved a record operating run.
  • Both McGuire Nuclear Station units completed their shortest refueling outages ever and unit 1 recorded its longest operating run.
  • Oconee Nuclear Station unit 2 achieved a fleet record operating run.

The Robinson Nuclear Plant team completed the station’s 30th refueling outage, which included a main generator stator replacement and other life-extension activities, well ahead of schedule.

“Our nuclear employees are committed to providing reliable, clean electricity every day for our Carolinas customers,” added Gillespie. “We are very proud of our team’s 2017 accomplishments and continue to look for additional opportunities to further enhance operations.”

 

 

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Cheaper electricity rate for customers on First Nations not allowed, Manitoba appeal court rules

Manitoba Hydro Court Ruling affirms the Public Utilities Board exceeded its jurisdiction by ordering a First Nations rate class, overturning an electricity rates appeal tied to geography, poverty, and regulatory authority in Manitoba.

 

Key Points

A decision holding the PUB lacked authority to create a First Nations rate class, restoring uniform electricity pricing.

✅ Court says PUB exceeded jurisdiction creating on-reserve rate

✅ Equalized electricity pricing reaffirmed across Manitoba

✅ Geography, not poverty, found decisive in unlawful rate class

 

Manitoba Hydro was wrongly forced to create a new rate class for electricity customers living on First Nations, the Manitoba Court of Appeal has ruled. 

The court decided the Public Utilities Board "exceeded its jurisdiction" by mandating Indigenous customers on First Nations could have a different electricity rate from other Manitobans. 

The board made the order in 2018, which exempted those customers from the general rate increase that year of 3.6 per cent.

"The directive constituted the creation and implementation of general social policy, an area outside of the PUB's jurisdiction and encroaching into areas that are better suited to the federal and provincial government," says the decision, which was released Tuesday.

Hydro's appeal of the PUB's decision went to court earlier this year.

At the time, the Crown corporation acknowledged many Indigenous people on First Nations live in poverty, but it argued the Public Utilities Board was overstepping its authority in trying to address the issue by creating a new rate class.

It also argued it was against provincial law to charge different rates in different areas of the province.

The PUB, however, insisted that legislation gives it the right to decide which factors are relevant when considering electricity prices, such as social issues. 

Special Manitoba Hydro rate class needed to offset challenges of living on First Nations, appeal court hears
Manitoba Hydro can appeal order to create special First Nation rate
The board had heard evidence that some customers were making "unacceptable" sacrifices to keep the lights on each month.

Decision 'heavy-handed': AMC
The Assembly of Manitoba Chiefs, an intervener in the appeal, had backed the utility board's position. It said on-reserve customers are disproportionately vulnerable to rate hikes over time.

Grand Chief Arlen Dumas said Wednesday he was surprised by the court's ruling. 

He argued Indigenous people are unduly excluded in the setting of electricity rates in Manitoba.

"I will be speaking with my federal and provincial counterparts on how we deal with this issue, because I think it's the wrong [decision]. It's heavy-handed and we need to address it."

The appeal court judges said there is past precedent for setting equal electricity rates, regardless of where customers live. Legislation to that effect was made in the early 2000s and a few years ago, the PUB recognized that geographical limitations should not be imposed on a class of customers.

Since the board's new order didn't extend the same savings to First Nations members who don't live on reserve but face similar financial circumstances, it is clear the deciding factor was geography, rather than poverty or treaty status, the judges said.

Manitoba Hydro temporarily cutting 200 jobs, many of them front-line workers
"In my view, the PUB erred in law when it created an on-reserve class based solely on a geographic region of the province in which customers are located," the decision read.

While Manitoba Hydro objected to the PUB's order in 2018, it still devoted money to create the new customer class.

Spokesperson Bruce Owen said the utility is still studying the impact of the court's decision, but it appreciates the ruling.  

"We all recognize that many people on First Nations have challenges, but our argument was solely on whether or not the PUB had the authority to create a special rate class based on where people live."

Owen added that Hydro recognizes electricity rates can be a hardship on individuals facing poverty. He said those considerations are part of the discussions the corporation has with the utilities board.

 

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The Evolution of Electric Vehicle Charging Infrastructure in the US

US EV Charging Infrastructure is evolving with interoperable NACS and CCS standards, Tesla Supercharger access, federal funding, ultra-fast charging, mobile apps, and battery advances that reduce range anxiety and expand reliable, nationwide fast-charging access.

 

Key Points

Nationwide network, standards, and funding enabling fast, interoperable EV charging access for drivers across the US.

✅ NACS and CCS interoperability expands cross-network access

✅ Tesla Superchargers opening to more brands accelerate adoption

✅ Federal funding builds fast chargers along highways and communities

 

The landscape of electric vehicle (EV) charging infrastructure in the United States is rapidly evolving, driven by technological advancements, collaborative efforts between automakers and charging networks across the country, and government initiatives to support sustainable transportation.

Interoperability and Collaboration

Recent developments highlight a shift towards interoperability among charging networks, even as control over charging continues to be contested across the market today. The introduction of the North American Charging Standard (NACS) and the adoption of the Combined Charging System (CCS) by major automakers underscore efforts to standardize charging protocols. This move aims to enhance convenience for EV drivers by allowing them to use multiple charging networks seamlessly.

Tesla's Role and Expansion

Tesla, a trailblazer in the EV industry, has expanded its Supercharger network to accommodate other EV brands. This initiative represents a significant step towards inclusivity, addressing range anxiety and supporting the broader adoption of electric vehicles. Tesla's expansive network of fast-charging stations across the US continues to play a pivotal role in shaping the EV charging landscape.

Government Support and Infrastructure Investment

The federal government's commitment to infrastructure development is crucial in advancing EV adoption. The Bipartisan Infrastructure Law allocates substantial funding for EV charging station deployment along highways and in underserved communities, while automakers plan 30,000 chargers to complement public investment today. These investments aim to expand access to charging infrastructure, promote economic growth, and reduce greenhouse gas emissions associated with transportation.

Technological Advancements and User Experience

Technological innovations in EV charging, including energy storage and mobile charging solutions, continue to improve user experience and efficiency. Ultra-fast charging capabilities, coupled with user-friendly interfaces and mobile apps, simplify the charging process for consumers. Advancements in battery technology also contribute to faster charging times and increased vehicle range, enhancing the practicality and appeal of electric vehicles.

Challenges and Future Outlook

Despite progress, challenges remain in scaling EV charging infrastructure to meet growing demand. Issues such as grid capacity constraints are coming into sharp focus, alongside permitting processes and funding barriers that necessitate continued collaboration between stakeholders. Addressing these challenges is crucial in supporting the transition to sustainable transportation and achieving national climate goals.

Conclusion

The evolution of EV charging infrastructure in the United States reflects a transformative shift towards sustainable mobility solutions. Through interoperability, government support, technological innovation, and industry collaboration, stakeholders are paving the way for a robust and accessible charging ecosystem. As investments and innovations continue to shape the landscape, and amid surging U.S. EV sales across 2024, the trajectory of EV infrastructure development promises to accelerate, ensuring reliable and widespread access to charging solutions that support a cleaner and greener future.

 

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Gaza’s sole electricity plant shuts down after running out of fuel

Gaza Power Plant Shutdown underscores the Gaza Strip's fuel ban, Israeli blockade, and electricity crisis, cutting megawatts, disrupting hospitals and quarantine centers, and exposing fragile energy supply, GEDCO warnings, and public health risks.

 

Key Points

An abrupt halt of Gaza's sole power plant due to a fuel ban, deepening the electricity crisis and straining hospitals.

✅ Israeli fuel ban halts Gaza's only power plant

✅ Available supply drops far below 500 MW demand

✅ Hospitals and COVID-19 quarantine centers at risk

 

The only electricity plant in the Gaza Strip shut down yesterday after running out of fuel banned from entering the besieged enclave by the Israeli occupation, Gaza Electricity Distribution Company announced.

“The power plant has shut down completely,” the company said in a brief statement, as disruptions like China power cuts reveal broader grid vulnerabilities.

Israel banned fuel imports into Gaza as part of punitive measures over the launching incendiary balloons from the Strip.

On Sunday, GEDCO warned that the industrial fuel for the electricity plant would run out, mirroring Lebanon's fuel shortage challenges, on Tuesday morning.

Since 2007, the Gaza Strip suffered under a crippling Israeli blockade that has deprived its roughly two million inhabitants of many vital commodities, including food, fuel and medicine, and regional strains such as Iraq's summer electricity needs highlight broader power insecurity.

As a result, the coastal enclave has been reeling from an electricity crisis, similar to when the National Grid warned of short supply in other contexts.

The Gaza Strip needs some 500 megawatts of electricity – of which only 180 megawatts are currently available – to meet the needs of its population, while Iran supplies about 40% of Iraq's electricity in the region.

Spokesman of the Ministry of Health in Gaza, Ashraf Al Qidra, said the lack of electricity undermines offering health services across Gaza’s hospitals.

He also warned that the lack of electricity would affect the quarantine centres used for coronavirus patients, reinforcing the need to keep electricity options open during the pandemic.

Gaza currently has three sources of electricity: Israel, which provides 120 megawatts and is advancing coal use reduction measures; Egypt, which supplies 32 megawatts; and the Strip’s sole power plant, which generates between 40 and 60 megawatts.

 

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Ontario Sets Electricity Rates at Off-Peak Price until February 7

Ontario Off-Peak Electricity Rate offers 8.2 cents per kWh for 24 hours, supporting Time-of-Use and Tiered Regulated Price Plan customers, including residential, small business, and farms, under Ontario Energy Board guidelines during temporary relief.

 

Key Points

A temporary 8.2 cents per kWh all-day price for RPP customers, covering TOU and Tiered users across Ontario.

✅ Applies 24 hours daily at 8.2 cents per kWh for 21 days

✅ Covers residential, small business, and farm RPP customers

✅ Valid for TOU and Tiered plans set by the Ontario Energy Board

 

 The Ontario government has announced electricity relief with electricity prices set at the off-peak price of 8.2 cents per kilowatt-hour, 24 hours per day for 21 days starting January 18, 2022, until the end of day February 7, 2022, for all Regulated Price Plan customers. The off-peak rate will apply automatically to residential, small businesses and farms who pay Time-of-Use or Tiered prices set by the Ontario Energy Board.

This rate relief includes extended off-peak rates to support small businesses, as well as workers and families spending more time at home while the province is in Modified Step Two of the Roadmap to Reopen.

As part of our mandate, we set the rates that your utility charges for the electricity you use in your home or small business. These rates appear on the Electricity line of your bill, and we administer protections such as disconnection moratoriums for residential customers. We also set the Delivery rates that cover the cost to deliver electricity to most residential and small business customers.

 

Types of electricity rates

For residential and small business customers that buy electricity from their utility, there are two different types of rates (also called prices here), and Ontario also provides stable electricity pricing for larger users. The Ontario Energy Board sets both once a year on November 1:

Time-of-Use (TOU)

With TOU prices, the price depends on when you use electricity, including options like ultra-low overnight pricing that encourage off-peak use.

There are three TOU price periods:

  • Off-peak, when demand for electricity is lowest and new offerings like the Ultra-Low Overnight plan can encourage shifting usage. Ontario households use most of their electricity – nearly two thirds of it – during off-peak hours.
  • Mid-peak, when demand for electricity is moderate. These periods are during the daytime, but not the busiest times of day, and utilities like BC Hydro are exploring similar TOU structures as well.
  • On-peak, when demand for electricity is generally higher. These are the busier times of day – generally when people are cooking, starting up their computers and running heaters or air conditioners.

 

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An NDP government would make hydro public again, end off-peak pricing, Horwath says in Sudbury

Ontario NDP Hydro Plan proposes ending time-of-use pricing, buying back Hydro One, lowering electricity rates, curbing rural delivery fees, and restoring public ownership to ease household bills amid debates with PCs and Liberals over costs.

 

Key Points

A plan to end time-of-use pricing, buy back Hydro One, and cut bills via public ownership and fair delivery fees.

✅ End time-of-use pricing; normal schedules without penalties

✅ Repurchase Hydro One; restore public ownership

✅ Cap rural delivery fees; address oversupply to cut rates

 

Ontario NDP leader Andrea Horwath says her party’s hydro plan will reduce families’ electricity bills, a theme also seen in Manitoba Hydro debates and the NDP is the only choice to get Hydro One back in public hands.

Howarth outlined the plan Saturday morning outside the home of a young family who say they struggle with their electricity bills — in particular over the extra laundry they now have after the birth of their twin boys.

An NDP government would end time-of-use pricing, which charges higher rates during peak times and lower rates after hours, “so that people aren’t punished for cooking dinner at dinner time,” Horwath said at a later campaign stop in Orillia, “so people can live normal lives and still afford their hydro bill.”

#google#

An NDP government would end time-of-use pricing, which gives lower rates for off-peak usage, Howarth said, separate from a recent subsidized hydro plan during COVID-19. The change would mean families wouldn't be "forced to wait until night when the pricing is lower to do laundry," and wouldn't have to rearrange their lives around chores.

The pricing scheme was supposed to lower prices and help smooth out demand for electricity, especially during peak times, but has failed, she said.

In order to lower hydro bills, Horwath said an NDP government would buy back shares of Hydro One sold off under the Wynne government, which she said has led to high prices and exorbitant executive pay among executives. The NDP plan would also make sure rural families do not pay more in delivery fees than city dwellers, and curb the oversupply of energy to bring prices down.

Critics have said the NDP plan is too costly and will take a long time to implement, and investors see too many unknowns about Hydro One.

"The NDP's plan to buy back Hydro One and continue moving forward with a carbon tax will cost taxpayers billions," said Melissa Lantsman, a spokesperson for PC Leader Doug Ford.

"Only Doug Ford has a plan to reduce hydro rates and put money back in people's pockets. We'll reduce your hydro bill by 12 per cent."

Ford has said he will fire Hydro One CEO Mayo Schmidt, and has dubbed him the $6-million-dollar man.

Horwath has said both Ford and Liberal Leader Kathleen Wynne will end up costing Ontarians more in electricity if one of them is elected come June 7. Their "hydro scheme is the wrong plan," she said.

 

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