Wind power on smaller scale carries potential

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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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Hydro One crews restore power to more than 277,000 customers following damaging storms in Ontario

Hydro One Power Restoration showcases outage recovery after a severe windstorm, with crews repairing downed power lines, broken poles and crossarms, partnering with utilities and contractors to boost grid resilience and promote emergency kit preparedness.

 

Key Points

A coordinated response by Hydro One and partners to repair storm damage, restore outages, strengthen grid resilience.

✅ Crews repaired downed lines, broken poles, and crossarms

✅ Partners and contractors aided rapid outage restoration

✅ Investments improve grid resilience and emergency readiness

 

Hydro One crews have restored power to more than 277,000 customers following back-to-back storms, with impacts felt in communities like Sudbury where local crews worked to reconnect service, including a damaging windstorm on that caused 57 broken poles, 27 broken crossarms, as well as downed power lines and fallen trees on lines. Hydro One crews restored power to more than 140,000 customers within 24 hours of Friday's windstorm, even as Toronto outages persisted for some customers elsewhere.

'We understand power outages bring life to a halt, which is why we are continuously improving our storm response, as employee COVID-19 support demonstrated, while making smart investments in a resilient, reliable and sustainable electricity system to energize life for families, businesses and communities for years to come,' said David Lebeter, Chief Operating Officer, Hydro One. 'We thank our customers for their patience as our crews worked tirelessly, alongside our utility partners and contractors, including Ontario crews in Florida, to restore power as quickly and as safely as possible.'

Hydro One thanks all of its utility partners and contractors who assisted with restoration efforts following the windstorm (alongside similar Quebec outages that highlighted the broader impact), including Durham High Voltage, EPCOR, ERTH Power, K-Line Construction Ltd., Lakeland Power Distribution Ltd., North Bay Hydro, Sproule Powerline Construction Ltd. and Valard Construction.

Hydro One encourages customers to restock their emergency kits following these storms, which utilities such as BC Hydro have also characterized as atypical, and to be aware of support programs like our pandemic relief fund that can help during difficult periods, to ensure they're prepared for an emergency or extended power outage.

 

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Ontario Breaks Ground on First Small Modular Nuclear Reactor

Ontario SMR BWRX-300 leads Canada in next-gen nuclear energy at Darlington, with GE Vernova and Hitachi, delivering clean, reliable power via modular design, passive safety, scalability, and lower costs for grid integration.

 

Key Points

Ontario SMR BWRX-300 is a 300 MW modular boiling water reactor at Darlington with passive safety and clean power.

✅ 300 MW BWR supplies power for about 300,000 homes

✅ Passive safety enables safe shutdown without external power

✅ Modular design reduces costs and speeds grid integration

 

Ontario has initiated the construction of Canada's first small modular nuclear reactor (SMR), supported by OPG's SMR commitment to deployment, marking a significant milestone in the province's energy strategy. This development positions Ontario at the forefront of next-generation nuclear technology within the G7 nations.

The project, known as the Darlington New Nuclear Project, is being led by Ontario Power Generation (OPG) in collaboration with GE Vernova and Hitachi Nuclear Energy, and through its OPG-TVA partnership on new nuclear technology development. The chosen design is the BWRX-300, a 300-megawatt boiling water reactor that is approximately one-tenth the size and complexity of traditional nuclear reactors. The first unit is expected to be operational by 2029, with plans for additional units to follow.

Each BWRX-300 reactor is projected to supply electricity to about 300,000 homes, contributing to Ontario's efforts, which include the decision to refurbish Pickering B for additional baseload capacity, to meet the anticipated 75% increase in electricity demand by 2050. The compact design of the SMR allows for easier integration into existing infrastructure, reducing the need for extensive new transmission lines.

The economic impact of the project is substantial. The construction of four such reactors is expected to create up to 18,000 jobs and contribute approximately $38.5 billion CAD to the Canadian economy, reflecting the economic benefits of nuclear projects over 65 years. The modular nature of SMRs also allows for scalability, with each additional unit potentially reducing costs through economies of scale.

Safety is a paramount consideration in the design of the BWRX-300. The reactor employs passive safety features, meaning it can safely shut down without the need for external power or operator intervention. This design enhances the reactor's resilience to potential emergencies, aligning with stringent regulatory standards.

Ontario's commitment to nuclear energy is further demonstrated by its plans for four SMRs at the Darlington site. This initiative reflects a broader strategy to diversify the province's energy mix, incorporating clean and reliable power sources to complement renewable energy efforts.

While the development of SMRs in Ontario is a significant step forward, it also aligns with the Canadian nuclear initiative positioning Canada as a leader in the global nuclear energy landscape. The successful implementation of the BWRX-300 could serve as a model for other nations exploring advanced nuclear technologies.

Ontario's groundbreaking work on small modular nuclear reactors represents a forward-thinking approach to energy generation. By embracing innovative technologies, the province is not only addressing future energy demands but also, through the Pickering NGS life extension, contributing to the global transition towards sustainable and secure energy solutions.

 

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Severe heat: 5 electricity blackout risks facing the entire U.S., not just Texas

Texas power grid highlights ERCOT reliability strains from extreme heat, climate change, and low wind, as natural gas and renewables balance tight capacity amid EV charging growth, heat pumps, and blackout risk across the U.S.

 

Key Points

Texas power grid is ERCOT-run and isolated, balancing natural gas and wind amid extreme weather and electrification.

✅ Isolated from other U.S. grids, limited import support

✅ Vulnerable to extreme heat, winter storms, low wind

✅ Demand growth from EVs and heat pumps stresses capacity

 

Texas has a unique state-run power grid facing a Texas grid crisis that has raised concerns, but its issues with extreme weather, and balancing natural gas and wind, hold lessons for an entire U.S. at risk for power outages from climate change.

Grid operator the Electric Reliability Council of Texas, or ERCOT, which has drawn criticism from Elon Musk recently, called on consumers to voluntarily reduce power use on Monday when dangerous heat gripped America’s second-most populous state.

The action paid off as the Texas grid avoided blackouts — and a repeat of its winter crisis — despite record or near-record temperatures that depleted electric supplies amid a broader supply-chain crisis affecting utilities this summer, and risked lost power to more than 26 million customers. ERCOT later on Monday lifted the call for conservation.

For sure, it’s a unique situation, as the state-run power grid system runs outside the main U.S. grids. Still, all Americans can learn from Texas about the fragility of a national power grid that is expected to be challenged more frequently by hot and cold weather extremes brought on by climate change, including potential reliability improvements policymakers are weighing.

The grid will also be tested by increased demand to power electric vehicles (EVs) and conversions to electric heat pumps — all as part of a transition to a “greener” future.

 

Why is Texas different?
ERCOT, the main, but not only, Texas grid, is unique in its state-run, and not regional, format used by the rest of the country. Because it’s an energy-rich state, Texas has been able to set power prices below those seen in other parts of the country, and its independence gives it more pricing authority, while lawmakers consider market reforms to avoid blackouts. But during unusual strain on the system, such as more people blasting their air conditioners longer to combat a record heat wave, it also has no where else to turn.

A lethal winter power shortage in February 2021, during a Texas winter storm that left many without power and water, notoriously put the state and its independent utility in the spotlight when ERCOT failed to keep residents warm and pipes from bursting. Texas’s 2021 outage left more than 200 people dead and rang up $20 billion in damage. Fossil-fuel CL00, 0.80% backers pointed to the rising use of intermittent wind power, which generates 23% of Texas’s electricity. Others said natural-gas equipment was frozen under the extreme conditions.

This week, ERCOT is asking for voluntary conservation between 2 p.m. and 8 p.m. local time daily due to record high electricity demand from the projected heat wave, and also because of low wind. ERCOT said current projections show wind generation coming in at less than 10% of capacity. ERCOT stressed that no systemwide outages are expected, and Gov. Greg Abbott has touted grid readiness heading into fall, but it was acting preemptively.

A report late last year from the North American Electric Reliability Corp. (NERC) said the Texas system without upgrades could see a power shortfall of 37% in extreme winter conditions. NERC’s outlook suggested the state and ERCOT isn’t prepared for a repeat of weather extremes.

 

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Balancing Act: Germany's Power Sector Navigates Energy Transition

Germany January Power Mix shows gas-fired generation rising, coal steady, and nuclear phaseout impacts, amid cold weather, energy prices, industrial demand, and emissions targets shaping renewables, grid stability, and security of supply.

 

Key Points

The January electricity mix, highlighting gas, coal, renewables, and nuclear exit effects on emissions, prices, and demand.

✅ Gas output up 13% to 8.74 TWh, share at 18.6%.

✅ Coal share 23%, down year on year, steady vs late 2023.

✅ Nuclear gap filled by gas and coal; emissions below Jan 2023.

 

Germany's electricity generation in January presented a fascinating snapshot of its energy transition journey. As the country strives to move away from fossil fuels, with renewables overtaking coal and nuclear in its power mix, it grapples with the realities of replacing nuclear power and meeting fluctuating energy demands.

Gas Takes the Lead:

Gas-fired power plants saw their highest output in two years, generating 8.74 terawatt hours (TWh). This 13% increase compared to January 2023 compensated for the closure of nuclear reactors, which were extended during the energy crisis to shore up supply, and colder weather driving up heating needs. This reliance on gas, however, pushed its share in the electricity mix to 18.6%, highlighting Germany's continued dependence on fossil fuels.

Coal Fades, but Not Forgotten:

While gas surged, coal-fired generation remained below previous levels, dropping 29% from January 2023. However, it stayed relatively flat compared to late 2023, suggesting utilities haven't entirely eliminated it. Coal still held a 23% share, and periodic coal reliance remains evident, exceeding gas' contribution, reflecting its role as a reliable backup for intermittent renewable sources like wind.

Nuclear Void and its Fallout:

The shutdown of nuclear plants in April 2023 created a significant gap, previously accounting for an average of 12% of annual electricity output. This loss is being compensated through gas and coal, with gas currently the preferred choice, even as a nuclear option debate persists among policymakers. This strategy kept January's power sector emissions lower than the previous year, but rising demand could shift the balance.

Industry's Uncertain Impact:

Germany's industrial sector, a major energy consumer, is facing challenges like high energy prices and weak consumer demand. While the government aims to foster industrial recovery, uncertainties linger due to a shaky coalition and limited budget, and debate about a possible nuclear resurgence continues in parallel, which could reshape policy. Any future industrial revival would likely increase energy demand and potentially necessitate more gas or coal.

Cost-Driven Choices and Emission Concerns:

The choice between gas and coal depends on their relative costs, in a system pursuing a coal and nuclear phase-out under long-term policy. Currently, gas seems more favorable emission-wise, but if its price rises, coal might become more attractive, impacting overall emissions.

Looking Ahead:

Germany's energy transition faces a complex balancing act, with persistent grid expansion woes and exposure to cheap gas complicating progress. While the reliance on gas and coal highlights the difficulties in replacing nuclear, the focus on emissions reduction is encouraging. Navigating the challenges of affordability, industrial needs, and climate goals will be crucial for a successful transition to a clean and secure energy future.

 

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TransAlta Poised to Finalize Alberta Data Centre Agreement in 2025 

TransAlta Alberta Data Centre integrates AI, cloud computing, and renewable energy, tackling electricity demand, grid capacity, decarbonization, and energy storage with clean power, cooling efficiency, and PPA-backed supply for hyperscale workloads.

 

Key Points

TransAlta Alberta Data Centre is a planned AI facility powered mostly by renewables to meet high electricity demand.

✅ Targets partner exclusivity mid-year; ops 18-24 months post-contract.

✅ Supplies ~90% power via TransAlta; balance from market.

✅ Anchors $3.5B clean energy growth and storage in Alberta.

 

TransAlta Corp., one of Alberta’s leading power producers, is moving toward finalizing agreements with partners to establish a data centre in the province, aligned with AI data center grid integration efforts nationally, aiming to have definitive contracts signed before the end of the year.

CEO John Kousinioris stated during an analyst conference that the company seeks to secure exclusivity with key partners by mid-year, with detailed design plans and final agreements expected by late 2025. Once the contracts are signed, the data centre is anticipated to be operational within 18 to 24 months, a horizon mirrored by Medicine Hat AI grid upgrades initiatives that aim to modernize local systems.

Data centres, which are critical for high-tech industries such as artificial intelligence, consume large amounts of electricity to run and cool servers, a trend reflected in U.S. utility power challenges reporting, underscoring the scale of energy demand. In this context, TransAlta plans to supply around 90% of its partner's energy needs for the facility, with the remainder coming from the broader electricity market.

Alberta has identified data centres as a strategic priority, aiming to see $100 billion in AI-related data centre construction over the next five years. However, the rapid growth of this sector presents challenges for the region’s energy infrastructure. Electricity demand from data centres has already outpaced the available capacity in Alberta’s power grid, intensifying discussions about a western Canadian electricity grid to improve regional reliability, potentially impacting the province’s decarbonization goals.

To address these challenges, TransAlta has adopted a renewable energy investment strategy. The company announced a $3.5 billion growth plan focused primarily on clean electricity generation and storage, as British Columbia's clean energy shift advances across the region, through 2028. By then, more than two-thirds of TransAlta’s earnings are expected to come from renewable power generation, supporting progress toward a net-zero electricity grid by 2050 nationally.

The collaboration between TransAlta and data centre developers represents an opportunity to balance growing energy demand with sustainability goals. By integrating renewable energy generation into data centre operations and broader macrogrid investments, Alberta could move toward a cleaner and more resilient energy future.

 

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Spain plans switch to 100% renewable electricity by 2050

Spain 2050 Renewable Energy Plan drives decarbonisation with wind and solar, energy efficiency, fossil fuel bans, and Paris Agreement targets, enabling net-zero power, emissions cuts, and just transition measures for workers and coal regions.

 

Key Points

A roadmap to 100 percent renewable power by 2050, deep emissions cuts, and a just transition aligned with Paris goals.

✅ Adds 3,000 MW of wind and solar each year through 2030

✅ Bans new fossil fuel drilling, hydrocarbon extraction, and fracking

✅ Targets 35% energy efficiency gains and 35% green power by 2030

 

Spain has launched an ambitious plan to switch its electricity system entirely to renewable sources, similar to California's 100% clean electricity mandate, by 2050 and completely decarbonise its economy soon after.

By mid-century, as EU electricity demand projections suggest increases, greenhouse gas emissions would be slashed by 90% from 1990 levels under Spain’s draft climate change and energy transition law.

To do this, the country’s social democratic government is committing to installing at least 3,000MW of wind and solar power capacity every year in the next 10 years ahead.

New licences for fossil fuel drills, hydrocarbon exploitation and fracking wells, will be banned, and a fifth of the state budget will be reserved for measures that can mitigate climate change. This money will ratchet upwards from 2025.

Christiana Figueres, a former executive secretary of the UN’s framework convention on climate change (UNFCCC), hailed the draft Spanish law as “an excellent example of the Paris agreement”. She added: “It sets a long-term goal, provides incentives on scaling up emissions technologies and cares about a good transition for the workforce.”

Under the plan, “just transition” contracts will be drawn up, similar to the £220m package announced in October, that will shut most Spanish coalmines in return for a suite of early retirement schemes, re-skilling in clean energy jobs, and environmental restoration. These deals will be partly financed by auction returns from the sale of emissions rights.

The government has already scrapped a controversial “sun tax” that halted Spain’s booming renewables sector earlier this decade, even as IEA analysis finds solar the cheapest electricity worldwide, and the new law will also mandate a 35% electricity share for green energy by 2030.

James Watson, chief executive of the SolarPower Europe trade association, said the law was “a wake-up call to the rest of the world” amid debate on the global energy transition today.

Energy efficiency will also be improved by 35% within 11 years, and government and public sector authorities will be able to lease only buildings that have almost zero energy consumption.

Laurence Tubiana, chief executive of the European Climate Foundation, and former French climate envoy who helped draft the Paris accord, described the agreement as groundbreaking and inspirational. “By planning on going carbon neutral, Spain shows that the battle against climate change is deadly serious, that they are ready to step up and plan to reap the rewards of decarbonisation,” she said.

However, the government’s hold on power is fragile. With just a quarter of parliamentary seats it will depend on the more leftwing Podemos and liberal Ciudadanos parties to pass the climate plan.

No dates were included in the legislation for phaseouts of coal or nuclear energy, and, echoing UK net zero policy shifts, a ban on new cars with petrol or diesel engines was delayed until 2040.

 

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