Automatic standby generators selling briskly this year

By Florida Today


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While most people consider the wonders of generators only when staring down the barrel of a hurricane, Nathan Iacobacci, president of Weather Engineers in Melbourne, thinks about it 365 days a year.

In summer, however, the rest of the world catches up with him.

"If people see a storm anywhere, the phones start ringing off the hook," Iacobacci said. "It's become a very popular item."

Weather Engineers, which in 2005 was named top Carrier dealer out of 9,000 nationwide, is one of the local companies that has seen a steady and strong consumer interest in automatic standby generators.

"We're busy year-round, but July is our busiest month," said Wes Henderson, in charge of generator sales at Weather Engineers.

The company started selling generators three years ago.

Iacobacci initially had thought the product would primarily serve to direct additional customers to his business.

"We knew we would pick up collateral business," Iacobacci said.

Sales surpassed expectations and now account for 15 percent of the company's annual sales.

Other companies have experienced similarly strong growth.

"We're doing very well with them this year," said Joe Chida, executive vice president for Urban Electrical in Melbourne.

Like Weather Engineers, Urban Electrical has been installing standbys for three years. Standbys account for between 10 percent and 15 percent of company total sales.

"I sold eight units in the last two weeks," Chida said.

It's not surprising that vulnerable beachside dwellers want them.

But Chida also sells many units to Palm Bay residents who faced weeks without power in 2004.

"They don't want to go through that again," Chida said.

The world of generators is made up of two major types: the high-end automatic standby models; and the portable, humming little boxes that populate people's garages and backyards after a serious outage.

The portable models so popular at warehouse clubs and big-box superstores typically sell for $500.

Automatic standby generators can be 10 times as expensive, but are completely automatic. When power goes off, the generators take over.

"I tell people to sit back and count back from 10, and the power will be back on," Henderson said. "It is a completely automatic, permanent fixed item."

These generators will provide juice to all appliances - including the ever-desired air-conditioning system - for as long as the power is out.

"The small portable ones are not big enough to run an air conditioner," Iacobacci said. "They're also not made to run 24/7."

Portables typically are rated at 5,000 kilowatts, although lower-end "suitcase" types are as small as 1,000 kilowatts.

"They're made to be used while camping," Iacobacci said.

Like insurance, an automatic standby generator is something you don't think about until the need arises.

"You take it for granted until the power goes off," Henderson said.

Automatic standby generators are a relatively new product, but already prices have dropped, making them more affordable to Joe Homeowner.

Three years ago, when Iacobacci got into the standby generator business, the price range fluctuated widely.

"They were all over the place - from $6,500 to $16,000," he said.

Now, costs have standardized and, as with digital televisions, prices have gone down.

"Prices have become reasonable," Henderson said.

Weather Engineers charges about $7,000 for a turnkey installation of the natural-gas models, a little more for liquid propane.

That will buy you a 16,000-kilowatt, entry-level generator that will comfortably power up to a 2,000-square-foot home. Larger homes may require up to 35,000-kilowatt unit.

The unit could pay for itself if it saves the home from mold.

"During the 2004 hurricanes, the power to south Melbourne Beach was out for three to four weeks," Iacobacci said. "When you're pricing these units, you need to consider how much it would cost you to mitigate mold."

"It's a big market in Florida," Iacobacci said. "It's incredible the number of generators sold in Florida. Carrier has moved thousands of these generators in Florida in the past three years. In South Florida, they sell like mad."

In addition to Carrier, Generac-Guardian, Briggs & Stratton and Kohler are among the companies that manufacture standbys.

While Florida is a very strong market for generator sales, it is by no means the only one.

"They're being sold throughout the United States, anywhere where people get power interruptions because of weather or the power grid," Iacobacci said.

"The national power grid has become increasingly unreliable," Henderson said.

Automatic standby generators may be a nice luxury for most people, but they can be truly lifesavers for others.

"For some people, it's not a luxury. It's a medical necessity," Henderson said.

If an individual requires oxygen, these standby models can make the difference between life and death.

"We do a lot of units where a generator is critical to survival," Henderson said.

For Weather Engineers, the bulk of generator business is residential.

"The commercial side is lagging, and I believe they're making a mistake," Henderson said.

However, commercial installations, like the one Weather Engineers did for Sunshine Health Foods in Titusville, are starting to catch up.

"The owner there has a lot of people dependent on her food," Henderson said. "It's commendable that she had this type of foresight."

Linda Garrison, owner of Sunshine Health Foods, recently bought not one, but two, standby automatic generators from Weather Engineers.

One went to her Sunshine Health Foods shop in Titusville, the other to her home.

Garrison's customers, many of whom have allergies, depend on her for special foods.

"I cater to a unique group of people," Garrison said. "I have walk-in coolers and freezers, so if the electricity goes off, I don't have to scramble to save the products."

Garrison figures the two units will pay for themselves after two active hurricane seasons.

But, for Garrison, there's more to these generators than financial savings.

"What nobody factors in is peace of mind," she said. "I'm hooked up. I don't have to worry. It's really about peace of mind - about being proactive, rather than reactive."

Although they carry relatively big price tags, these units can save businesses a lot of money.

According to Carrier statistics, being without power would cost a typical restaurant $700 an hour in lost revenue. Pharmacies lose $1,400 and supermarkets $3,510 an hour whenever the power goes off for extended periods.

"The generators can pay for themselves in hours," Henderson said.

Hospitals, of course, are required to have standby power, as are certain gas stations that are located along hurricane evacuation routes.

Major competition for companies like Weather Engineers and Urban Electrical lies in the Internet and from big-box home-improvement centers.

Some homeowners purchase the generators through the Internet with the thought that they can either install them themselves or act as contractor for the project.

Unlike the plug-and-go portables, however, the standbys are not easy to set up.

"It actually frightens me that people are buying these things from the Internet or from big-box stores, and trying to install them themselves," Henderson said.

The project requires a site and engineering plan, a concrete pad and electrical connection and fuel hookup, either through natural gas or by the addition of a propane tank buried in the yard.

"It's not something you want to do yourself," Henderson said. "There are certain inherent dangers in installing them if you're not qualified."

Do-it-yourself permitting also can be a headache.

"This is not an over-the-counter item," Iacobacci said.

Unlike roof or air-conditioning jobs, which require only one permit, installing a standby automatic generator necessitates multiple permitting, another headache-in-waiting for homeowners.

"Customers may not be getting enough information when they buy," said Chida, who schedules a home evaluation for any prospective standby generator customer. "You need to see what the house looks like and what the customer's expectations are."

Size matters with generators, both the unit and with the liquid-propane tanks that power some of them.

And homeowners may unwittingly purchase a generator inadequate to power their homes.

If liquid propane is used, Iacobacci recommends a 500-gallon tank.

"Some homeowners will install a 100-gallon tank," he said. "Hundred-gallon tanks are very needy, like a baby. A 500-gallon tank will give you enough fuel for 10 to 12 days. You have a bigger window to refuel."

According to Iacobacci, in the aftermath of a hurricane, liquid-propane companies typically will first service emergency facilities like hospitals, and then restaurant and other large commercial accounts, before moving down to the smaller residential contracts.

A 500-gallon tank could make the difference between cool and comfy and hot and bothered while you await a refill.

As the generators become even better and prices continue to drop, Henderson, Iacobacci and Chida expect that standby automatic generators will become part of a growing number of homes.

"The units are becoming more efficient, with a longer life of 20 years or more," Henderson said.

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National Energy Board hears oral traditional evidence over Manitoba-Minnesota transmission line

Manitoba-Minnesota Transmission Line connects Bipole III to Minnesota, raising export capacity, as NEB hearings weigh Indigenous rights, treaty obligations, environmental assessment, cumulative effects, and cross-border hydroelectric infrastructure impacts, land access, socio-economic concerns, and regulatory review.

 

Key Points

A cross-border hydro line linking Manitoba to Minnesota under review on Indigenous rights and environment concerns.

✅ Connects Bipole III to Minnesota to boost exports

✅ NEB hearings include Indigenous rights and treaty issues

✅ Environmental and access impacts debated in regulatory review

 

Concerned Indigenous groups asked the National Energy Board this week to take into consideration existing and future impacts and treaty rights, which have prompted a halt to Site C work elsewhere, when considering whether to OK a new hydro transmission line between Manitoba and Minnesota.

Friday was the last day of the oral traditional evidence hearings in Winnipeg on Manitoba Hydro's Manitoba-Minnesota Transmission project.

The international project will connect Manitoba Hydro's Bipole III transmission line to Minnesota and increase the province's electricity export capacity to 3185 MW from 2300 MW.

#google#

During the hearings Indigenous groups brought forward concerns and evidence of environmental degradation, echoing Site C dam opponents in other regions, and restricted access to traditional lands.

Ramona Neckoway, a member of the Nelson House First Nation, talked about her concern about the scope of Manitoba Hydro's application to the NEB.

"It's only concerned with a narrow 213 km corridor and thus it erases the histories, socio-economic impacts and the environmental degradation attached to this energy source," said Neckoway.

Prior to the hearings the board stated it did not intend to assess the environmental and socio-economic impacts of upstream or downstream facilities associated with electricity production, even as a utilities watchdog on Site C stability raised questions elsewhere.

However, the board did hear evidence from upstream and downstream affected communities despite objection from Manitoba Hydro lawyers.

"Manitoba Hydro objected to us being here, saying that we are irrelevant, but we are not irrelevant," said Elder Tommy Monias from Cross Lake First Nation.

Manitoba Hydro representative Bruce Owen said, "We respect the NEB hearing process and look forward to the input of all interested parties."

The hearings provided a rare opportunity for First Nations communities, similar to Ontario First Nations urging action, to voice their concerns about the line on a federal level.

"One of the hopes is that this project can't be built until a system-wide assessment is made," said Dr. Peter Kulchyski, an expert witness for the southern chiefs organization and professor of Native Studies at the University of Manitoba.

 

Hearings continue

The line is already under construction on the American side of the border as the NEB public hearings continue until June 22 with cross examinations and final arguments from Manitoba Hydro and intervenor groups.

The NEB's final decision on the Manitoba-Minnesota transmission line, amid an energy board delay recommendation, will be made before March 2019.

 

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US NRC streamlines licensing for advanced reactors

NRC Advanced Reactor Licensing streamlines a risk-informed, performance-based, technology-inclusive pathway for advanced non-light water reactors, aligning with NEIMA to enable predictable regulatory reviews, inherent safety, clean energy deployment, and industrial heat, hydrogen, and desalination applications.

 

Key Points

A risk-informed, performance-based NRC pathway streamlining licensing for advanced non-light water reactors.

✅ Aligned with NEIMA: risk-informed, performance-based, tech-inclusive

✅ Predictable licensing for advanced non-light water reactor designs

✅ Enables clean heat, hydrogen, desalination beyond electricity

 

The US Nuclear Regulatory Commission (NRC) voted 4-0 to approve the implementation of a more streamlined and predictable licensing pathway for advanced non-light water reactors, aligning with nuclear innovation priorities identified by industry advocates, the Nuclear Energy Institute (NEI) announced, and amid regional reliability measures such as New England emergency fuel stock plans that have drawn cost scrutiny.

This approach is consistent with the Nuclear Energy Innovation and Modernisation Act (NEIMA), a nuclear innovation act passed in 2019 by the US Congress calling for the development of a risk-informed, performance-based and technology inclusive licensing process for advanced reactor developers.

NEI Chief Nuclear Officer Doug True said: “A modernised regulatory framework is a key enabler of next-generation nuclear technologies that, amid ACORE’s challenge to DOE subsidy proposals in energy market proceedings, can help us meet our energy needs while protecting the climate. The Commission’s unanimous approval of a risk-informed and performance-based licensing framework paves the way for regulatory reviews to be aligned with the inherent safety characteristics, smaller reactor cores and simplified designs of advanced reactors.”

Over the last several years the industry’s Licensing Modernisation Project, sponsored by US Department of Energy, led by Southern Nuclear, and supported by NEI’s Advanced Reactor Regulatory Task Force, and influenced by a presidential order to bolster uranium and nuclear energy, developed the guidance for this new framework. Amid shifts in the fuel supply chain, including the U.S. ban on Russian uranium, this approach will inform the development of a new rule for licensing advanced reactors, which NEIMA requires.

“A well-defined licensing path will benefit the next generation of nuclear plants, especially as regions consider New England market overhaul efforts, which could meet a wide range of applications beyond generating electricity such as producing heat for industry, desalinating water, and making hydrogen – all without carbon emissions,” True noted.

 

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Electricity exports to New York from Quebec will happen as early as 2025: Hydro-Quebec

Hertel-New York Interconnection delivers Hydro-Quebec renewable energy via a cross-border transmission line to New York City by 2025, supplying 1,250 MW through underground and underwater routes under a 25-year contract.

 

Key Points

A cross-border line delivering 1,250 MW of Hydro-Quebec hydropower to New York City via underground routes.

✅ 1,250 MW clean power to NYC by 2025

✅ 56.1 km underground, 1.6 km underwater in Quebec

✅ 25-year contract; Mohawk partnership revenue

 

Hydro-Quebec announced Thursday it has chosen the route for the Hertel-New York interconnection line, which will begin construction in the spring of 2023 in Quebec.

The project will deliver 1,250 megawatts of Quebec hydroelectricity to New York City starting in 2025, even as a recent electricity shortage report warns about rising demand at home.

It's a 25-year contract for Hydro-Quebec, the largest export contract for the province-owned company, and comes as hydrogen production investments gain traction in Eastern Canada.

The Crown corporation has not disclosed potential revenues from the project, but Premier François Legault mentioned on social media last September that a deal in principle worth more than $20 billion over 25 years was in the works.

The route includes a 56.1-kilometre underground and a 1.6-kilometre underwater section, similar to the Lake Erie Connector project planned under Lake Erie.

Eight municipalities in the Montérégie region will be affected: La Prairie, Saint-Philippe, Saint-Jacques-le-Mineur, Saint-Édouard, Saint-Patrice-de-Sherrington, Saint-Cyprien-de-Napierville, Saint-Bernard-de-Lacolle and Lacolle.

Across the country, new renewables such as wind projects in Yukon are receiving federal support, reflecting broader grid decarbonization.

The last part of the route will run along Fairbanks Creek to the Richelieu River, where it will connect with the American network.

Further south, there will be a 545-kilometre link between the Canada-U.S. border and New York City, while a separate Maine transmission approval advances a New England pathway for Quebec power.

Hydro-Quebec is holding two consultations on the project, on Dec. 8 in Lacolle and Dec. 9 in Saint-Jacques-le-Mineur.

Elsewhere in Atlantic Canada, EV-to-grid integration pilots are underway to test how vehicles can support the power system.

Once the route is in service, the Quebec line will be subject to a partnership between Hydro-Quebec and the Mohawk Council of Kahnawake, which will benefit from economic remunerations for 40 years.

To enhance reliability, grid-scale battery storage projects are also expanding in Ontario.

 

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P.E.I. government exploring ways for communities to generate their own electricity

P.E.I. Community Energy Independence empowers local microgrids through renewable generation, battery storage, and legislative reform, enabling community-owned power, stable electricity rates, and grid-friendly distributed generation across Island communities with wind, biomass, and net metering models.

 

Key Points

A program enabling communities to generate and store renewable power under supportive laws and grid-friendly models.

✅ Legislative review of Electric Power and Renewable Energy Acts

✅ Community microgrids with wind, biomass, and battery storage

✅ Grid integration without raising rates via Maritime Electric

 

The P.E.I. government is taking steps to review energy legislation and explore new options when it comes to generating power across Island communities.

Energy Minister Steven Myers said one of those options will be identifying ways for Island communities to generate their own energy, aligning with a federal electrification study now examining how electricity can reduce or eliminate fossil fuels. 

He said the move would provide energy independence, create jobs and economic development, and save the communities on their energy bills, as seen with an electricity bill credit in Newfoundland that eased costs for consumers.

But the move will require sweeping legislative changes, that may include the merging of the Electric Power Act and the Renewable Energy Act, similar to an electricity market overhaul in Connecticut seen in other jurisdictions.  

Myers said creating energy independence should ensure a steady supply of electricity while also ensuring costs remain reasonable for P.E.I. residents, even as a Nova Scotia electricity rate hike highlights regional cost pressures.   

"We have communities that are looking to generate their own electricity for their own needs," said Myers, adding the province will not dictate what energy sources communities can invest in. 

He also said the province wants to find new community-based models that will complement existing services.

"How do we do that in a way that we don't impact the grid, that we don't impact the service that Maritime Electric is delivering, mindful of a seasonal rate backlash in New Brunswick that illustrates consumer concerns, that we don't drive up the rates for all other Islanders."

Last fall, a group of P.E.I. MLAs traveled to Samsø, a small Danish island, where they learned about renewable and sustainable energy systems being used there.

The province is looking at storage options so it can store power generated during the day to be used in the evening when electricity use is at its highest. (CBC)
Samsø produces 100 per cent of its electricity from wind and biomass, and utilities like HECO meeting renewable goals early show how quickly transitions can occur. The P.E.I. government said the Island produces 25 per cent of its electricity from wind. 

Following the trip, Myers said he was impressed by the control the island had over its energy production and would like to see if a similar model could work on P.E.I. 

Myers said the legislative review will also look at different ways to store energy on the Island. 

He said that will allow communities to sell that excess energy into the provincial electricity grid, and those revenues could be redirected into that community's priorities. 

'For the survival and the future of their community'
"This is kind of a model that we had suggested that would be in place that would allow people in their own community to produce a revenue stream for themselves that they could then turn into projects like rinks, or parks, or tennis courts or whatever it is that community thinks is the most important thing for the survival and the future of their community," said Myers. 

Energy Minister Steven Myers says creating energy independence could create a steady supply of electricity while also ensuring costs remain reasonable for P.E.I. residents. (Randy McAndrew/CBC)
The province said Maritime Electric, Summerside Electric and the P.E.I. Energy Corporation will be involved in the review, recognizing that a Nova Scotia ruling on rate-setting powers underscores regulatory limits 

Government also wants to hear from Islanders and will be accepting written submissions beginning Monday. Myers said the province is also planning to host public consultations, but because of COVID-19, those will be held virtually in mid-June.

Myers calls this a major move, one that will take time. He said he doesn't expect the legislation to be made public until the spring of 2021.

"I want to make sure we take our time and do the proper consultation."

 

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Wartsila to Power USA’s First Battery-Electric High-Speed Ferries

San Francisco Battery-Electric Ferries will deliver zero-emission, high-speed passenger service powered by Wartsila electric propulsion, EPMS, IAS, batteries, and shore power, advancing maritime decarbonization under the REEF program and USCG Subchapter T standards.

 

Key Points

They are the first US zero-emission high-speed passenger ferries using integrated electric propulsion and shore power

✅ Dual 625 kW motors enable up to 24-knot service speeds

✅ EPMS, IAS, DC hub, and shore power streamline operations

✅ Built to USCG Subchapter T for safety and compliance

 

Wartsila, a global leader in sustainable marine technology, has been selected to supply the electric propulsion system for the United States' first fully battery-electric, zero-emission high-speed passenger ferries. This significant development marks a pivotal step in the decarbonization of maritime transport, aligning with California's ambitious environmental goals, including recent clean-transport investments across ports and corridors.

A Leap Toward Sustainable Maritime Transport

The project, commissioned by All American Marine (AAM) on behalf of San Francisco Bay Ferry, involves the construction of three 150-passenger ferries, reflecting broader U.S. advances like the Washington State Ferries hybrid upgrade now underway. These vessels will operate on new routes connecting the rapidly developing neighborhoods of Treasure Island and Mission Bay to downtown San Francisco. The ferries are part of the Rapid Electric Emission Free (REEF) Ferry Program, a comprehensive initiative by San Francisco Bay Ferry to transition its fleet to zero-emission propulsion technology. The first vessel is expected to join the fleet in early 2027.

Wärtsilä’s Role in the Project

Wärtsilä's involvement encompasses the supply of a comprehensive electric propulsion system, including the Energy and Power Management System (EPMS), integrated automation system (IAS), batteries, DC hub, transformers, electric motors, and shore power supply. This extensive scope underscores Wärtsilä’s expertise in providing integrated solutions for emission-free marine transportation. The company's extensive global experience in developing and supplying integrated systems and solutions for zero-emission high-speed vessels, as seen with electric ships on the B.C. coast operating today, was a key consideration in the selection process.

Technical Specifications of the Ferries

The ferries will be 100 feet (approximately 30 meters) in length, with a beam of 26 feet and a draft of 5.9 feet. Each vessel will be powered by dual 625-kilowatt electric motors, enabling them to achieve speeds of up to 24 knots. The vessels will be built to U.S. Coast Guard Subchapter T standards, ensuring compliance with stringent safety regulations.

Environmental and Operational Benefits

The transition to battery-electric propulsion offers numerous environmental and operational advantages. Electric ferries produce zero emissions during operation, as demonstrated by Berlin's electric ferry deployments, significantly reducing the carbon footprint of maritime transport. Additionally, electric propulsion systems are generally more efficient and require less maintenance compared to traditional diesel engines, leading to lower operational costs over the vessel's lifespan.

Broader Implications for Maritime Decarbonization

This project is part of a broader movement toward sustainable maritime transport in the United States. San Francisco Bay Ferry has also approved the purchase of two larger 400-passenger battery-electric ferries for transbay routes, further expanding its commitment to zero-emission operations. The agency has secured approximately $200 million in funding from local, state, and federal sources, echoing infrastructure bank support seen in B.C., to support these initiatives, including vessel construction and terminal electrification.

Wartsila’s involvement in this project highlights the company's leadership in the maritime industry's transition to sustainable energy solutions, including hybrid-electric pathways like BC Ferries' new hybrids now in service. With a proven track record in supplying integrated systems for zero-emission vessels, Wärtsilä is well-positioned to support the global shift toward decarbonized maritime transport.

As the first fully battery-electric high-speed passenger ferries in the United States, these vessels represent a significant milestone in the journey toward sustainable and environmentally responsible maritime transportation, paralleling regional advances such as the Kootenay Lake electric-ready ferry entering service. The collaboration between Wärtsilä, All American Marine, and San Francisco Bay Ferry exemplifies the collective effort required to realize a zero-emission future for the maritime industry.

The deployment of these battery-electric ferries in San Francisco Bay not only advances the city's environmental objectives but also sets a precedent for other regions to follow. With continued innovation and collaboration, the maritime industry can look forward to a future where sustainable practices are the standard, not the exception.

 

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WY Utility's First Wind Farm Faces Replacement

Foote Creek I Wind Farm Repowering upgrades Wyoming turbines with new nacelles, towers, and blades, cutting 68 units to 12 while sustaining 41.6 MW, under PacifiCorp and Rocky Mountain Power's Energy Vision 2020 plan.

 

Key Points

Replacement at Foote Creek Rim I, cutting to 12 turbines while sustaining about 41.6 MW using modern 2-4.2 MW units.

✅ 12 turbines replace 68, output steady near 41.6 MW

✅ New nacelles, towers, blades; taller 500 ft turbines

✅ Part of PacifiCorp Energy Vision 2020 and Gateway West

 

A Wyoming utility company has filed a permit to replace its first wind farm—originally commissioned in 1998, composed of over 65 turbines—amid new gas capacity competing with nuclear in Ohio, located at Foote Creek Rim I. The replacement would downsize the number of turbines to 12, which would still generate roughly the same energy output.

According to the Star Tribune, PacifiCorp’s new installation would involve new nacelles, new towers and new blades. The permit was filed with Carbon County.

 

New WY Wind Farm

The replacement wind turbines will stand more than twice as tall as the old: Those currently installed stand 200 feet tall, whereas their replacements will tower closer to 500 feet. Though this move is part of the company’s overall plan to expand its state wind fleet as some utilities respond to declining coal returns in the Midwest, the work going into the Foote Creek site is somewhat special, noted David Eskelsen, spokesperson for Rocky Mountain Power, the western arm of PacifiCorp.

“Foote Creek I repowering is somewhat different from the repowering projects announced in the (Energy Vision) 2020 initiative,” he said. “Foote Creek is a complete replacement of the existing 68 foundations, towers, turbine nacelles and rotors (blades).”

Currently, the turbines at Foote Creek have 600 kilowatts capacity each; the replacements’ maximum production ranges from 2 megawatts to 4.2 megawatts each, with the total output remaining steady at 41.4 megawatts, a scale similar to a 30-megawatt wind expansion in Eastern Kings, though there will be a slight capacity increase to 41.6 megawatts, according to the Star Tribune.

As part of the wind farm repowering initiative, PacifiCorp is to become full owner and operator of the Foote Creek site. When the farm was originally built, an Oregon-based water and electric board was 21 percent owner; 37 percent of the project’s output was tied into a contract with the Bonneville Power Administration.

Otherwise, PacifiCorp is moving to further expand its state wind fleet in line with initiatives like doubling renewable electricity by 2030 in Saskatchewan, with the addition of three new wind farms—to be located in Carbon, Albany and Converse counties—which may add up to 1,150 megawatts of power.

According to PacifiCorp, the company has more than 1,000 megawatts of owned wind generation capability, along with long-term purchase agreements for more than 600 megawatts from other wind farms owned by other entities. Energy Vision 2020 refers to a $3.5 billion investment and company move that is looking to upgrade the company's existing wind fleet with newer technology, adding 1,150 megawatts of new wind resources by 2020 and a a new 140-mile Gateway West transmission segment in Wyoming, comparable to a transmission project in Missouri just energized.

 

 

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