Audits aimed toward energy efficiency

By Southeast Farm Press


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Agriculture Secretary Tom Vilsack has announced an initiative designed to help agricultural producers transition to more energy efficient operations. This initiative will make funding available for individual onfarm energy audits designed to save both money and energy when fully implemented.

Reducing energy use on Americas farms and ranches will not only help our agricultural producers become more profitable, but also help the United States become more energy independent, said Vilsack. Through this initiative, producers will be able to receive individual onfarm energy audit evaluations and assistance with implementation of energy conservation and efficiency measures.

Approximately 1,000 onfarm energy audit evaluations in 29 states will be funded by $2 million through the Environmental Quality Incentives Program EQIP in fiscal year 2010. The energy audits will be individually tailored to ensure coverage of each farms primary energy uses such as milk cooling, irrigation pumping, heating and cooling of livestock production facilities, manure collection and transfer, grain drying, and similar common onfarm activities.

Participating states include: Alabama, Arizona, Arkansas, California, Colorado, Connecticut, Florida, Georgia, Idaho, Louisiana, Maine, Maryland, Massachusetts, Mississippi, Nevada, New Hampshire, New Mexico, New York, Oklahoma, Pennsylvania, Rhode Island, South Dakota, Tennessee, Texas, Utah, Vermont, Virginia, West Virginia, and Wisconsin.

Implementation will occur in stages beginning with the shortterm immediate goal of providing the onfarm energy audits to help identify how the operations can become more energy efficient. Longerterm goals will involve development of agricultural energy management plans for cost effective implementation of the recommendations provided in their onfarm energy audits. More information about agricultural energy management plans is available at www.nrcs.usda.gov/programs/eqip/cap.html.

The 2008 farm bill provides authority to use EQIP financial assistance funds for payment of practices and conservation activities involving the development of an Agricultural Energy Management Plan AgEMP appropriate for the eligible land of a program participant. The Farm Bill statute allows EQIP payments for up to 75 percent of the estimated incurred cost of practice implementation for the development of an AgEMP meeting agency standards and requirements. Eligible producers in the above listed states may apply for the AgEMP through application at their local NRCS office. EQIP payments are made directly to program participants for development of an AgEMP by a certified Technical Service Provider TSP http://techreg.usda.gov/CustLocateTSP.aspx.

Information about how to apply for an AgEMP is available at www.nrcs.usda.gov/programs/eqip/EQIP_signup/2009_signup/index.html. Click on the state where the property you are interested in obtaining an EQIP AgEMP is located. Dairy, beef, poultry, swine, and other agricultural operations are included in this energy efficiency initiative. USDAs Natural Resources Conservation Service, in partnership with USDA Rural Development, will implement the agricultural energy conservation and efficiency initiative.

For information about other NRCS conservation programs, online visit www.nrcs.usda.gov, or visit the nearest USDA Service Center in your area.

This year represents the 75th year of NRCS helping people help the land. Since its inception the NRCS conservation delivery system has advanced a unique partnership with state and local governments and private landowners delivering conservation based on specific, local conservation needs, while accommodating state and national interests.

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Alberta's Last Coal Plant Closes, Embracing Clean Energy

Alberta Coal Phase-Out signals a clean energy transition, replacing coal with natural gas and renewables, cutting greenhouse gas emissions, leveraging a carbon levy, and supporting workers in Alberta's evolving electricity market.

 

Key Points

Alberta Coal Phase-Out moves power from coal to lower-emission natural gas and renewables to reduce grid emissions.

✅ Last coal plant closed: Genesee Generating Station, Sept 30, 2023

✅ Shift to natural gas and renewables lowers emissions

✅ Carbon levy and incentives accelerated clean power build-out

 

The closure of the Genesee Generating Station on September 30, 2023, marked a significant milestone in Alberta's energy history, as the province moved to retire coal power by 2023 ahead of its 2030 provincial deadline. The Genesee, located near Calgary, was the province's last remaining coal-fired power plant. Its closure represents the culmination of a multi-year effort to transition Alberta's electricity sector away from coal and towards cleaner sources of energy.

For decades, coal was the backbone of Alberta's electricity grid. Coal-fired plants were reliable and relatively inexpensive to operate. However, coal also has a significant environmental impact. The burning of coal releases greenhouse gases, including carbon dioxide, a major contributor to climate change. Coal plants also produce air pollutants such as sulfur dioxide and nitrogen oxide, which can cause respiratory problems and acid rain, and in some regions electricity is projected to get dirtier as gas use expands.

In recognition of these environmental concerns, the Alberta government began to develop plans to phase out coal-fired power generation in the early 2000s. The government implemented a number of policies to encourage the shift from coal to cleaner energy such as natural gas and renewable energy. These policies included providing financial incentives for the construction of new natural gas plants and renewable energy facilities, as well as imposing a carbon levy on coal-fired generation.

The phase-out of coal was also driven by economic factors. The cost of natural gas has declined significantly in recent years, making it a more competitive fuel source for electricity generation as producers switch to gas under evolving market conditions. Additionally, the Alberta government faced increasing pressure from the federal government to reduce greenhouse gas emissions.

The transition away from coal has not been without its challenges. Coal mining and coal-fired power generation have long been important parts of Alberta's economy. The closure of coal plants has resulted in job losses in the affected communities. The government has implemented programs to help workers transition to new jobs in the clean energy sector.

Despite these challenges, the closure of the Genesee Generating Station is a positive development for Alberta's environment and climate. Coal-fired power generation is one of the largest sources of greenhouse gas emissions in Alberta, and recent wind generation outpacing coal underscores the sector's transformation. The closure of the Genesee is expected to result in a significant reduction in emissions, helping Alberta to meet its climate change targets.

The transition away from coal also presents opportunities for Alberta. The province has vast natural gas resources, which can be used to generate electricity with lower emissions than coal. Alberta is also well-positioned to develop renewable energy sources, such as wind power and solar power. These renewable energy sources can help to further reduce emissions and create new jobs in the clean energy sector.

The closure of the Genesee Generating Station is a significant milestone in Alberta's energy history. It represents the end of an era for coal-fired power generation in the province, a shift mirrored by the UK's last coal station going offline earlier this year. However, it also marks the beginning of a new era for Alberta's energy sector. By transitioning to cleaner sources of energy, Alberta can reduce its environmental impact and create a more sustainable energy future.

 

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Ottawa sets out to protect its hydro heritage

Ottawa Hydro Substation Heritage Designation highlights Hydro Ottawa's 1920s architecture, Art Deco facades, and municipal utility history, protecting key voltage-reduction sites in Glebe, Carling-Merivale, Holland, King Edward, and Old Ottawa South.

 

Key Points

A city plan to protect Hydro Ottawa's 1920s substations for architecture, utility role, and civic electrical heritage.

✅ Protects five operating voltage-reduction sites citywide

✅ Recognizes Art Deco and early 20th century utility architecture

✅ Allows emergency demolition to ensure grid safety

 

The city of Ottawa is looking to designate five hydro substations built nearly a century ago as heritage structures, a move intended to protect the architectural history of Ottawa's earliest forays into the electricity business, even as Ottawa electricity consumption has shifted in recent years.

All five buildings are still used by Hydro Ottawa to reduce the voltage coming from transmission lines before the electricity is transmitted to homes and businesses, and when severe weather causes outages, Sudbury Hydro crews work to reconnect service across communities.

Electricity came to Ottawa in 1882 when two carbon lamps were installed on LeBreton Flats, heritage planner Anne Fitzpatrick told the city's built heritage subcommittee on Tuesday. It became a lucrative business, and soon a privately owned monopoly that drew public scrutiny similar to debates over retroactive charges in neighboring jurisdictions.

In 1905, city council held a special meeting to buy the electrical company, which led to a dramatic drop in electricity rates for residents, a contrast with recent discussions about peak hydro rates for self-isolating customers.

The substations are now owned by Hydro Ottawa, which agreed to the heritage designations on the condition it not be prevented from emergency demolitions if it needs to address incidents such as damaging storms in Ontario while it works to "preserve public safety and the continuity of critical hydro electrical services."

Built in 1922, the substation at the intersection of Glebe and Bronson avenues was the first to be built by the new municipal electrical department, long before modern battery storage projects became commonplace on Ontario's grid.

The largest of the substations being protected dates back to 1929 and is found at the corner of Carling Avenue and Merivale Road. It was built to accommodate a growing population in areas west of downtown including Hintonburg and Mechanicsville.

The substation on Holland Avenue near the Queensway is different from the others because it was built in 1924 to serve the Ottawa Electric Railway Company. The streetcar company operated from 1891 to 1959, and urban electrical infrastructure can face failures such as the Hydro-Québec manhole fire that left thousands without power.

This substation on King Edward Avenue was built in 1931 and designed by architect William Beattie, who also designed York Street Public School in Lowertown and the substation on Carling Avenue. 

The last substation to be built in a 'bold and decorative style' is at 39 Riverdale Ave. in Old Ottawa South, according to city staff. It was designed in an Art Deco style by prominent architect J. Albert Ewart, who was also behind the Civic Hospital and nearby Southminster Church on Bank Street.

 

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ACCIONA Energía Launches 280 MW Wind Farm in Alberta

Forty Mile Wind Farm delivers 280 MW of renewable wind power in Alberta, with 49 Nordex turbines by ACCIONA Energía, supplying clean electricity to the grid, lowering carbon emissions, and enabling future 120 MW expansion.

 

Key Points

A 280 MW ACCIONA Energía wind farm in Alberta with 49 Nordex turbines, delivering clean power and cutting carbon.

✅ 280 MW via 49 Nordex N155 turbines on 108 m towers

✅ Supplies clean power to 85,000+ homes, reducing emissions

✅ Phase II could add 120 MW, reaching 400 MW capacity

 

ACCIONA Energía, a global leader in renewable energy, has successfully launched its Forty Mile Wind Farm in southern Alberta, Canada, amid momentum from a new $200 million wind project announced elsewhere in the province. This 280-megawatt (MW) project, powered by 49 Nordex turbines, is now supplying clean electricity to the provincial grid and stands as one of Canada's ten largest wind farms. It also marks the company's largest wind installation in North America to date. 

Strategic Location and Technological Specifications

Situated approximately 50 kilometers southwest of Medicine Hat, the Forty Mile Wind Farm is strategically located in the County of Forty Mile No. 8. Each of the 49 Nordex N155 turbines boasts a 5.7 MW capacity and stands 108 meters tall. The project's design allows for future expansion, with a potential Phase II that could add an additional 120 MW, bringing the total capacity to 400 MW, a scale comparable to Enel's 450 MW U.S. wind farm now in operation. 

Economic and Community Impact

The Forty Mile Wind Farm has significantly contributed to the local economy. During its peak construction phase, the project created approximately 250 jobs, with 25 permanent positions anticipated upon full operation. These outcomes align with an Alberta renewable energy surge projected to power thousands of jobs across the province. Additionally, the project has injected new tax revenues into the local economy and provided direct financial support to local non-profit organizations, including the Forty Mile Family & Community Support Services, the Medicine Hat Women’s Shelter Society, and the Root Cellar Food & Wellness Hub. 

Environmental Benefits

Once fully operational, the Forty Mile Wind Farm is expected to generate enough clean energy to power more than 85,000 homes, supporting wind power's competitiveness in electricity markets today. This substantial contribution to Alberta's energy mix aligns with ACCIONA Energía's commitment to sustainability and its goal of reducing carbon emissions. The project is part of the company's broader strategy to expand its renewable energy footprint in North America and support the transition to a low-carbon economy. 

Future Prospects

Looking ahead, ACCIONA Energía plans to continue its expansion in the renewable energy sector, as peers like TransAlta add 119 MW in the U.S. to their portfolios. The success of the Forty Mile Wind Farm serves as a model for future projects and underscores the company's dedication to delivering sustainable energy solutions, even as Alberta's energy future presents periodic headwinds. With ongoing developments and a focus on innovation, ACCIONA Energía is poised to play a pivotal role in shaping the future of renewable energy in North America.

The Forty Mile Wind Farm exemplifies ACCIONA Energía's commitment to advancing renewable energy, supporting local communities, and contributing to environmental sustainability, and it benefits from evolving demand signals, including a federal green electricity contract initiative in Canada that encourages clean supply. As the project continues to operate and expand, it stands as a testament to the potential of wind energy in Canada's clean energy landscape.

 

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Ford deal to build electric cars in Oakville comes amid $500M government cash to upgrade plant

Ford Oakville EV investment secures government funding, Unifor deal, and plant retooling, channeling $500 million plus $1.98 billion for Canadian electric vehicle manufacturing, Windsor engine contracts, and 2025 production, strengthening Ontario's auto industry.

 

Key Points

Government and Ford will retool Oakville for EVs, creating jobs under a Unifor deal and Windsor engine work.

✅ $500M government funding for plant retooling

✅ Ford commits $1.98B; five new EVs by 2025

✅ Unifor deal adds Windsor engine work, jobs

 

The federal government and Ontario have pledged to spend up to $500 million to make the Ford plant in Oakville, Ont., able to build electric vehicles, aligning with efforts to capitalize on the U.S. EV pivot underway.

The future of the plant has been a key question for Canada's automotive industry, as moves like GM's Ontario EV deal point to broader changes, ever since the Unifor union started negotiating with the automaker for a new three-year pact to cover the company's Canadian workforce.

The two sides struck a deal a few hours after a midnight strike deadline on Tuesday morning, one that will see the company commit $1.98 billion to build five new electric vehicles and an engine contract that could yield new EV jobs in Windsor, Ont.

Ford has previously committed to spending $11 billion US to develop and manufacture electric vehicles, but so far all of that money was earmarked for Ford plants in Mexico and the company's home state of Michigan.

"With Oakville gaining such a substantial portion of Ford's planned investment, the assembly plant and its workers are better set for employment going forward," said Sam Fiorani, vice-president of global forecasting at AutoForecast Solutions.

Unifor's 'unique' Ford deal includes 5 new electric vehicles in Oakville, engine for Windsor plants
Currently, the plant builds the Ford Edge and Lincoln Nautilus, but concerns over the plant's future emerged earlier this year when a report suggested Ford was contemplating scrapping the Edge altogether. The new vehicles will come as welcome news for the plant, even as Fiorani says he worries that demand for the electric vehicles (EV) has so far not lived up to the hype.

"The EV market is coming, and Ford looks to be preparing for it. However, the demand is just not growing in line with the proposed investment from all vehicle manufacturers," he said.

Plant needs upgrade first
And the plant can't simply flip a switch and start building an entirely new type of vehicle. It will require a major retooling, and that will require time — and cash — to happen, which is where government cash comes in, as seen with a Niagara Region battery plant supporting the EV supply chain.

As first reported by the Toronto Star, the two branches of government have committed to spent up to $500 million combined to upgrade the plant so that it can build electric vehicles.

"The retooling will begin in 2024 with vehicles rolling off the line in 2025," Unifor president Jerry Dias said. "So we know this is a decades-long commitment."

It's not clear what portion of the cash will come from what branch of government, but CBC News has previously reported that Wednesday's throne speech is expected to contain a number of policies aimed at beefing up Canada's electric vehicle industry, as EV assembly deals are putting Canada in the race, both on the consumer side and for businesses that build them.

Ontario's minister of economic development and trade welcomed the news of a tentative deal on Tuesday and confirmed that Queen's Park legislators stand ready to do their part, as shown by Honda's Ontario battery investment moves in the province.

"Our government will always work with our federal colleagues, workers and the auto sector to ensure the right conditions are in place for the industry to remain stable today and seize the new opportunities of tomorrow," a spokesperson for Vic Fedeli told CBC News in an emailed statement Tuesday.

 

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Nova Scotia can't order electric utility to lower power rates, minister says

Nova Scotia Power Rate Regulation explains how the privately owned utility is governed by the Utility Review Board, limiting government authority, while COVID-19 relief measures include suspended disconnections, waived fees, payment plans, and emergency assistance.

 

Key Points

URB oversight where the board, not the province, sets power rates, with COVID-19 relief pausing disconnections and fees.

✅ Province lacks authority to order rate cuts

✅ URB regulates Nova Scotia Power rates

✅ Relief: no disconnections, waived fees, payment plans

 

The province can't ask Nova Scotia Power to lower its rates to ease the financial pressure on out-of-work residents because it lacks the authority to take that kind of action, even as the Nova Scotia regulator approved a 14% hike in a separate proceeding, the provincial energy minister said Thursday.

Derek Mombourquette said he is in "constant contact" with the privately owned utility.

"The conversations are ongoing with Nova Scotia Power," he said after a cabinet meeting.

When asked if the Liberal government would order the utility to lower electricity rates as households and businesses struggle with the financial fallout from the COVID-19 pandemic, Mombourquette said there was nothing he could do.

"We don't have the regulatory authority as a government to reduce the rates," he told reporters during a conference call.

"They're independent, and they are regulated through the (Nova Scotia Utility Review Board). My conversations with Nova Scotia Power essentially have been to do whatever they can to support Nova Scotians, whether it's residents or businesses in this very difficult time."

Asked if the board would take action, the minister said: "I'm not aware of that," despite the premier's appeals to regulators in separate rate cases.

However, the minister noted that the utility, owned by Emera Inc., has suspended disconnections for bill non-payment for at least 90 days, a step similar to reconnection efforts by Hydro One announced in Ontario.

It has also relaxed payment timelines and waived penalties and fees, while some jurisdictions offered lump-sum credits to help with bills.

Nova Scotia Power CEO Wayne O'Connor has also said the company is making additional donations to a fund available to help low-income individuals and families pay their energy bills.

In late March, Ontario cut electricity rates for residential consumers, farms and small businesses in response to a surge in people forced to work from home as a result of the pandemic, alongside bill support measures for ratepayers.

Premier Doug Ford said there would be a 45-day switch to off-peak rates, later moving to a recovery rate framework, which meant electricity consumers would be paying the lowest rate possible at any time of day.

The change was expected to cost the province about $162 million.

 

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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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