Emera to acquire TECO Energy

By TECO Energy


NFPA 70b Training - Electrical Maintenance

Our customized live online or in‑person group training can be delivered to your staff at your location.

  • Live Online
  • 12 hours Instructor-led
  • Group Training Available
Regular Price:
$599
Coupon Price:
$499
Reserve Your Seat Today
Emera Inc. and TECO Energy, Inc. recently announced a definitive agreement for Emera to acquire TECO Energy, creating a North American energy leader, with over US$20 billion of assets and more than 2.4 million electric and gas customers. Upon closing, TECO Energy will become a wholly owned subsidiary of Emera.

Under the terms of the all-cash deal, which has been unanimously approved by the Board of Directors of both companies, TECO Energy shareholders will receive US $27.55 per common share, a 48 percent premium based on TECO EnergyÂ’s unaffected closing stock price on July 15, 2015 the last trading day prior to news reports regarding TECO EnergyÂ’s strategic review and 25 percent above TECO EnergyÂ’s unaffected 52-week high. This represents an aggregate purchase price of approximately US $10.4 billion including assumption of approximately US $3.9 billion of debt.

The closing of the Emera/TECO deal, which is expected to occur by mid-2016, is subject to TECO Energy common shareholder approval and certain regulatory and government approvals, including approval by the New Mexico Public Regulation Commission, the Federal Energy Regulatory Commission and compliance with any applicable requirements under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, and the satisfaction of customary closing conditions.

Highlights:

- EPS accretion expected in the first full year of operations 2017, growing to more than 10 percent by the third full year 2019 - TECO Energy shareholders will receive US$27.55 per share in cash, a 48 percent premium to the unaffected closing share price of July 15, 2015

- The TECO/Emera deal provides additional support to EmeraÂ’s eight percent dividend growth target through 2019 and positions Emera to extend the dividend growth target beyond 2019

- Upon closing, Emera will have approximately US$20 billion in assets, making it a top 20 North American regulated utility

- The acquisition of TECO Energy is an ideal strategic fit for Emera due to its business and generation mix and expanded U.S. presence in constructive regulatory jurisdictions. The acquisition provides Emera with a new platform in growth markets, and further opportunities to supply customers with cleaner generation

- TECO Energy, Tampa Electric, Peoples Gas and New Mexico Gas Co. will maintain existing corporate headquarters in Tampa and Albuquerque

Related News

DOE Announces $28M Award for Wind Energy

DOE Wind Energy Funding backs 13 R&D projects advancing offshore wind, distributed energy, and utility-scale turbines, including microgrids, battery storage, nacelle and blade testing, tall towers, and rural grid integration across the United States.

 

Key Points

DOE Wind Energy Funding is a $28M R&D effort in offshore, distributed, and utility-scale wind to lower cost and risk.

✅ $6M for rural microgrids, storage, and grid integration.

✅ $7M for offshore R&D, nacelle and long-blade testing.

✅ Up to $10M demos; $5M for tall tower technology.

 

The U.S. Department of Energy announced that in order to advance wind energy in the U.S., 13 projects have been selected to receive $28 million. Project topics focus on technology development while covering distributed, offshore wind growth and utility-scale wind found on land.

The selections were announced by the DOE’s Assistant Secretary for the Office of Energy Efficiency and Renewable Energy, Daniel R. Simmons, at the American Wind Energy Association Offshore Windpower Conference in Boston, as New York's offshore project momentum grows nationwide.

 

Wind Project Awards

According to the DOE, four Wind Innovations for Rural Economic Development projects will receive a total of $6 million to go toward supporting rural utilities via facilitating research drawing on U.K. wind lessons for deployment that will allow wind projects to integrate with other distributed energy resources.

These endeavors include:

Bergey WindPower (Norman, Oklahoma) working on developing a standardized distributed wind/battery/generator micro-grid system for rural utilities;

Electric Power Research Institute (Palo Alto, California) working on developing modeling and operations for wind energy and battery storage technologies, as large-scale projects in New York progress, that can both help boost wind energy and facilitate rural grid stability;

Iowa State University (Ames, Iowa) working on optimization models and control algorithms to help rural utilities balance wind and other energy resources; and

The National Rural Electric Cooperative Association (Arlington, Virginia) providing the development of standardized wind engineering options to help rural-area adoption of wind.

Another six projects are to receive a total of $7 million to facilitate research and development in offshore wind, as New York site investigations advance, with these projects including:

Clemson University (North Charleston, South Carolina) improving offshore-scale wind turbine nacelle testing via a “hardware-in-the-loop capability enabling concurrent mechanical, electrical and controller testing on the 7.5-megawatt dynamometer at its Wind Turbine Drivetrain Testing Facility to accelerate 1 GW on the grid progress”; and

The Massachusetts Clean Energy Center (Boston) upgrading its Wind Technology Testing Center to facilitate structural testing of 85- to 120-meter-long (roughly 278- to 393-foot-long) blades, as BOEM lease requests expand, among other projects.

Additionally, two offshore wind technology demonstration projects will receive up to $10 million for developing initiatives connected to reducing wind energy risk and cost. One last project will also be granted $5 million for the development of tall tower technology that can help overcome restrictions associated with transportation.

“These projects will be instrumental in driving down technology costs and increasing consumer options for wind across the United States as part of our comprehensive energy portfolio,” said Simmons.

 

Related News

View more

Power Outages to Mitigate Wildfire Risks

Colorado Wildfire Power Shutoffs reduce ignition risk through PSPS, grid safety protocols, data-driven forecasts, and emergency coordination, protecting communities, natural resources, and infrastructure during extreme fire weather fueled by drought and climate change.

 

Key Points

Planned PSPS outages cut power in high-risk areas to prevent ignitions, protect residents, and boost wildfire resilience.

✅ PSPS triggered by forecasts, fuel moisture, and fire danger indices.

✅ Utilities coordinate alerts, timelines, and critical facility support.

✅ Paired with forest management, education, and rapid response.

 

Colorado, known for its stunning landscapes and outdoor recreation, has implemented proactive measures to reduce the risk of wildfires by strategically shutting off power in high-risk areas, similar to PG&E wildfire shutoffs implemented in California during extreme conditions. This approach, while disruptive, aims to safeguard communities, protect natural resources, and mitigate the devastating impacts of wildfires that have become increasingly prevalent in the region.

The decision to initiate power outages as a preventative measure against wildfires underscores Colorado's commitment to proactive fire management and public safety, aligning with utility disaster planning practices that strengthen grid readiness. With climate change contributing to hotter and drier conditions, the state faces heightened wildfire risks, necessitating innovative strategies to minimize ignition sources and limit fire spread.

Utility companies, in collaboration with state and local authorities, identify areas at high risk of wildfire based on factors such as weather forecasts, fuel moisture levels, and historical fire data. When conditions reach critical thresholds, planned power outages, also known as Public Safety Power Shutoffs (PSPS), are implemented to reduce the likelihood of electrical equipment sparking wildfires during periods of extreme fire danger, particularly during windstorm-driven outages that elevate ignition risks.

While power outages are a necessary precautionary measure, they can pose challenges for residents, businesses, and essential services that rely on uninterrupted electricity, as seen when a North Seattle outage affected thousands last year. To mitigate disruptions, utility companies communicate outage schedules in advance, provide updates during outages, and coordinate with emergency services to ensure the safety and well-being of affected communities.

The implementation of PSPS is part of a broader strategy to enhance wildfire resilience in Colorado. In addition to reducing ignition risks from power lines, the state invests in forest management practices, wildfire prevention education, and emergency response capabilities, including continuity planning seen in the U.S. grid COVID-19 response, to prepare for and respond to wildfires effectively.

Furthermore, Colorado's approach to wildfire prevention highlights the importance of community preparedness and collaboration, and utilities across the region adopt measures like FortisAlberta precautions to sustain critical services during emergencies. Residents are encouraged to create defensible space around their properties, develop emergency evacuation plans, and stay informed about wildfire risks and response protocols. Community engagement plays a crucial role in building resilience and fostering a collective effort to protect lives, property, and natural habitats from wildfires.

The effectiveness of Colorado's proactive measures in mitigating wildfire risks relies on a balanced approach that considers both short-term safety measures and long-term fire prevention strategies. By integrating technology, data-driven decision-making, and community partnerships, the state aims to reduce the frequency and severity of wildfires while enhancing overall resilience to wildfire impacts.

Looking ahead, Colorado continues to refine its wildfire management practices in response to evolving environmental conditions and community needs, drawing on examples of localized readiness such as PG&E winter storm preparation to inform response planning. This includes ongoing investments in fire detection and monitoring systems, research into fire behavior and prevention strategies, and collaboration with neighboring states and federal agencies to coordinate wildfire response efforts.

In conclusion, Colorado's decision to implement power outages as a preventative measure against wildfires demonstrates proactive leadership in wildfire risk reduction and public safety. By prioritizing early intervention and community engagement, the state strives to safeguard vulnerable areas, minimize the impact of wildfires, and foster resilience in the face of increasing wildfire threats. As Colorado continues to innovate and adapt its wildfire management strategies, its efforts serve as a model for other regions grappling with the challenges posed by climate change and wildfire risks.

 

Related News

View more

$550 Million in Clean Energy Funding to Benefit More than 250 Million Americans

EECBG Program Funding empowers states, Tribes, and local governments with DOE grants to deploy clean energy, energy efficiency, EV infrastructure, and community solar, cutting emissions, lowering utility bills, and advancing net-zero decarbonization.

 

Key Points

EECBG Program Funding is a $550M DOE grant for states, Tribes, and governments to deploy clean energy and efficiency.

✅ Supports EV infrastructure and community solar deployment

✅ Cuts emissions and lowers utility costs via efficiency

✅ Prioritizes Justice40 benefits for underserved communities

 

The Biden-Harris Administration, through the U.S. Department of Energy (DOE), today released a Notice of Intent announcing $550 million to support community-based clean energy in state, Tribal, and local governments — serving more than 250 million Americans. This investment in American communities, through the Energy Efficiency and Conservation Block Grant (EECBG) Program, will support communities across the country to develop local programming and deploy clean energy technologies to cut emissions, advance a 90% carbon-free electricity goal nationwide, and reduce consumers’ energy costs, and help meet President Biden’s goal of a net-zero economy by 2050. 

“This funding is a streamlined and flexible tool for local governments to build their electricity future with clean energy,” said U.S. Secretary of Energy Jennifer M. Granholm. “State, local, and Tribal communities nationwide will be able to leverage this funding to drive greater energy efficiency and conservation practices to lower utility bills and create healthier environments for American families.”   

The EECBG Program will fund 50 states, five U.S. territories, the District of Columbia, 774 Tribes, and 1,878 local governments in a variety of capacity-building, planning, and infrastructure efforts to reduce carbon emissions and energy use and improve energy efficiency in the transportation, building, and other related sectors. For example, communities with this funding can build out electric vehicle infrastructure and deploy community solar to serve areas that otherwise do not have access to electric vehicles or clean energy, particularly through a rural energy security program where appropriate.  

The $550 million made available through the Bipartisan Infrastructure Law (BIL) represents the second time that the EECBG Program has been funded, the first of which was through the American Recovery and Reinvestment Act of 2009. With this most recent funding, communities can build on prior investments and leverage additional clean energy funding from DOE, other federal agencies, and the private sector to achieve sustained impacts, supported by a Clean Electricity Standard where applicable, that can put their communities on a pathway to decarbonization. 

Through the EECBG Program and the Office of State and Community Energy Programs (SCEP), DOE will support the many diverse state, local, and tribal communities across the U.S., including efforts to revitalize coal communities through clean energy, as they implement this funding and other clean energy projects. To ensure no communities are left behind, the program aligns with President’s Justice40 initiative and efforts toward equity in electricity regulation to help ensure that 40% of the overall benefits of clean energy investments go to underserved and overburdened communities. 

 

Related News

View more

Lump sum credit on electricity bills as soon as July

NL Hydro electricity credit delivers a one-time on-bill rebate from the rate stabilization fund, linked to oil prices and the Holyrood plant, via the Public Utilities Board, with payment deferrals and interest relief for customers.

 

Key Points

A one-time on-bill credit from the rate stabilization fund to cut power costs as oil prices remain low.

✅ One-time on-bill credit via the Public Utilities Board

✅ Funded by surplus in the rate stabilization fund

✅ Deferrals and 15 months interest assistance available

 

Most people who pay electricity bills will get a one-time credit as early as July.

The provincial government on Thursday outlined a new directive to the Public Utilities Board to provide a one-time credit for customers whose electricity rates are affected by the price of oil, part of an effort to shield ratepayers from Muskrat Falls overruns through recent agreements.

Electricity customers who are not a part of the Labrador interconnected system, including those using diesel on the north coast of Labrador, will receive the credit.

The credit, announced at a press conference Thursday morning, will come from the rate stabilization fund and comes as many customers have begun paying for Muskrat Falls on their bills, which has an estimated surplus of about $50 million because low oil prices mean NL Hydro has spent less on fuel for the Holyrood thermal generating station.

Normally a surplus would be paid out over a year, but customers this year will get the credit in a lump sum, as early as July, with the amount varying based on electricity usage.

"Given the difficult times many are finding themselves in, we believe an upfront, one-time on-bill credit would be much more helpful for customers than a small monthly decrease over the next 12 months," said Natural Resources Minister Siobhan Coady at the provincial government's announcement Thursday morning.

Premier Dwight Ball said with many households and businesses experiencing financial hardship, the one-time credit is meant to make life a little easier, noting that Nova Scotia's premier has urged regulators to reject a major hike elsewhere.

"We have requested that the board of commissioners of the Public Utilities Board, even as Nova Scotia's regulator approved a 14% increase recently, adopt a policy so that a credit will be dispersed immediately," Ball said.

"This is to help people when they need it the most.… We're doing what we can to support you."

The provincial government estimates someone whose power costs an average of $200 a month would get a one-time credit of about $130. Details of the plan will be left to the PUB.

Deferred payments allowed
Ball said the credit will make a "significant impact" on customers' July bills.

Both businesses and residential customers will also be able to defer payments, similar to Alberta's deferral program that shifted costs for unpaid bills, with up to $2.5 million in interest being waived on overdue accounts. Customers will be required to make agreed-upon monthly payments to their account, and there will be interest assistance for 15 months, beginning June 1.

Coady said customers can renegotiate their bills and defer payments, with the province picking up the tab for the interest.

"You can speak to a customer service agent and they will make accommodations, but you have to continue to make some version of a monthly payment," Coady

"The interest that may be accrued is going to be paid for by the provincial government, so if you're a business, a person, and you're having difficulty and you can't make what I would say is your normal payment, call your utility, make some arrangements."

Labrador's interconnected grid isn't affected by the price of oil, but those customers can take advantage of the interest relief.

Relief policies already put in place during the pandemic, like not disconnecting customers and providing options for more flexible bill payments, will continue, as utilities such as Hydro One reconnecting customers demonstrate in Ontario.

Credit not enough to support customers: PCs
While Ball said his government is doing what they can to help ratepayers, the opposition doesn't believe the announcement does enough to support those who need it.

Tony Wakeham, the Progressive Conservative MHA for Stephenville-Port au Port, said in a statement Thursday the credit simply gives people's money back to them, after the NL Consumer Advocate called an 18% rate hike unacceptable, and Newfoundland Power stands to benefit. 

"The Liberal government would like ratepayers to believe that they are getting electricity rate relief, but in reality, customers would have been entitled to receive the value of this credit anyway over a 12-month period. Furthermore, in providing a one-time credit, Newfoundland Power will also be able to collect an administrative fee, adding to their revenues," Wakeham said in the statement.

"People and businesses in this province are struggling to pay their utility bills, and the Liberal government should help them by putting extra money into their pockets, not by recycling an already existing program to the benefit of a large corporation."

Wakeham called on government to direct the PUB to lower Newfoundland Power's guaranteed rate of return to give cash refunds to customers, and for Newfoundland Power to waive its fees.

 

Related News

View more

Calgary's electricity use soars in frigid February, Enmax says

Calgary Winter Energy Usage Surge highlights soaring electricity demand, added megawatt-hours, and grid reliability challenges driven by extreme cold, heating loads, and climate change, with summer air conditioning also shifting seasonal peaks.

 

Key Points

A spike in Calgary's power use from extreme cold, adding 22k MWh and testing reliability as heating demand rises.

✅ +22,000 MWh vs Feb 2018 amid fourth-coldest February

✅ Heating loads spike; summer A/C now drives peak demand

✅ Grid reliability monitored; more solar and green resources ahead

 

February was so cold in Calgary that the city used enough extra energy to power 3,400 homes for a whole year, echoing record-breaking demand in B.C. in 2021 during severe cold.

Enmax Power Corporation, the primary electricity utility in the city, says the city 's energy consumption was up 22,000 megawatt hours last month compared with Februray 2018.

"We've seen through this cold period our system has held up very well. It's been very reliable," Enmax vice-president Andre van Dijk told the Calgary Eyeopener on Friday. "You know, in the absence of a windstorm combined with cold temperatures and that sort of thing, the system has actually held up pretty well."

The past month was the fourth coldest in Calgary's history, and similar conditions have pushed all-time high demand in B.C. in recent years across the West. The average temperature for last month was –18.1 C. The long-term average for February is –5.4 C.

 

Watching use, predicting issues

The electricity company monitors demand and load on a daily basis, always trying to predict issues before they happen, van Dijk said, and utilities have introduced winter payment plans to help customers manage bills during prolonged cold.

One of the issues they're watching is climate change, and how extreme temperatures and weather affect both the grid's reliability, as seen when Quebec shattered consumption records during cold snaps, and the public's energy use.

The colder it gets, the higher you turn up the heat. The hotter it is, the more you use air conditioning.

He also noted that using fuels then contributes to climate change, creating a cycle.

​"We are seeing variations in temperature and we've seen large weather events across the continent, across the world, in fact, that impact electrical systems, whether that's flooding, as we've experienced here, or high winds, tornadoes," van Dijk said.

"Climate change and changing weather patterns have definitely had had an impact on us as an electrical industry."

In 2012, he said, Calgary switched from using the most power during winter to using the most during summer, in large part due to air conditioning, he said.

"Temperature is a strong influencer of energy consumption and of our demand," van Dijk said.

Christmas tree lights have also become primarily LED, van Dijk said, which cuts down on a big energy draw in the winter.

He said he expects more solar and other green resources will be added into the electrical system in the future to mitigate how much the increasingly levels of energy use impact climate change, and to help moderate electricity costs in Alberta over time.

 

Related News

View more

BC announces grid development, job creation

BC Hydro Power Pathway accelerates electrification with clean energy investments, new transmission lines, upgraded substations, and renewable projects like wind and solar, strengthening the grid, supporting decarbonization, and creating jobs across British Columbia's growing economy.

 

Key Points

A $36B, 10-year BC Hydro plan to expand clean power infrastructure, accelerate electrification, and support jobs.

✅ $36B for new lines, substations, dam upgrades, and distribution

✅ Supports 10,500-12,500 jobs per year across B.C.

✅ Adds wind and solar, leveraging hydro to balance renewables

 

BC Hydro is gearing up for a decade of extensive construction to enhance British Columbia's electrical system, supporting a burgeoning clean economy and community growth while generating new employment opportunities.

Premier David Eby emphasized the necessity of expanding the electrical system for industrial growth, residential needs, and future advancements. He highlighted the role of clean, affordable energy in reducing pollution, securing well-paying jobs, and fostering economic growth.

At the B.C. Natural Resources Forum in Prince George, Premier Eby unveiled a $36-billion investment plan for infrastructure projects in communities and regions and green energy solutions to provide clean, affordable electricity for future generations.

The Power Pathway: Building BC’s Energy Future, BC Hydro’s revised 10-year capital plan, involves nearly $36 billion in investments across the province from 2024-25 to 2033-34. This marks a 50% increase from the previous plan of $24 billion and includes a substantial rise in electrification and emissions-reduction projects (nearly $10 billion, up from $1 billion).

These upcoming construction projects are expected to support approximately 10,500 to 12,500 jobs annually. The plan is set to bolster and sustain BC Hydro’s capital investments as significant projects like Site C are near completion.

The plan addresses the increasing demand for electricity due to population and housing growth, industrial development, such as a major hydrogen project, and the transition from fossil fuels to clean electricity. Key projects include constructing new high-voltage transmission lines from Prince George to Terrace, building or expanding substations in high-growth areas, and upgrading dams and generating facilities for enhanced safety and efficiency.

Minister of Energy, Mines, and Low Carbon Innovation Josie Osborne stated that this plan aims to build a clean energy future and support EV charging expansion while creating construction jobs. With BC Hydro’s capital plan allocating almost $4 billion annually for the next decade, it will drive economic growth and ensure access to clean, affordable electricity.

BC Hydro aims to add new clean, renewable energy sources like wind and solar, while acknowledging power supply challenges that must be managed as capacity grows. B.C.’s hydroelectric dams, functioning as batteries, enable the integration of intermittent renewables into the grid, providing reliable backup.

Chris O’Riley, president and CEO of BC Hydro, said the grid is one of the world’s cleanest. The new $36 billion capital plan encompasses investments in generation assets, large transmission infrastructure, and local distribution networks.

In partnership with BC Hydro, Premier Eby also announced a new streamlined approval process to expedite electrification for high-demand industries and support job creation, complementing measures like the BC Hydro rebate and B.C. Affordability Credit that help households.

Minister of Environment and Climate Change Strategy George Heyman highlighted the importance of rapid electrification in collaboration with the private sector to achieve CleanBC climate goals by 2030, including corridor charging via the BC's Electric Highway, and maintain the competitiveness of B.C. industries. The new process will streamline approvals for industrial electrification projects, enhancing efficiency and funding certainty.

 

Related News

View more

Sign Up for Electricity Forum’s Newsletter

Stay informed with our FREE Newsletter — get the latest news, breakthrough technologies, and expert insights, delivered straight to your inbox.

Electricity Today T&D Magazine Subscribe for FREE

Stay informed with the latest T&D policies and technologies.
  • Timely insights from industry experts
  • Practical solutions T&D engineers
  • Free access to every issue

Live Online & In-person Group Training

Advantages To Instructor-Led Training – Instructor-Led Course, Customized Training, Multiple Locations, Economical, CEU Credits, Course Discounts.

Request For Quotation

Whether you would prefer Live Online or In-Person instruction, our electrical training courses can be tailored to meet your company's specific requirements and delivered to your employees in one location or at various locations.