Cliffside power plant construction draws more discussion

By The Shelby Star


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Welchel Road resident Roger Hollis said his backyard sounds like a train riding through it every morning.

He's hearing noise from construction at Duke Energy's Cliffside steam station. Once construction is complete — probably in 2012 — the company plans to shut down four units that were built in the 1940s.

A handful of people stood in a small area on Duke Power Road to protest the coal-fired plant and construction.

"It's a symbolic gesture," said Abby Gage, one of the organizers.

Gage is a farmer from Madison County and brought along her son, Alexander, 7, for the protest.

"The cost of building a coal-fired power plant is going up," she said. "The cost of solar wind power is going down."

Protests are nothing new at the Cliffside location, with arrests happening on the property in the past when protestors chained themselves to equipment.

Earlier, environmentalist groups joined together for a march at Duke Energy's Charlotte headquarters.

Hollis was not involved in the protest, but stopped by to share his support.

"I feel like the people living here are being done a total injustice," he said. "They just say what they are not going to do."

Joyce Norman, who lives nearby, said she doesn't have a problem with the plant or construction. She has lived in her home on Duke Power Road for more than 50 years.

"Whether it's coal or electric, we have to have power," she said.

Bill Conner, who lives about five miles away, is also in favor of the plant. "We always used coal before and never hurt us before," he said. "You don't have enough wind to keep things turning."

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Canada Invests Over $960-Million in Renewable Energy and Grid Modernization Projects

Smart Renewables and Electrification Pathways Program enables clean energy and grid modernization across Canada, funding wind, solar, hydro, geothermal, tidal, and storage to cut GHG emissions and accelerate electrification toward a net-zero economy.

 

Key Points

A $964M Canadian program funding clean power and grid upgrades to cut emissions and build net-zero electrified economy.

✅ Funds wind, solar, hydro, geothermal, tidal, and storage projects

✅ Modernizes grids for reliability, digitalization, and resilience

✅ Supports net-zero by 2050 with Indigenous and utility partners

 

Harnessing Canada's immense clean energy resources requires transformational investments to modernize our electricity grid. The Government of Canada is investing in renewable energy and upgrading the electricity grid, moving toward an electric, connected and clean economy, to make clean, affordable electricity options more accessible in communities across Canada.

The Honourable Seamus O'Regan Jr., Minister of Natural Resources, today launched a $964-million program, alongside a recent federal green electricity contract in Alberta that underscores momentum, to support smart renewable energy and grid modernization projects that will lower emissions by investing in clean energy technologies, like wind, solar, storage, hydro, geothermal and tidal energy across Atlantic Canada.

The Smart Renewables and Electrification Pathways Program (SREPs) supports building Canada's low-emissions energy future and a renewable, electrified economy through projects that focus on non-emitting, cleaner energy technologies, such as storage, and modernizing electricity system operations.

Investing in these technologies reduces greenhouse gas emissions by creating a cleaner, more connected electrical system, supporting progress toward zero-emissions electricity by 2035 goals, while helping Canada reach net-zero emissions by 2050.

Minister O'Regan launched the program during the Canadian Electricity Association's (CEA) virtual regulatory forum on Electricity Regulation & the Four Disruptors – Decarbonization, Decentralization, Digitalization and Democratization, highlighting evolving regulatory approaches as B.C. streamlines clean energy approvals to support deployment nationwide. The launch also coincides with Canadian Environment Week, which celebrates Canada's environmental accomplishments and encourages Canadians to contribute to conserving and protecting the environment.

Through SREPs and other programming, the government is working with provinces and territories, with the Prairie Provinces leading renewable growth in the years ahead, utilities, Indigenous partners and others, including diverse businesses and communities, to deliver these clean and reliable energy initiatives. With Canadian innovation, technology and skilled energy workers, we can provide more communities, households and businesses with an increased supply of clean electricity and a cleaner electrical grid.

To help interested stakeholders find information on SREPs, a new webpage has been launched, which includes a comprehensive guide for eligible projects.

This supports Canada's strengthened climate plan, A Healthy Environment and a Healthy Economy. Canada is advancing projects that support the clean grid of the future and seize opportunities in the global electricity market to boost competitiveness. Collectively with investments from the Fall Economic Statement 2020 and Budget 2021, Canada will achieve our climate change commitments and ensure a healthier environment and more prosperous economy for future generations.

 

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Duke Energy reaffirms capital investments in renewables and grid projects to deliver cleaner energy, economic growth

Duke Energy Clean Energy Strategy advances renewables, battery storage, grid modernization, and energy efficiency to cut carbon, retire coal, and target net-zero by 2050 across the Carolinas with robust IRPs and capital investments.

 

Key Points

Plan to expand renewables, storage, and grid upgrades to cut carbon and reach net-zero electricity by 2050.

✅ 56B investment in renewables, storage, and grid modernization

✅ Targets 50% carbon reduction by 2030 and net-zero by 2050

✅ Retires coal units; expands energy efficiency and IRPs

 

Duke Energy says that the company will continue advancing its ambitious clean energy goals without the Atlantic Coast Pipeline (ACP) by investing in renewables, battery storage, energy efficiency programs and grid projects that support U.S. electrification efforts.

Duke Energy, the nation's largest electric utility, unveils its new logo. (PRNewsFoto/Duke Energy) (PRNewsfoto/Duke Energy)

Duke Energy's $56 billion capital investment plan will deliver significant customer benefits and create jobs at a time when policymakers at all levels are looking for ways to rebuild the economy in 2020 and beyond. These investments will deliver cleaner energy for customers and communities while enhancing the energy grid to provide greater reliability and resiliency.

"Sustainability and the reduction of carbon emissions are closely tied to our region's success," said Lynn Good, Duke Energy Chair, President and CEO. "In our recent Climate Report, we shared a vision of a cleaner electricity future with an increasing focus on renewables and battery storage in addition to a diverse mix of zero-carbon nuclear, natural gas, hydro and energy efficiency programs.

"Achieving this clean energy vision will require all of us working together to develop a plan that is smart, equitable and ensures the reliability and affordability that will spur economic growth in the region. While we're disappointed that we're not able to move forward with ACP, we will continue exploring ways to help our customers and communities, particularly in eastern North Carolina where the need is great," said Good.

Already a clean-energy leader, Duke Energy has reduced its carbon emissions by 39% from 2005 and remains on track to cut its carbon emissions by at least 50% by 2030, as peers like Alliant's carbon-neutral plan demonstrate broader industry momentum toward decarbonization. The company also has an ambitious clean energy goal of reaching net-zero emissions from electricity generation by 2050. 

In September 2020, Duke Energy plans to file its Integrated Resource Plans (IRP) for the Carolinas after an extensive process of working with the state's leaders, policymakers, customers and other stakeholders. The IRPs will include multiple scenarios to support a path to a cleaner energy future in the Carolinas, reflecting key utility trends shaping resource planning.

Since 2010, Duke Energy has retired 51 coal units totaling more than 6,500 megawatts (MW) and plans to retire at least an additional 900 MW by the end of 2024. In 2019, the company proposed to shorten the book lives of another approximately 7,700 MW of coal capacity in North Carolina and Indiana.

Duke Energy will host an analyst call in early August 2020 to discuss second quarter 2020 financial results and other business and financial updates. The company will also host its inaugural Environmental, Social and Governance (ESG) investor day in October 2020.

 

Duke Energy

Duke Energy is transforming its customers' experience, modernizing the energy grid, generating cleaner energy and expanding natural gas infrastructure to create a smarter energy future for the people and communities it serves. The Electric Utilities and Infrastructure unit's regulated utilities serve 7.8 million retail electric customers in six states: North Carolina, South Carolina, Florida, Indiana, Ohio and Kentucky. The Gas Utilities and Infrastructure unit distributes natural gas to 1.6 million customers in five states: North Carolina, South Carolina, Tennessee, Ohio and Kentucky. The Duke Energy Renewables unit operates wind and solar generation facilities across the U.S., as well as energy storage and microgrid projects.

Duke Energy was named to Fortune's 2020 "World's Most Admired Companies" list and Forbes' "America's Best Employers" list. More information about the company is available at duke-energy.com. The Duke Energy News Center contains news releases, fact sheets, photos, videos and other materials. Duke Energy's illumination features stories about people, innovations, community topics and environmental issues. Follow Duke Energy on Twitter, LinkedIn, Instagram and Facebook.

 

Forward-Looking Information

This document includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward-looking statements are based on management's beliefs and assumptions and can often be identified by terms and phrases that include "anticipate," "believe," "intend," "estimate," "expect," "continue," "should," "could," "may," "plan," "project," "predict," "will," "potential," "forecast," "target," "guidance," "outlook" or other similar terminology. Various factors may cause actual results to be materially different than the suggested outcomes within forward-looking statements; accordingly, there is no assurance that such results will be realized. These factors include, but are not limited to:

  • The impact of the COVID-19 electricity demand shift on operations and revenues;
  • State, federal and foreign legislative and regulatory initiatives, including costs of compliance with existing and future environmental requirements, including those related to climate change, as well as rulings that affect cost and investment recovery or have an impact on rate structures or market prices;
  • The extent and timing of costs and liabilities to comply with federal and state laws, regulations and legal requirements related to coal ash remediation, including amounts for required closure of certain ash impoundments, are uncertain and difficult to estimate;
  • The ability to recover eligible costs, including amounts associated with coal ash impoundment retirement obligations and costs related to significant weather events, and to earn an adequate return on investment through rate case proceedings and the regulatory process;
  • The costs of decommissioning nuclear facilities could prove to be more extensive than amounts estimated and all costs may not be fully recoverable through the regulatory process;
  • Costs and effects of legal and administrative proceedings, settlements, investigations and claims;
  • Industrial, commercial and residential growth or decline in service territories or customer bases resulting from sustained downturns of the economy and the economic health of our service territories or variations in customer usage patterns, including energy efficiency and demand response efforts and use of alternative energy sources, such as self-generation and distributed generation technologies;
  • Federal and state regulations, laws and other efforts designed to promote and expand the use of energy efficiency measures and distributed generation technologies, such as private solar and battery storage, in Duke Energy service territories could result in customers leaving the electric distribution system, excess generation resources as well as stranded costs;
  • Advancements in technology;
  • Additional competition in electric and natural gas markets and continued industry consolidation;
  • The influence of weather and other natural phenomena on operations, including the economic, operational and other effects of severe storms, hurricanes, droughts, earthquakes and tornadoes, including extreme weather associated with climate change;
  • The ability to successfully operate electric generating facilities and deliver electricity to customers including direct or indirect effects to the company resulting from an incident that affects the U.S. electric grid or generating resources;
  • The ability to obtain the necessary permits and approvals and to complete necessary or desirable pipeline expansion or infrastructure projects in our natural gas business;
  • Operational interruptions to our natural gas distribution and transmission activities;
  • The availability of adequate interstate pipeline transportation capacity and natural gas supply;
  • The impact on facilities and business from a terrorist attack, cybersecurity threats, data security breaches, operational accidents, information technology failures or other catastrophic events, such as fires, explosions, pandemic health events or other similar occurrences;
  • The inherent risks associated with the operation of nuclear facilities, including environmental, health, safety, regulatory and financial risks, including the financial stability of third-party service providers;
  • The timing and extent of changes in commodity prices and interest rates and the ability to recover such costs through the regulatory process, where appropriate, and their impact on liquidity positions and the value of underlying assets;
  • The results of financing efforts, including the ability to obtain financing on favorable terms, which can be affected by various factors, including credit ratings, interest rate fluctuations, compliance with debt covenants and conditions and general market and economic conditions;
  • Credit ratings of the Duke Energy Registrants may be different from what is expected;
  • Declines in the market prices of equity and fixed-income securities and resultant cash funding requirements for defined benefit pension plans, other post-retirement benefit plans and nuclear decommissioning trust funds;
  • Construction and development risks associated with the completion of the Duke Energy Registrants' capital investment projects, including risks related to financing, obtaining and complying with terms of permits, meeting construction budgets and schedules and satisfying operating and environmental performance standards, as well as the ability to recover costs from customers in a timely manner, or at all;
  • Changes in rules for regional transmission organizations, including FERC debates on coal and nuclear subsidies and new and evolving capacity markets, and risks related to obligations created by the default of other participants;
  • The ability to control operation and maintenance costs;
  • The level of creditworthiness of counterparties to transactions;
  • The ability to obtain adequate insurance at acceptable costs;
  • Employee workforce factors, including the potential inability to attract and retain key personnel;
  • The ability of subsidiaries to pay dividends or distributions to Duke Energy Corporation holding company (the Parent);
  • The performance of projects undertaken by our nonregulated businesses and the success of efforts to invest in and develop new opportunities;
  • The effect of accounting pronouncements issued periodically by accounting standard-setting bodies;
  • The impact of U.S. tax legislation to our financial condition, results of operations or cash flows and our credit ratings;
  • The impacts from potential impairments of goodwill or equity method investment carrying values; and
  • The ability to implement our business strategy, including enhancing existing technology systems.
  • Additional risks and uncertainties are identified and discussed in the Duke Energy Registrants' reports filed with the SEC and available at the SEC's website at sec.gov. In light of these risks, uncertainties and assumptions, the events described in the forward-looking statements might not occur or might occur to a different extent or at a different time than described. Forward-looking statements speak only as of the date they are made and the Duke Energy Registrants expressly disclaim an obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

 

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Nord Stream: Norway and Denmark tighten energy infrastructure security after gas pipeline 'attack'

Nord Stream Pipeline Sabotage triggers Baltic Sea gas leaks as Norway and Denmark tighten energy infrastructure security, offshore surveillance, and exclusion zones, after drone sightings near platforms and explosions reported by experts.

 

Key Points

An alleged attack causing Baltic gas leaks and heightened energy security measures in Norway and Denmark.

✅ Norway boosts offshore and onshore site security

✅ Denmark enforces 5 nm exclusion zone near leaks

✅ Drones spotted; police probe sabotage and safety breaches

 

Norway and Denmark will increase security and surveillance around their energy infrastructure sites after the alleged sabotage of Russia's Nord Stream gas pipeline in the Baltic Sea, as the EU pursues a plan to dump Russian energy to safeguard supplies. 

Major leaks struck two underwater natural gas pipelines running from Russia to Germany, which has moved to a 200 billion-euro energy shield amid surging prices, with experts reporting that explosions rattled the Baltic Sea beforehand.

Norway -- an oil-rich nation and Europe's biggest supplier of gas -- will strengthen security at its land and offshore installations, even as it weighs curbing electricity exports to avoid shortages, the country's energy minister said.

The Scandinavian country's Petroleum Safety Authority also urged vigilance on Monday after unidentified drones were seen flying near Norway's offshore oil and gas platforms.

"The PSA has received a number of warnings/notifications from operator companies on the Norwegian Continental Shelf concerning the observation of unidentified drones/aircraft close to offshore facilities" the agency said in a statement.

"Cases where drones have infringed the safety zone around facilities are now being investigated by the Norwegian police."

Meanwhile Denmark will increase security across its energy sector after the Nord Stream incident, as wider market strains, including Germany's struggling local utilities, ripple across Europe, a spokesperson for gas transmission operator Energinet told Upstream.

The Danish Maritime Agency has also imposed an exclusion zone for five nautical miles around the leaks, warning ships of a danger they could lose buoyancy, and stating there is a risk of the escaping gas igniting "above the water and in the air," even as Europe weighs emergency electricity measures to limit prices.

Denmark's defence minister said there was no cause for security concerns in the Baltic Sea region.

"Russia has a significant military presence in the Baltic Sea region and we expect them to continue their sabre-rattling," Morten Bodskov said in a statement.

Video taken by a Danish military plane on Tuesday afternoon showed the extent of one of gas pipeline leaks, with the surface of the Baltic bubbling up as gas escapes, highlighting Europe's energy crisis for global audiences:

Meanwhile police in Sweden have opened a criminal investigation into "gross sabotage" of the Nord Stream 1 and Nord Stream 2 pipelines, and Sweden's crisis management unit was activated to monitor the situation. The unit brings together representatives from different government agencies. 

Swedish Foreign Minister Ann Linde had a call with her Danish counterpart Jeppe Kofod on Tuesday evening, and the pair also spoke with Norwegian Foreign Minister Anniken Huitfeldt on Wednesday, as the bloc debates gas price cap strategies to address the crisis, with Kofod saying there should be a "clear and unambiguous EU statement about the explosions in the Baltic Sea." 

"Focus now on uncovering exactly what has happened - and why. Any sabotage against European energy infrastructure will be met with a robust and coordinated response," said Kofod. 

 

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7 steps to make electricity systems more resilient to climate risks

Electricity System Climate Resilience underpins grid reliability amid heatwaves and drought, integrating solar, wind, hydropower, nuclear, storage, and demand response with efficient transmission, flexibility, and planning to secure power for homes, industry, and services.

 

Key Points

Power systems capacity to endure extreme weather and integrate clean energy, maintaining reliability and flexibility.

✅ Grid hardening, transmission upgrades, and digital forecasting.

✅ Flexible low-carbon supply: hydropower, nuclear, storage.

✅ Demand response, efficient cooling, and regional integration.

 

Summer is just half done in the northern hemisphere and yet we are already seeing electricity systems around the world struggling to cope with the severe strain of heatwaves and low rainfall.

These challenges highlight the urgent need for strong and well-planned policies and investments to improve the security of our electricity systems, which supply power to homes, offices, factories, hospitals, schools and other fundamental parts of our economies and societies. This means making our electricity systems more resilient to the effects of global warming – and more efficient and flexible as they incorporate rising levels of solar and wind power, as solar is now the cheapest electricity in history according to the IEA, which will be critical for reaching net-zero emissions in time to prevent even worse impacts from climate change.

A range of different countries, including the US, Canada and Iraq, have been hard hit by extreme weather recently in the form of unusually high temperatures. In North America, the heat soared to record levels in the Pacific Northwest. An electricity watchdog says that five US regions face elevated risks to the security of their electricity supplies this summer, underscoring US grid climate risks that could worsen, and that California’s risk level is even higher.

Heatwaves put pressure on electricity systems in multiple ways. They increase demand as people turn up air conditioning, driving higher US electricity bills for many households, and as some appliances work harder to maintain cool temperatures. At the same time, higher temperatures can also squeeze electricity supplies by reducing the efficiency and capacity of traditional thermal power plants, such as coal, natural gas and nuclear. Extreme heat can reduce the availability of water for cooling plants or transporting fuel, forcing operators to reduce their output. In some cases, it can result in power plants having to shut down, increasing the risk of outages. If the heat wave is spread over a wide geographic area, it also reduces the scope for one region to draw on spare capacity from its neighbours, since they have to devote their available resources to meeting local demand.

A recent heatwave in Texas forced the grid operator to call for customers to raise their thermostats’ temperatures to conserve energy. Power generating companies suffered outages at much higher rates than expected, providing an unwelcome reminder of February’s brutal cold snap when outages – primarily from natural gas power plants – left up to 5 million customers across the US without power over a period of four days.

At the same time, lower than average rainfall and prolonged dry weather conditions are raising concerns about hydropower’s electricity output in various parts of the world, including Brazil, China, India and North America. The risks that climate change brings in the form of droughts adds to the challenges faced by hydropower, the world’s largest source of clean electricity, highlighting the importance of developing hydropower resources sustainably and ensuring projects are climate resilient.

The recent spate of heatwaves and unusually long dry spells are fresh warnings of what lies ahead as our climate continues to heat up: an increase in the scale and frequency of extreme weather events, which will cause greater impacts and strains on our energy infrastructure.

Heatwaves will increase the challenge of meeting electricity demand while also decarbonizing the electricity supply. Today, the amount of energy used for cooling spaces – such as homes, shops, offices and factories – is responsible for around 1 billion tonnes of global CO2 emissions. In particular, energy for cooling can have a major impact on peak periods of electricity demand, intensifying the stress on the system. Since the energy demand used for air conditioners worldwide could triple by 2050, these strains are set to grow unless governments introduce stronger policy measures to improve the energy efficiency of air conditioning units.

Electricity security is crucial for smooth energy transitions
Many countries around the world have announced ambitious targets for reaching net-zero emissions by the middle of this century and are seeking to step up their clean energy transitions. The IEA’s recent Global Roadmap to Net Zero by 2050 makes it clear that achieving this formidable goal will require much more electricity, much cleaner electricity and for that electricity to be used in far more parts of our economies than it is today. This means electricity reaching much deeper into sectors such as transport (e.g. EVs), buildings (e.g. heat-pumps) and industry (e.g. electric-arc steel furnaces), and in countries like New Zealand's electrification plans it is accelerating broader efforts. As clean electricity’s role in the economy expands and that of fossil fuels declines, secure supplies of electricity become ever-more important. This is why the climate resilience of the electricity sector must be a top priority in governments’ policy agendas.

Changing climate patterns and more frequent extreme weather events can hit all types of power generation sources. Hydropower resources typically suffer in hot and dry conditions, but so do nuclear and fossil fuel power plants. These sources currently help ensure electricity systems have the flexibility and capacity to integrate rising shares of solar and wind power, whose output can vary depending on the weather and the time of day or year.

As governments and utilities pursue the decarbonization of electricity systems, mainly through growing levels of solar and wind, and carbon-free electricity options, they need to ensure they have sufficiently robust and diverse sources of flexibility to ensure secure supplies, including in the event of extreme weather events. This means that the possible decommissioning of existing power generation assets requires careful assessments that take into account the importance of climate resilience.

Ensuring electricity security requires long-term planning and stronger policy action and investment
The IEA is committed to helping governments make well-informed decisions as they seek to build a clean and secure energy future. With this in mind, here are seven areas for action for ensuring electricity systems are as resilient as possible to climate risks:

1. Invest in electricity grids to make them more resilient to extreme weather. Spending today is far below the levels needed to double the investment for cleaner, more electrified energy systems, particularly in emerging and developing economies. Economic recovery plans from the COVID-19 crisis offer clear opportunities for economies that have the resources to invest in enhancing grid infrastructure, but much greater international efforts are required to mobilize and channel the necessary spending in emerging and developing economies.

2. Improve the efficiency of cooling equipment. Cost-effective technology already exists in most markets to double or triple the efficiency of cooling equipment. Investing in higher efficiency could halve future energy demand and reduce investment and operating costs by $3 trillion between now and 2050. In advance of COP26, the Super-Efficient Equipment and Appliance Deployment (SEAD) initiative is encouraging countries to sign up to double the energy efficiency of equipment sold in their countries by 2030.

3. Enable the growth of flexible low-carbon power sources to support more solar and wind. These electricity generation sources include hydropower and nuclear, for countries who see a role for one or both of them in their energy transitions. Guaranteeing hydropower resilience in a warming climate will require sophisticated methods and tools – such as the ones implemented in Brazil – to calculate the necessary level of reserves and optimize management of reservoirs and hydropower output even in exceptional conditions. Batteries and other forms of storage, combined with solar or wind, can also provide important amounts of flexibility by storing power and releasing it when needed.

4. Increase other sources of electricity system flexibility. Demand-response and digital technologies can play an important role. The IEA estimates that only a small fraction of the huge potential for demand response in the buildings sector is actually tapped at the moment. New policies, which associate digitalization and financial behavioural incentives, could unlock more flexibility. Regional integration of electricity systems across national borders can also increase access to flexible resources.

5. Expedite the development and deployment of new technologies for managing extreme weather threats. The capabilities of electricity utilities in forecasting and situation awareness should be enhanced with the support of the latest information and communication technologies.

6. Make climate resilience a central part of policy-making and system planning. The interconnected nature of recent extreme weather events reminds us that we need to account for many contingencies when planning resilient power systems. Climate resilience should be integral to policy-making by governments and power system planning by utilities and relevant industries, and debates over Canadian climate policy underscore how grid implications must be considered. According to the recent IEA report on climate resilience, only nine out of 38 IEA member and association countries include concrete actions on climate adaptation and resilience for every segment of electricity systems.

7. Strengthen international cooperation on electricity security. Electricity underpins vital services and basic needs, such as health systems, water supplies and other energy industries. Maintaining a secure electricity supply is thus of critical importance. The costs of doing nothing in the face of growing climate threats are becoming abundantly clear. The IEA is working with all countries in the IEA family, as well as others around the world, by providing unrivalled data, analysis and policy advice on electricity security issues. It is also bringing governments together at various levels to share experiences and best practices, and identify how to hasten the shift to cleaner and more resilient energy systems.


 

 

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British Columbia Fuels Up for the Future with $900 Million Hydrogen Project

H2 Gateway Hydrogen Network accelerates clean energy in B.C., building electrolysis plants and hydrogen fueling stations for zero-emission vehicles, heavy-duty trucks, and long-haul transit, supporting decarbonization, green hydrogen supply, and infrastructure investment.

 

Key Points

A $900M B.C. initiative by HTEC to build electrolysis plants and 20 hydrogen fueling stations for zero-emission transport.

✅ $900M project with HTEC, CIB, and B.C. government

✅ 3 electrolysis plants plus byproduct liquefaction in North Vancouver

✅ Up to 20 stations; 14 for heavy-duty vehicles in B.C. and Alberta

 

British Columbia is taking a significant step towards a cleaner future with a brand new $900 million project. This initiative, spearheaded by hydrogen company HTEC and supported by the CIB in B.C. and the B.C. government, aims to establish a comprehensive hydrogen network across the province. This network will encompass both hydrogen production plants and fueling stations, marking a major leap in developing hydrogen infrastructure in B.C.

The project, dubbed "H2 Gateway," boasts several key components. At its core lies the construction of three brand new electrolysis hydrogen production plants. These facilities will be strategically located in Burnaby, Nanaimo, and Prince George, ensuring a wide distribution of hydrogen fuel. An additional facility in North Vancouver will focus on liquefying byproduct hydrogen, maximizing resource efficiency.

The most visible aspect of H2 Gateway will undoubtedly be the network of hydrogen fueling stations. The project envisions up to 20 stations spread across British Columbia and Alberta, complementing the province's Electric Highway build-out, with 18 being situated within B.C. itself. This extensive network will significantly enhance the accessibility of hydrogen fuel, making it a more viable option for motorists. Notably, 14 of these stations will be designed to handle heavy-duty vehicles, catering to the transportation sector's clean energy needs.

The economic and environmental benefits of H2 Gateway are undeniable. The project is expected to generate nearly 300 jobs, aligning with recent grid job creation efforts, providing a much-needed boost to the B.C. economy. More importantly, the widespread adoption of hydrogen fuel promises significant reductions in greenhouse gas emissions. Hydrogen-powered vehicles produce zero tailpipe emissions, making them a crucial tool in combating climate change.

British Columbia's investment in hydrogen infrastructure aligns with a global trend. As countries strive to achieve ambitious climate goals, hydrogen is increasingly viewed as a promising clean energy source. Hydrogen fuel cells offer several advantages over traditional electric vehicles, and while B.C. leads the country in going electric, they boast longer driving ranges and shorter refueling times, making them particularly attractive for long-distance travel and heavy-duty applications.

While H2 Gateway represents a significant step forward, challenges remain. The production of clean hydrogen, often achieved through electrolysis using renewable energy sources, faces power supply challenges and requires substantial initial investment. Additionally, the number of hydrogen-powered vehicles on the road is still relatively low.

However, projects like H2 Gateway are crucial in overcoming these hurdles. By creating a robust hydrogen infrastructure, B.C. is sending a strong signal to the industry and, alongside BC Hydro's EV charging expansion across southern B.C., is building a comprehensive clean transportation network. This investment will not only benefit the environment but also incentivize the development and adoption of hydrogen-powered vehicles. As the technology matures and production costs decrease, hydrogen fuel has the potential to revolutionize transportation and play a key role in a sustainable future.

The road ahead for hydrogen may not be entirely smooth, but British Columbia's commitment to H2 Gateway demonstrates a clear vision. By investing in clean energy infrastructure, the province is not only positioning itself as a leader in the fight against climate change, with Canada and B.C. investing in green energy solutions to accelerate progress, but also paving the way for a more sustainable transportation landscape.

 

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U.S. residential electricity bills increased 5% in 2022, after adjusting for inflation

U.S. Residential Electricity Bills rose on stronger demand, inflation, and fuel costs, with higher retail prices, kWh consumption, and extreme weather driving 2022 spikes; forecasts point to stable summer usage and slight price increases.

 

Key Points

They are average household power costs shaped by prices, kWh use, weather, and upstream fuel costs.

✅ 2022 bills up 13% nominal, 5% real vs. 2021

✅ Retail price rose 11%; consumption up 2% to 907 kWh

✅ Fuel costs to plants up 34%, pressuring rates

 

In nominal terms, the average monthly electricity bill for residential customers in the United States increased 13% from 2021 to 2022, rising from $121 a month to $137 a month. After adjusting for inflation—which reached 8% in 2022, a 40-year high—electricity bills increased 5%. Last year had the largest annual increase in average residential electricity spending since we began calculating it in 1984. The increase was driven by a combination of more extreme temperatures, which increased U.S. consumption of electricity for both heating and cooling, and higher fuel costs for power plants, which drove up retail electricity prices nationwide.

Residential electricity customers’ monthly electricity bills are based on the amount of electricity consumed and the retail electricity price. Average U.S. monthly electricity consumption per residential customer increased from 886 kilowatthours (kWh) in 2021 to 907 kWh in 2022, even as U.S. electricity sales have declined over the past seven years. Both a colder winter and a hotter summer contributed to the 2% increase in average monthly electricity consumption per residential customer in 2022 because customers used more space heating during the winter and more air conditioning during the summer, with some states, such as Pennsylvania, facing sharp winter rate increases.

Although we don’t directly collect retail electricity prices, we do collect revenues from electricity providers that allow us to determine prices by dividing by consumption, and industry reports show major utilities spending more on electricity delivery than on power production. In 2022, the average U.S. residential retail electricity price was 15.12 cents/kWh, an 11% increase from 13.66 cents/kWh in 2021. After adjusting for inflation, U.S. residential electricity prices went up by 2.5%.

Higher fuel costs for power plants drove the increase in residential retail electricity prices. The cost of fossil fuels—including natural gas prices, coal, and petroleum—delivered to U.S. power plants increased 34%, from $3.82 per million British thermal units (MMBtu) in 2021 to $5.13/MMBtu in 2022. The higher fuel costs were passed along to residential customers and contributed to higher retail electricity prices, and Germany power prices nearly doubled over a year in a related trend.

In the first three months of 2023, the average U.S. residential monthly electricity bill was $133, or 5% higher than for the same time last year, according to data from our Electric Power Monthly. The increase was driven by a 13% increase in the average U.S. residential retail electricity price, which was partly offset by a 7% decrease in average monthly electricity consumption per residential customer, and industry outlooks also see U.S. power demand sliding 1% on milder weather. This summer, we expect that typical household electricity bills will be similar to last year’s, with customers paying about 2% more on average. The slight increase in electricity costs forecast for this summer stems from higher retail electricity prices but similar consumption levels as last summer.
 

 

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Live Online & In-person Group Training

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

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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.