Utilities told to pay up for outage costs

By Detroit Free Press


Electrical Testing & Commissioning of Power Systems

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
When violent wind gusts knocked out power to more than 230,000 DTE Energy customers in metro Detroit over the weekend, calls of downed power lines poured in to local fire and police departments.

Groveland Township, for one, had at least seven reports to its fire department of lines down that it had to guard until DTE repair workers arrived.

"Babysitting these power lines is typically a big problem for us and much more so in violent storms like the one we just experienced," township Fire Chief Steve McGee said.

It's enough of an issue that the township — and a growing number of area municipalities — now charge utility companies for the services police and fire personnel provide during emergencies such as downed wires and natural gas leaks.

The shift has the potential to provide thousands of dollars of revenue for communities such as Royal Oak, Madison Heights, Ferndale, Waterford, White Lake Township and Groveland Township that already have adopted ordinances allowing such fees to be charged. And many others may follow suit.

DTE Energy and Consumers Energy officials argue that they pay huge amounts in property taxes each year on substations and service buildings and shouldn't have to pay additional fees.

"We're taxpayers in these communities, too," said DTE spokesman Scott Simons.

The fees vary from community to community. Ferndale, whose officials say their emergency personnel wait at the scene of 100 downed power lines and 30 gas leaks each year, can charge up to $250 an hour for a fire engine at the scene, in addition to an average of $40 per hour for each firefighter and police officer.

Royal Oak charges hourly fees ranging from almost $400 for a main engine at the scene to an average of $50 for each firefighter and police officer.

"Our goal is not about generating city revenue but about generating the appropriate response from the utility companies," Royal Oak Fire Chief Wil White said.

Ferndale Fire Chief Roger Schmidt insisted the goal is to get the utility companies to respond in a timely manner.

"On a normal day we've got eight to 10 people on duty," Schmidt said. "When you run into several problem situations the same day, you can get stretched thin really fast and then you have to call in off-duty people. I don't want to say it's not our problem, because it is, but it's their problem as well."

DTE Energy officials noted it pays $300,000 in property taxes annually to Ferndale and $1.2 million to Royal Oak.

"Naturally, safety is our highest priority, and we respond to every emergency as quickly as possible," DTE Energy spokesman Len Singer said. "However, we don't believe we should have to pay for emergency responses when power lines go down.... They're not safeguarding our lines, they're safeguarding the public."

DTE Energy's service area stretches from Monroe County to the tip of the Thumb, an area of 7,600 square miles with 2.2 million electric customers, Singer said. And with so much area to cover, he said, workers often cannot respond as quickly — particularly during wind and ice storms.

In those instances, Singer said, it is standard procedure to dispatch public safety teams consisting of everyday office personnel to secure a scene until service crews can arrive.

Consumers Energy, which provides gas and electric service to nearly 6 million people in Michigan, takes a similar stance. The Jackson-based utility said it paid $491,679 in property taxes to Royal Oak last year and $130,964 to Ferndale.

"While we appreciate the services provided by the police and fire departments in these kind of situations, we hope they recognize that we can't always respond as promptly as we would like during incidents such as a major storm," said Debra Dodd, a spokeswoman for Consumers Energy. "However, we are willing to reimburse them for reasonable costs for their response."

What can be charged and what actually is collected are two different things. Before last weekend's storm, Ferndale — which adopted its ordinance last spring — had billed DTE twice for downed lines. White Lake Township said it has used its ordinance less than a half-dozen times since adopting it three years ago. Madison Heights has yet to bill anyone.

Royal Oak, however, said it has submitted bills for more than $30,000 worth of services over the past two years.

"They've been known to drag their feet when it comes to paying up," White said.

Countering such claims, DTE spokesman Singer replied, "We have reimbursed communities for the emergency response ordinance when extraordinary circumstances warranted... although it's decidedly the exception."

As the two sides continue to debate the justification for such ordinances, some fire officials say there has been a noticeable reduction in the amount of time spent at emergency sites by police and fire departments.

"We've noticed a much quicker response time from the utility companies," White Lake Township Fire Chief Tony Maltese said. "And why not? Money is tight right now and they have to watch every nickel and dime just like we do."

Related News

PG&E Rates Set to Stabilize in 2025

PG&E 2024 Rate Hikes signal sharp increases to fund wildfire safety, infrastructure upgrades, and CPUC-backed reliability, with rates expected to stabilize in 2025, affecting rural residents, businesses, and high-risk zones across California.

 

Key Points

PG&E’s 2024 hikes fund wildfire safety and grid upgrades, with pricing expected to stabilize in 2025.

✅ Driven by wildfire safety, infrastructure, and reinsurance costs

✅ Largest impacts in rural, high-risk zones; business rates vary

✅ CPUC oversight aims to ensure necessary, justified investments

 

Pacific Gas and Electric (PG&E) is expected to implement a series of rate hikes that, amid analyses of why California electricity prices are soaring across the state, will significantly impact California residents. These increases, while substantial, are anticipated to be followed by a period of stabilization in 2025, offering a sense of relief to customers facing rising costs.

PG&E, one of the largest utility providers in the state, announced that its 2024 rate hikes are part of efforts to address increasing operational costs, including those related to wildfire safety, infrastructure upgrades, and regulatory requirements. As California continues to face climate-related challenges like wildfires, utilities like PG&E are being forced to adjust their financial models to manage the evolving risks. Wildfire-related liabilities, which have plagued PG&E in recent years, play a significant role in these rate adjustments. In response to previous fire-related lawsuits, including a bankruptcy plan supported by wildfire victims that reshaped liabilities, and the increased cost of reinsurance, PG&E has made it clear that customers will bear part of the financial burden.

These rate hikes will have a multi-faceted impact. Residential users, particularly those in rural or high-risk wildfire zones, will see some of the largest increases. Business customers will also be affected, although the adjustments may vary depending on the size and energy consumption patterns of each business. PG&E has indicated that the increases are necessary to secure the utility’s financial stability while continuing to deliver reliable service to its customers.

Despite the steep increases in 2024, PG&E's executives have assured that the company's pricing structure will stabilize in 2025. The utility has taken steps to balance the financial needs of the business with the reality of consumer affordability. While some rate hikes are inevitable given California's regulatory landscape and climate concerns, PG&E's leadership believes the worst of the increases will be seen next year.

PG&E’s anticipated stabilization comes after a year of scrutiny from California regulators. The California Public Utilities Commission (CPUC) has been working closely with PG&E to scrutinize its rate request and ensure that hikes are justifiable and used for necessary investments in infrastructure and safety improvements. The CPUC’s oversight is especially crucial given the company’s history of safety violations and the public outrage over past wildfire incidents, including reports that its power lines may have sparked fires in California, which have been linked to PG&E’s equipment.

The hikes, though significant, reflect the broader pressures facing utilities in California, where extreme weather patterns are becoming more frequent and intense due to climate change. Wildfires, which have grown in severity and frequency in recent years, have forced PG&E to invest heavily in fire prevention and mitigation strategies, including compliance with a judge-ordered use of dividends for wildfire mitigation across its service area. This includes upgrading equipment, inspecting power lines, and implementing more rigorous protocols to prevent accidents that could spark devastating fires. These investments come at a steep cost, which PG&E is passing along to consumers through higher rates.

For homeowners and businesses, the potential for future rate stabilization offers a glimmer of hope. However, the 2024 increases are still expected to hit consumers hard, especially those already struggling with high living costs. The steep hikes have prompted public outcry, with calls for action as bills soar amplifying advocacy group arguments that utilities should absorb more of the costs related to climate change and fire prevention instead of relying on ratepayers.

Looking ahead to 2025, the expectation is that PG&E’s rates will stabilize, but the question remains whether they will return to pre-2024 levels or continue to rise at a slower rate. Experts note that California’s energy market remains volatile, and while the rates may stabilize in the short term, long-term cost management will depend on ongoing investments in renewable energy sources and continued efforts to make the grid more resilient to climate-related risks.

As PG&E navigates this challenging period, the company’s commitment to transparency and working with regulators will be crucial in rebuilding trust with its customers. While the immediate future may be financially painful for many, the hope is that the utility's focus on safety and infrastructure will lead to greater long-term stability and fewer dramatic rate increases in the years to come.

Ultimately, California residents will need to brace for another tough year in terms of utility costs but can find reassurance that PG&E’s rate increases will eventually stabilize. For those seeking relief, there are ongoing discussions about increasing energy efficiency, exploring renewable energy alternatives, and expanding assistance programs for lower-income households to help mitigate the financial strain of these price hikes.

 

Related News

View more

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.

 

Related News

View more

Ontario's five largest electricity providers join together to warn of holiday scams

Ontario Electricity Bill Scams: beware phishing, spoofed calls, fake invoices, and disconnection threats demanding prepaid cards, gift cards, or Bitcoin; verify with Hydro One, Alectra, Toronto Hydro, Elexicon, or Hydro Ottawa customer service.

 

Key Points

Fraud schemes impersonating utilities via calls, texts, emails, or fake bills to coerce instant payment with threats.

✅ Never pay by gift cards, prepaid debit, or Bitcoin.

✅ Do not call numbers in messages; use your bill or utility website.

✅ Verify IDs; report threats or door-to-door demands to police.

 

Ontario’s five largest electricity utilities have teamed up to warn the public about ongoing scams concerning fake phone calls, texts and bills connected to the utility accounts.

“We always receive these reports of scams and it gets increasingly higher during the holidays when people are busy and enjoying the season," said Whitney Brhelle, spokesperson with Hydro One.

Hydro One joined with Alectra Utilities, Elexicon Energy, Hydro Ottawa and Toronto Hydro to get the message out that scammers are targeting customers and threatening to turn off their power.

Scams involve impersonation of a local utility or its employees, threatening phone calls, texts or emails and pressure for immediate payment that come with threats to disconnect service the same day.

Criminals may demand payment in prepaid debit cards, gift cards or Bitcoin. Utilities said they would never call a customer without notice and threaten disconnection over the phone.

In a separate case, authorities in Montreal arrested suspects in an electricity theft ring that highlights broader energy-related crime.

“People have been calling customers and saying you need to pay your bill immediately and they are threatened with disconnection, often citing supposed changes to peak hydro rates to add pressure, which is something that we would ever do," said Kimberly Brathwaite, spokesperson with Elexicon Energy.

Scammers are also creating fake bills that look like the real thing.

“Scammers will actually take our Alectra logo and send out various authentic looking documents to people’s homes, so people have to be aware and check their statements very carefully” said Ashley Trgachef spokesperson with Alectra Utilities.

Customers are advised to never make a payment not listed on their recent bill and to ignore texts or emails with links promising refunds, and to verify any official relief fund information only through their utility and not to provide personal information or details about their account.

If you are given a number to call don’t call the number provided, you are better off to go to your bill or the utility’s website to makes sure it is the correct number for customer service and to review information about customer flexibility there.

Some scammers have even gone door to door demanding payment, and the utilities are advising anyone who feels threatened to call police.

They are also asking that you share the information with family and friends to be careful if they are contacted by someone claiming to be with their electricity company.

If you fall for a scam and money is sent, it's very difficult to get it back.  

 

Related News

View more

Power Demand Seen Holding Firm In Europe’s Latest Lockdown

European Power Demand During Second Lockdowns remains resilient as winter heating offsets commercial losses; electricity consumption tracks seasonal norms, with weather sensitivity, industrial activity, natural gas shielding, and coal decline shaping dynamics under COVID-19 restrictions.

 

Key Points

It is expected to remain near seasonal norms, driven by heating, industry activity, and weather sensitive consumption.

✅ Winter heating offsets retail and hospitality closures

✅ Demand sensitivity rises with colder weather in France

✅ Gas generation shielded; coal likely to curtail first

 

European power demand is likely to hold up in the second round of national lockdown restrictions, with fluctuations most likely driven by changes in the weather.

Traders and analysts expect normal consumption this time around as home heating during the chilly season replaces commercial demand.

Last week electricity consumption in France, Germany and the U.K. was close to business-as-usual levels for the time of year, according to BloombergNEF data. By contrast, power demand had dropped 16% in the first seven days of the springtime lockdown, as reflected by the U.K.’s 10% daily decline reported then.

How power demand performs has significance outside the sector. It’s often seen as a proxy for economic growth and during lockdowns earlier this year, electricity use slumped along with GDP, and stunted hydro and nuclear output could further hobble recovery. For Western Europe, annual demand is expected to be 5% lower than the previous year, a bigger decline than after the global financial crisis in 2008, according to S&P Global Platts.

The Covid-19 limits are lighter than those from earlier in the year “with an explicit drive to preserve economic activity, particularly at the more energy-intensive industrial end of the spectrum,” said Glenn Rickson, head of European power analysis at S&P Global Platts.

Higher levels of working from home will offset some of the losses from shop and hospitality closures, “but also increase the temperature sensitivity of overall gas and power demand, as heat-driven demand records have shown in recent summers,” he said.

The latest wave of national lockdowns began in France, Germany, Spain, Italy and Britain, with Spain having seen April demand plummet earlier in the year, as coronavirus cases surged and officials struggled to keep the spread of the virus under control.

Much of the manufacturing industry remains working for now despite additional restrictions to contain the coronavirus. With the peak of the second wave yet to be reached, “it seems almost inevitable that the fourth quarter will prove economically challenging,” analysts at Alfa Energy said.

There will initially be significantly less of an impact on demand compared with this spring when global daily demand dipped about 15% and electricity consumption in Europe was down 30%, Johan Sigvardsson, power price analyst at Swedish utility Bixia AB said.

The prevalence of electric heating systems in France means that power demand is particularly sensitive to cold weather. A cold spell would significantly boost demand and drive record electricity prices in tight markets.

Similar to the last round of shutdowns, it’s use of coal that will probably be hit first if power demand sags, as transition-focused responses gather pace, leaving natural gas mostly shielded from fluctuations in the market.

“We expect that another drop in power demand would again impact coal-fired generation and shield gas power to some extent,” said Carlos Torres Diaz, an analyst at Rystad Energy.

 

Related News

View more

Will Israeli power supply competition bring cheaper electricity?

Israel Electricity Reform Competition opens the supply segment to private suppliers, challenges IEC price controls, and promises consumer choice, marginal discounts, and market liberalization amid natural gas generation and infrastructure remaining with IEC.

 

Key Points

Policy opening 40% of supply to private vendors, enabling consumer choice and small discounts while IEC retains the grid.

✅ 40% of retail supply opened to private electricity suppliers

✅ IEC keeps meters, lines; tariffs still regulated by the authority

✅ Expected discounts near 7%, not dramatic price cuts initially

 

"See the pseudo-reform in the electricity sector: no lower prices, no opening the market to competition, and no choice of electricity suppliers, with a high rate for consumers despite natural gas." This is an advertisement by the Private Power Producers Forum that is appearing everywhere: Facebook, the Internet, billboards, and the press.

Is it possible that the biggest reform in the economy with a cost estimated by Israel Electric Corporation (IEC) (TASE: ELEC.B22) at NIS 7 billion is really a pseudo-reform? In contrast to the assertions by the private electricity producers, who are supposedly worried about our wallets and want to bring down the cost of electricity for us, the reform will open a segment of electricity supply to competition, as agreed in the final discussions about the reform. No less than 40% of this segment will be removed from IEC's exclusive responsibility and pass to private hands.

This means that in the not-too-distant future, one million households in Israel will be able to choose between different electricity suppliers. IEC will retain the infrastructure, with its meter and power lines, but for the first time, the supplier who sends the monthly bill to our home can be a private concern.

Up until now, the only regulatory agency determining the electricity rate in Israel was the Public Utilities Authority (electricity), i.e. the state. Now, in the framework of the reform, as a result of opening the supply segment to competition, private electricity producers will be able to offer a lower rate than IEC's, with mechanisms like electricity auctions shown to cut costs in some markets, while IEC's rate will still be controlled by the Public Utilities Authority (electricity).

This situation differs from the situation in almost all European countries, where the electricity market is fully open to competition and the EU is pursuing an electricity market revamp to address pricing challenges, with no electricity price controls and free switching by consumers between electricity producers, just as in the mobile phone market. This measure has not lowered electricity prices in Europe, where rates are higher than in Israel, which is in the bottom third of OECD countries in its electricity rate.

Regardless of reports, supply will be opened to competition and we will be able to choose between electricity suppliers in the future. Are the private electricity producers nevertheless right when they say that the electricity sector will not be opened to "real competition"?

 

What is obviously necessary is for the private producers to offer a substantially lower rate than IEC in order to attract as many new customers as possible and win their trust. Can the private producers offer a significantly lower rate than IEC? The answer is no, at least not in the near future. The teams handling the negotiations are aware of this. "The private supplier's price will not be significantly cheaper than IEC's controlled price; there will be marginal discounts," a senior government source explains. "What is involved here is another electricity intermediary, so it will not contribute to competition and lowering the price," he added.

There are already private electricity producers supplying electricity to large business customers - factories, shopping malls, and so forth - at a 7% discount. The rest of the electricity that they produce is sold to the system manager. When supply is opened to competition, it can be assumed that the private suppliers will also be able to offer a similar discount to private consumers.

Will a 7% discount cause a home consumer to leave reliable and familiar IEC for a private producer, given evidence from retail electricity competition in other markets? This is hard to know.

#google#

Why cannot private electricity producers offer a larger discount that will really break the monopoly, as their advertisement says they want to do? Chen Herzog, chief economist and partner at BDO Consulting, which is advising the Private Power Producers Forum, says, "Competition in supply requires the construction of competitive power plants that can compete and offer cheaper electricity.

"The power plants that IEC will sell in the reform, which will go on selling electricity to IEC, are outmoded, inefficient, and non-competitive. In addition, the producer will have to continue employing IEC workers in the purchased plants for at least five years. The producer will generate electricity in IEC power stations with IEC employees and additional overhead of a private producer, with factors such as cost allocation further shaping end-user rates. This amounts to being an IEC subcontractor in production. There is no saving on costs, so there will be no surplus to deduct from the consumer price," he adds.

The idea of opening supply to electricity market competition on such a large scale sounds promising, but saving on electricity for consumers still looks a long way off.

 

Related News

View more

New fuel cell concept brings biological design to better electricity generation

Quinone-mediated fuel cell uses a bio-inspired organic shuttle to carry electrons and protons to a nearby cobalt catalyst, improving hydrogen conversion, cutting platinum dependence, and raising efficiency while lowering costs for clean electricity.

 

Key Points

An affordable, bio-inspired fuel cell using an organic quinone shuttle and cobalt catalyst to move electrons efficiently

✅ Organic quinone shuttles electrons to a separate cobalt catalyst

✅ Reduces platinum use, lowering cost of hydrogen power

✅ Bio-inspired design aims to boost efficiency and durability

 

Fuel cells have long been viewed as a promising power source. But most fuel cells are too expensive, inefficient, or both. In a new approach, inspired by biology, a team has designed a fuel cell using cheaper materials and an organic compound that shuttles electrons and protons.

Fuel cells have long been viewed as a promising power source. These devices, invented in the 1830s, generate electricity directly from chemicals, such as hydrogen and oxygen, and produce only water vapor as emissions. But most fuel cells are too expensive, inefficient, or both.

In a new approach, inspired by biology and published today (Oct. 3, 2018) in the journal Joule, a University of Wisconsin-Madison team has designed a fuel cell using cheaper materials and an organic compound that shuttles electrons and protons.

In a traditional fuel cell, the electrons and protons from hydrogen are transported from one electrode to another, where they combine with oxygen to produce water. This process converts chemical energy into electricity. To generate a meaningful amount of charge in a short enough amount of time, a catalyst is needed to accelerate the reactions.

Right now, the best catalyst on the market is platinum -- but it comes with a high price tag, and while advances like low-cost heat-to-electric materials show promise, they address different conversion pathways. This makes fuel cells expensive and is one reason why there are only a few thousand vehicles running on hydrogen fuel currently on U.S. roads.

Shannon Stahl, the UW-Madison professor of chemistry who led the study in collaboration with Thatcher Root, a professor of chemical and biological engineering, says less expensive metals can be used as catalysts in current fuel cells, but only if used in large quantities. "The problem is, when you attach too much of a catalyst to an electrode, the material becomes less effective," he says, "leading to a loss of energy efficiency."

The team's solution was to pack a lower-cost metal, cobalt, into a reactor nearby, where the larger quantity of material doesn't interfere with its performance. The team then devised a strategy to shuttle electrons and protons back and forth from this reactor to the fuel cell.

The right vehicle for this transport proved to be an organic compound, called a quinone, that can carry two electrons and protons at a time. In the team's design, a quinone picks up these particles at the fuel cell electrode, transports them to the nearby reactor filled with an inexpensive cobalt catalyst, and then returns to the fuel cell to pick up more "passengers."

Many quinones degrade into a tar-like substance after only a few round trips. Stahl's lab, however, designed an ultra-stable quinone derivative. By modifying its structure, the team drastically slowed down the deterioration of the quinone. In fact, the compounds they assembled last up to 5,000 hours -- a more than 100-fold increase in lifetime compared to previous quinone structures.

"While it isn't the final solution, our concept introduces a new approach to address the problems in this field," says Stahl. He notes that the energy output of his new design produces about 20 percent of what is possible in hydrogen fuel cells currently on the market. On the other hand, the system is about 100 times more effective than biofuel cells that use related organic shuttles.

The next step for Stahl and his team is to bump up the performance of the quinone mediators, allowing them to shuttle electrons more effectively and produce more power. This advance would allow their design to match the performance of conventional fuel cells, but with a lower price tag.

"The ultimate goal for this project is to give industry carbon-free options for creating electricity, including thermoelectric materials that harvest waste heat," says Colin Anson, a postdoctoral researcher in the Stahl lab and publication co-author. "The objective is to find out what industry needs and create a fuel cell that fills that hole."

This step in the development of a cheaper alternative could eventually be a boon for companies like Amazon and Home Depot that already use hydrogen fuel cells to drive forklifts in their warehouses.

"In spite of major obstacles, the hydrogen economy, with efforts such as storing electricity in pipelines in Europe, seems to be growing," adds Stahl, "one step at a time."

Financial support for this project was provided by the Center for Molecular Electrocatalysis, an Energy Frontier Research Center funded by the U.S. Department of Energy, Office of Science, Office of Basic Energy Sciences, and by the Wisconsin Alumni Research Foundation (WARF) through the WARF Accelerator Program.

 

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

Download the 2025 Electrical Training Catalog

Explore 50+ live, expert-led electrical training courses –

  • Interactive
  • Flexible
  • CEU-cerified