Incandescent bulbs return to the cutting edge

By New York Times


Substation Relay Protection Training

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:
$699
Coupon Price:
$599
Reserve Your Seat Today
When Congress passed a new energy law two years ago, obituaries were written for the incandescent light bulb. The law set tough efficiency standards, due to take effect in 2012, that no traditional incandescent bulb on the market could meet, and a century-old technology that helped create the modern world seemed to be doomed.

But as it turns out, the obituaries were premature.

Researchers across the country have been racing to breathe new life into Thomas EdisonÂ’s light bulb, a pursuit that accelerated with the new legislation. Amid that footrace, one company is already marketing limited quantities of incandescent bulbs that meet the 2012 standard, and researchers are promising a wave of innovative products in the next few years.

Indeed, the incandescent bulb is turning into a case study of the way government mandates can spur innovation.

“There’s a massive misperception that incandescents are going away quickly,” said Chris Calwell, a researcher with Ecos Consulting who studies the bulb market. “There have been more incandescent innovations in the last three years than in the last two decades.”

The first bulbs to emerge from this push, Philips LightingÂ’s Halogena Energy Savers, are expensive compared with older incandescents. They sell for $5 apiece and more, compared with as little as 25 cents for standard bulbs.

But they are also 30 percent more efficient than older bulbs. Philips says that a 70-watt Halogena Energy Saver gives off the same amount of light as a traditional 100-watt bulb and lasts about three times as long, eventually paying for itself.

The line, for now sold exclusively at Home Depot and on Amazon.com, is not as efficient as compact fluorescent light bulbs, which can use 75 percent less energy than old-style bulbs. But the Energy Saver line is finding favor with consumers who dislike the light from fluorescent bulbs or are bothered by such factors as their slow start-up time and mercury content.

“We’re experiencing double-digit growth and we’re continuing to expand our assortment,” said Jorge Fernandez, the executive who decides what bulbs to stock at Home Depot. “Most of the people that buy that bulb have either bought a C.F.L. and didn’t like it, or have identified an area that C.F.L.’s don’t work in.”

For lighting researchers involved in trying to save the incandescent bulb, the goal is to come up with one that matches the energy savings of fluorescent bulbs while keeping the qualities that many consumers seem to like in incandescents, like the color of the light and the ease of using them with dimmers.

“Due to the 2007 federal energy bill that phases out inefficient incandescent light bulbs beginning in 2012, we are finally seeing a race” to develop more efficient ones, said Noah Horowitz, senior scientist with the Natural Resources Defense Council.

Some of the leading work is under way at a company called Deposition Sciences here in Santa Rosa. Its technology is a key component of the new Philips bulb line.

Normally, only a small portion of the energy used by an incandescent bulb is converted into light, while the rest is emitted as heat. Deposition Sciences applies special reflective coatings to gas-filled capsules that surround the bulbÂ’s filament. The coatings act as a sort of heat mirror that bounces heat back to the filament, where it is transformed to light.

While the first commercial product achieves only a 30 percent efficiency gain, the company says it has achieved 50 percent in the laboratory. No lighting manufacturer has agreed yet to bring the latest technology to market, but Deposition Sciences hopes to persuade one.

“We built a better mouse trap,” said Bob Gray, coating program manager at Deposition Sciences. “Now, we’re trying to get people to beat a path to our door.”

With the new efficiency standards, experts predict more companies will develop specialized reflective coatings for incandescents. The big three lighting companies — General Electric, Osram Sylvania and Philips — are all working on the technology, as is Auer Lighting of Germany and Toshiba of Japan.

And a wave of innovation appears to be coming. David Cunningham, an inventor in Los Angeles with a track record of putting lighting innovations on the market, has used more than $5 million of his own money to develop a reflective coating and fixture design that he believes could make incandescents 100 percent more efficient.

“There’s enormous interest,” Mr. Cunningham said. “All the major lighting companies want an exclusive as soon as we demonstrate feasibility.”

Both Mr. Cunningham and Deposition Sciences have been looking into the work of Chunlei Guo, an associate professor of optics at Rochester University, who announced in May that he had used lasers to pit the surface of a tungsten filament. “Our measurements show that the treated filament becomes twice as bright with the same power consumption,” Mr. Guo said.

And a physics professor at Rensselaer Polytechnic Institute, Shawn-Yu Lin, is also seeing improved incandescent performance by using a high-tech, iridium-coated filament that recycles wasted heat. “The technology can get up to six to seven times more efficient,” Mr. Lin said.

Despite a decade of campaigns by the government and utilities to persuade people to switch to energy-saving compact fluorescents, incandescent bulbs still occupy an estimated 90 percent of household sockets in the United States. Aside from the aesthetic and practical objections to fluorescents, old-style incandescents have the advantage of being remarkably cheap.

But the cheapest such bulbs are likely to disappear from store shelves between 2012 and 2014, driven off the market by the governmentÂ’s new standard. Compact fluorescents, which can cost as little as $1 apiece, may become the bargain option, with consumers having to spend two or three times as much to get the latest energy-efficient incandescents.

A third technology, bulbs using light-emitting diodes, promises remarkable gains in efficiency but is still expensive. Prices can exceed $100 for a single LED bulb, and results from a government testing program indicate such bulbs still have performance problems.

That suggests that LEDs — though widely used in specialized applications like electronic products and, increasingly, streetlights — may not displace incumbent technologies in the home any time soon.

Given how costly the new bulbs are, big lighting companies are moving gradually. Osram will introduce a new line of incandescents in September that are 25 percent more efficient. The bulbs will feature a redesigned capsule with higher-quality gas inside and will sell for a starting price of about $3. That is less than the Philips product already on the market, but they will have shorter life spans. GE also plans to introduce a line of household incandescents that will comply with the new standards.

Mr. Calwell predicts “a lot more flavors” of incandescent bulbs coming out in the future. “It’s hard to be an industry leader in the crowded C.F.L field,” he said. “But a company could truly differentiate itself with a better incandescent.”

Related News

The nuclear power dispute driving a wedge between France and Germany

Franco-German Nuclear Power Divide shapes EU energy policy, electricity market reform, and decarbonization strategies, as Paris backs reactors and state subsidies while Berlin prioritizes renewables, hydrogen, and energy security after Russian gas shocks.

 

Key Points

A policy rift over nuclear shaping EU market reform, subsidies, and the balance between reactors and renewables.

✅ Nuclear in EU targets vs. renewables-first strategy

✅ Market design disputes over long-term power prices

✅ Energy security after Russian gas; hydrogen definitions

 

Near the French village of Fessenheim, facing Germany across the Rhine, a nuclear power station stands dormant. The German protesters that once demanded the site’s closure have decamped, in a sign of Europe's nuclear decline, and the last watts were produced three years ago. 

But disagreements over how the plant from 1977 should be repurposed persist, speaking to a much deeper divide over nuclear power, which Eon chief's warning to Germany underscored, between the two countries on either side of the river’s banks.

German officials have disputed a proposal to turn it into a centre to treat metals exposed to low levels of radioactivity, Fessenheim’s mayor Claude Brender says. “They are not on board with anything that might in some way make the nuclear industry more acceptable,” he adds.

France and Germany’s split over nuclear power is a tale of diverging mindsets fashioned over decades, including since the Chernobyl disaster in USSR-era Ukraine. But it has now become a major faultline in a touchy relationship between Europe’s two biggest economies.

Their stand-off over how to treat nuclear in a series of EU reforms has consequences for how Europe plans to advance towards cleaner energy. It will also affect how the bloc secures power supplies as the region weans itself off Russian gas, even though nuclear would do little for the gas issue, and how it provides its industry with affordable energy to compete with the US and China. 

“There can be squabbles between partners. But we’re not in a retirement home today squabbling over trivial matters. Europe is in a serious situation,” says Eric-André Martin, a specialist in Franco-German relations at French think-tank IFRI. 

France, which produces two-thirds of its power from nuclear plants and has plans for more reactors, is fighting for the low-carbon technology to be factored into its targets for reducing emissions and for leeway to use state subsidies to fund the sector.

For Germany, which closed its last nuclear plants this year and, having turned its back on nuclear, has been particularly shaken by its former reliance on Russian gas, there’s concern that a nuclear drive will detract from renewable energy advances.

But there is also an economic subtext in a region still reeling from an energy crisis last year, reviving arguments for a needed nuclear option for climate in Germany, when prices spiked and laid bare how vulnerable households and manufacturers could become.

Berlin is wary that Paris would benefit more than its neighbours if it ends up being able to guarantee low power prices from its large nuclear output as a result of new EU rules on electricity markets, amid talk of a possible U-turn on the phaseout, people close to talks between the two countries say.

Ministers on both sides have acknowledged there is a problem. “The conflict is painful. It’s painful for the two governments as well as for our [EU] partners,” Sven Giegold, state secretary at the German economy and climate action ministry, where debates about whether a nuclear resurgence is possible persist, tells the Financial Times. 

Agnès Pannier-Runacher, France’s energy minister, says she wants to “get out of the realm of the emotional and move past the considerable misunderstandings that have accumulated in this discussion”.

In a joint appearance in Hamburg last week, German chancellor Olaf Scholz and French president Emmanuel Macron made encouraging noises over their ability to break the latest deadlock: a disagreement over the design of the EU’s electricity market. Ministers had been due to agree a plan in June but will now meet on October 17 to discuss the reform, aimed at stabilising long-term prices.

But the French and German impasse on nuclear has already slowed down debates on key EU policies such as rules on renewable energy and how hydrogen should be produced. Smaller member states are becoming impatient. The delay on the market design is “a big Franco-German show of incompetence again”, says an energy ministry official from another EU country who requested anonymity. 

 

Related News

View more

Ontario Supports Plan to Safely Continue Operating the Pickering Nuclear Generating Station

Pickering Nuclear Generating Station Refurbishment will enable OPG to deliver reliable, clean electricity in Ontario, cut CO2 emissions, support jobs, boost Cobalt-60 medical isotopes supply, and proceed under CNSC oversight alongside small modular reactor leadership.

 

Key Points

A plan to assess and renew Pickering's B units, extending safe, clean, low-cost power in Ontario for up to 30 years.

✅ Extends zero-emissions baseload by up to 30 years

✅ Requires CNSC approval and rigorous safety oversight

✅ Supports Ontario jobs and Cobalt-60 isotope production

 

The Ontario government is supporting Ontario Power Generation’s (OPG) continued safe operation of the Pickering Nuclear Generating Station. At the Ontario government’s request, as a formal extension request deadline approaches, OPG reviewed their operational plans and concluded that the facility could continue to safely generate electricity.

“Keeping Pickering safely operating will provide clean, low-cost, and reliable electricity to support the incredible economic growth and new jobs we’re seeing, while building a healthier Ontario for everyone,” said Todd Smith, Minister of Energy. “Nuclear power has been the safe and reliable backbone of Ontario’s electricity system since the 1970s and our government is working to secure that legacy for the future. Our leadership on Small Modular Reactors and consideration of a refurbishment of Pickering Nuclear Generating Station are critical steps on that path.”

Maintaining operations of Pickering Nuclear Generation Station will also protect good-paying jobs for thousands of workers in the region and across the province. OPG, which reported 2016 financial results that provide context for its operations, employs approximately 4,500 staff to support ongoing operation at its Pickering Nuclear Generating Station. In total, there are about 7,500 jobs across Ontario related to the Pickering Nuclear Generating Station.

Further operation of Pickering Nuclear Generating Station beyond September 2026 would require a complete refurbishment. The last feasibility study was conducted between 2006 and 2009. With significant economic growth and increasing electrification of industry and transportation, and a growing electricity supply gap across the province, Ontario has asked OPG to update its feasibility assessment for refurbishing Pickering “B” units at the Nuclear Generating Station, based on the latest information, as a prudent due diligence measure to support future electricity planning decisions. Refurbishment of Pickering Nuclear Generating Station could result in an additional 30 years of reliable, clean and zero-emissions electricity from the facility.

“Pickering Nuclear Generating Station has never been stronger in terms of both safety and performance,” said Ken Hartwick, OPG President and CEO. “Due to ongoing investments and the efforts of highly skilled and dedicated employees, Pickering can continue to safely and reliably produce the clean electricity Ontarians need.”

Keeping Pickering Nuclear Generating Station operational would ensure Ontario has reliable, clean, and low-cost energy, even as planning for clean energy when Pickering closes continues across the system, while reducing CO2 emissions by 2.1 megatonnes in 2026. This represents an approximate 20 per cent reduction in projected emissions from the electricity sector in that year, which is the equivalent of taking up to 643,000 cars off the road annually. It would also increase North America’s supply of Cobalt-60, a medical isotope used in cancer treatments and medical equipment sterilization, by about 10 to 20 per cent.

OPG requires approval from the Canadian Nuclear Safety Commission (CNSC) for its revised schedule. The CNSC, which employs a rigorous and transparent decision-making process, will make the final decision regarding Pickering’s safe operating life, even though the station was slated to close as planned earlier. OPG will continue to ensure the safety of the Pickering facility through rigorous monitoring, inspections, and testing.

 

Related News

View more

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

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

 

Key Points

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

✅ Connects Bipole III to Minnesota to boost exports

✅ NEB hearings include Indigenous rights and treaty issues

✅ Environmental and access impacts debated in regulatory review

 

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

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

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

#google#

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

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

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

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

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

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

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

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

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

 

Hearings continue

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

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

 

Related News

View more

By Land and Sea, Clean Electricity Needs to Lead the Way

Martha's Vineyard 100% Renewable Energy advances electrification across EVs, heat pumps, distributed solar, offshore wind, microgrids, and battery storage, cutting emissions, boosting efficiency, and strengthening grid resilience for storms and sea-level rise.

 

Key Points

It is an islandwide plan to electrify transport and buildings using wind, solar, storage, and a modern resilient grid.

✅ Electrify transport: EV adoption and SSA hybrid-electric ferries.

✅ Deploy heat pumps for efficient heating and cooling in buildings.

✅ Modernize the grid: distributed solar, batteries, microgrids, VPP.

 

Over the past year, it has become increasingly clear that climate change is accelerating. Here in coastal New England, annual temperatures and precipitation have risen more quickly than expected, tidal flooding is now commonplace, and storms have increased in frequency and intensity. The window for avoiding the worst consequences of a climate-changed planet is closing.

At their recent special town meeting, Oak Bluffs citizens voted to approve the 100 per cent renewable Martha’s Vineyard warrant article; now, all six towns have adopted the same goals for fossil fuel reduction and green electricity over the next two decades. Establishing these targets for the adoption of renewable energy, though, is only an initial step. Town and regional master plans for energy transformation are being developed, but this is a whole-community effort as well. Now is the time for action.

There is much to do to combat climate change, but our most important task is to transition our energy system from one heavily dependent on fossil fuels to one that is based on clean electricity. The good news is that this can be accomplished with currently available technology, and can be done in an economically efficient manner.

Electrification not only significantly lowers greenhouse gas emissions, but also is a powerful energy efficiency measure. So even though our detailed Island energy model indicates that eliminating all (or almost all) fossil fuel use will mean our electricity use will more than double, posing challenges for state power grids in some regions, our overall annual energy consumption will be significantly lower.

So what do we specifically need to do?

The primary targets for electrification are transportation (roughly 60 peer cent of current fossil fuel use on Martha’s Vineyard) and building heating and cooling (40 per cent).

Over the past two years, the increase in the number of electric vehicle models available across a wide range of price points has been remarkable — sedans, SUVs, crossovers, pickup trucks, even transit vans. When rebates and tax credits are considered, they are affordable. Range anxiety is being addressed both by increases in vehicle performance and the growing availability of charging locations (other than at home, which will be the predominant place for Islanders to refuel) and, over time, enable vehicle-to-grid support for our local system. An EV purchase should be something everyone should seriously consider when replacing a current fossil vehicle.

The elephant in the transportation sector room is the Steamship Authority. The SSA today uses roughly 10 per cent of the fossil fuel attributable to Martha’s Vineyard, largely but not totally in the ferries. The technology needed for fully electric short-haul vessels has been under development in Scandinavia for a number of years and fully electric ferries are in operation there. A conservative approach for the SSA would be to design new boats to be hybrid diesel-electric, retrofittable to plug-in hybrids to allow for shoreside charging infrastructure to be planned and deployed. Plug-in hybrid propulsion could result in a significant reduction in emissions — perhaps as much as 95 per cent, per the long-range plan for the Washington State ferries. While the SSA has contracted for an alternative fuel study for its next boat, given the long life of the vessels, an electrification master plan is needed soon.

For building heating and cooling, the answer for electrification is heat pumps, both for new construction and retrofits. These devices move heat from outside to inside (in the winter) or inside to outside (summer), and are increasingly integrated into connected home energy systems for smarter control. They are also remarkably efficient (at least three times more efficient than burning oil or propane), and today’s technology allows their operation even in sub-zero outside temperatures. Energy costs for electric heating via heat pumps on the Vineyard are significantly below either oil or propane, and up-front costs are comparable for new construction. For new construction and when replacing an existing system, heat pumps are the smart choice, and air conditioning for the increasingly hot summers comes with the package.

A frequent objection to electrification is that fossil-fueled generation emits greenhouse gases — thus a so-called green grid is required in order to meet our targets. The renewable energy fraction of our grid-supplied electricity is today about 30 per cent; by 2030, under current legislation that fraction will reach 54 per cent, and by 2040, 77 per cent. Proposed legislation will bring us even closer to our 2040 goals. The Vineyard Wind project will strongly contribute to the greening of our electricity supply, and our local solar generation (almost 10 per cent of our overall electricity use at this point) is non-negligible.

A final important facet of our energy system transformation is resilience. We are dependent today on our electricity supply, and this dependence will grow. As we navigate the challenges of climate change, with increasingly more frequent and more serious storms, 2021 electricity lessons underscore that resilience of electricity supply is of paramount importance. In many ways, today’s electricity distribution system is basically the same approach developed by Edison in the late 19th century. In partnership with our electric utility, we need to modernize the grid to achieve our resiliency goals.

While the full scope of this modernization effort is still being developed, the outline is clear. First, we need to increase the amount of energy generated on-Island — to perhaps 25 per cent of our total electricity use. This will be via distributed energy resources (in the form of distributed solar and battery installations as well as community solar projects) and the application of advanced grid control systems. For emergency critical needs, the concept of local microgrids that are detachable from the main grid when that grid suffers an outage are an approach that is technically sound and being deployed elsewhere. Grid coordination of distributed resources by the utility allows for handling of peak power demand; in the early 2030s this could result in what is known as a virtual power plant on the Island.

The adoption of the 100 renewable Martha’s Vineyard warrant articles is an important milestone for our community. While the global and national efforts in the climate crisis may sometimes seem fraught, we can take some considerable pride in what we have accomplished so far and will accomplish in coming years. As with many change efforts, the old catch-phrase applies: think globally, act locally.
 

 

Related News

View more

All-electric home sports big windows, small footprint

Cold-Climate Heat Pumps deliver efficient heating and cooling for Northern B.C. Net Zero Ready homes, with air-source Mitsubishi H2i systems, triple-pane windows, blower door ACH 0.8, BC Hydro rebates, and CleanBC incentives.

 

Key Points

Electric air-source systems that heat and cool in subzero climates, cutting emissions and lowering energy costs.

✅ Net Zero Ready, Step Code 5, ACH 0.8 airtightness

✅ Operate efficiently to about -28 C with backup heat

✅ Eligible for BC Hydro and CleanBC rebates

 

Heat pump provides heating, cooling in northern B.C. home
It's a tradition at Vanderhoof-based Northern Homecraft that, on the day of the blower door test for a just-completed home, everyone who worked on the build gathers to watch it happen. And in the spring of 2021, on a dazzling piece of land overlooking the mouth of the Stuart River near Fort St. James, that day was a cause for celebration.

A new 3,400-square foot home subjected to the blower door test – a diagnostic tool to determine how much air is entering or escaping from a home – was rated as having just .8 air changes per hour (ACH). That helps make it a Net Zero Ready home, and BC Energy Code Step 5 compliant. That means it would take about a third of the amount of energy to heat the home compared to a typical similar-sized home in B.C. today.

From an energy-efficiency perspective, this is a home whose evident beauty is anything but skin deep.

"The home has lot of square footage of finished living space, and it also has a lot of glazing," says Northern Homecraft owner Shay Bulmer, referring to the home's large windows. "We had a lot of window space to deal with, as well as large vaulted open areas where you can only achieve so much additional insulation. There were a few things that the home had going against it as far as performance goes. There were challenges in keeping it comfortable year-round."


Well-insulated home ideal for heat pump option
Most homes in colder areas of B.C. lean on gas-fueled heating systems to deal with the often long, chilly winters. But with the arrival of cold climate heat pumps capable of providing heat efficiently when temperatures dip as low as -30°C, there's now a clean option for those homes, and using more electricity for heat is gaining support in the North as well.

Heat pumps are an increasingly popular option, both for new and existing homes, because they avoid carbon emissions associated with fossil use while also offering summer cooling, even as record-high electricity demand in Yukon underscores the need for efficient systems.

The Fort St. James home, which was built with premium insulation, airtightness and energy efficiency in mind, made the decision to opt for a heat pump even easier. Still, the heat pump option took the home's owners Dexter and Cheryl Hodder by surprise. While their focus was on designing a home that took full advantage of views down to the river, the couple was under the distinct impression that heat pumps couldn't cut it in the chilly north.

"I wasn't really considering a heat pump, which I thought was only a good solution in a moderate climate," says Dexter, who as director of research and education for the John Prince Research Forest, studies wildlife and forestry interactions in north central B.C. "The specs on the heat pump indicate it would work down to -28°C, and I was skeptical of that. But it worked exactly to spec. It almost seems ridiculous to generate heat from outside air at those low temperatures, but it does."

 

Getting it right with support and rebates
Northern Homecraft took advantage of BC Hydro's Mechanical System Design Pilot program to ensure proper heat pump system design, installation, and verification for the home were applied, and with BC Hydro's first call for power in 15 years driven by electrification, the team prioritized efficient load management.

Based on the home's specific location, size, and performance targets, they installed a ducted Mitsubishi H2I air-source heat pump system. Windows are triple pane, double coated, and a central feature of the home, while insulation specifications were R-40 deep frame insulation in the exterior walls, R-80 insulation in the attic, and R-40 insulation in the vaulted ceilings.

The combination of the year-round benefits of heat pumps, their role in reducing fossil fuel emissions, and the availability of rebates, is making the systems increasingly attractive in B.C., especially as two new BC generating stations were recently commissioned to expand clean supply.

BC Hydro offers home renovation rebates of up to $10,000 for energy-efficient upgrades to existing homes. Rebates are available for windows and doors, insulation, heat pumps, and heat pump hot water heaters. In partnership with CleanBC, rebates of up to $11,000 are also available – when combined with the federal Greener Homes program – for those switching from fossil fuel heating to an electric heat pump.


'Heat dome' pushes summer highs to 40°C
Cooling wasn't really a consideration for Dexter and Cheryl when they were living in a smaller bungalow shaded by trees. But they knew that with the big windows, vaulted ceiling in the living room, and an upstairs bedroom in the new home, there may come a time when they needed air conditioning.

That day arrived shortly after the home was built, as the infamous "heat dome" settled on B.C. and drove temperatures at Fort St. James to a dizzying 40°C.

"It was disgustingly hot, and I don't care if I never see that again here," says Hodder, with a laugh. "But the heat pump maintained the house really nicely throughout, at about 22 degrees. The whole house stayed cool. We just had to close the door to the upper bedroom so it wasn't really heating up during the day."

Hodder says he had to work with the heat pump manufacturer Mitsubishi a couple times over that first year to fix a few issues with the system's controls. But he's confident that the building's tight and well-insulated envelope, and the heat pump's backup electric heat that kicks in when temperatures dip below -28°C, will make it the system-for-all-seasons it was designed to be.

Even with the use of supplemental electric heating during the record chill of December-January, the home's energy costs weren't much higher than the mid-winter energy bills they used to pay in the couple's smaller bungalow that relied on a combination of gas-fired in-floor heating and electric baseboards, as gas-for-electricity swaps are being explored elsewhere.

Fort St. James is a former fur trading post located northwest of Prince George and a short drive north of Vanderhoof. Winters are cold and snowy, with average daily low temperatures in December and January of around -14°C.

"During the summer and into the fall, we were paying well less than $100 a month," says Hodder, looking back at electricity bills over the first year in the home. "And that's everything. We're only electric here, and we also had both of us working from home all last year."

 

Word of mouth making heat pumps popular in Fort St. James
While the size of the home presented new challenges for the builders, it's one of five Net Zero Ready or Net Zero homes – all equipped with some form of heat pump – that Northern Homecraft has built in Fort St. James, even as debates about going nuclear for electricity continue in B.C.

The smallest of the homes is a two-bedroom, one-bathroom home that's just under 900 square feet. Northern Homecraft may be based in Vanderhoof, but it's the much smaller town of Fort St. James where they're making their mark with super-efficient homes. Net Zero Ready homes are up to 80% more efficient than the standard building code, and become Net Zero once renewable energy generation – usually in the form of photovoltaic solar – is installed, and programs like switching 5,000 homes to geothermal show the broader momentum for clean heating.

"We were pretty proud that the first home we built in Fort St. James was the first single family Net Zero Ready home built in B.C.," says Northern Homecraft's Bulmer. "And I think it's kind of caught on in a smaller community where everyone talks to everyone."

 

Related News

View more

Magnitude 5 quake strikes near Iran nuclear plant

Iran Bushehr Earthquake rattles southern province near the Bushehr nuclear power plant, USGS reports M5.1 at 38 km depth; seismic activity along major fault lines raises safety, damage, and monitoring concerns.

 

Key Points

A magnitude 5.1 quake near Bushehr nuclear plant at 38 km depth, with no damage reported, per USGS.

✅ USGS lists magnitude 5.1 at 38 km depth

✅ Near Bushehr nuclear power plant; built for stronger quakes

✅ Iran lies on major fault lines; quake risk is frequent

 

A magnitude 5 earthquake struck southern Iran early Friday near the Islamic Republic's only nuclear power plant. There were no immediate reports of damage or injuries as Iran continues combined-cycle conversions across its power sector.

The quake hit Iran's Bushehr province at 5:23 a.m., according to the U.S. Geological Survey. It put the magnitude at 5.1 and the depth of the earthquake at 38 kilometres (24 miles), in a province tied to efforts to transmit electricity to Europe in coming years.

Iranian state media did not immediately report on the quake. However, the Bushehr nuclear power plant was designed to withstand much stronger earthquakes, a notable consideration as Iraq plans nuclear power plants to address shortages.

A magnitude 5 earthquake can cause considerable damage, including power disruptions that have seen blackouts spark protests in some Iranian cities.

Iran sits on major fault lines and is prone to near-daily earthquakes, yet it remains a key player in regional power, with Iran-Iraq energy cooperation ongoing. In 2003, a 6.6-magnitude quake flattened the historic city of Bam, killing 26,000 people, and today Iran supplies 40% of Iraq's electricity through cross-border power deals. Bam is near the Bushehr nuclear plant, which wasn’t damaged at that time, while more recently Iran finalized deals to rehabilitate Iraq's power grid to improve resilience.

 

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