Marz to build 100 per cent renewable homes

By EcoHome Magazine


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This year, the Canadian builder Marz Homes expects to close between 100 and 125 homes in five suburban Ontario communities, and all of them will be 100% powered by renewable energy.

Stoney Creek, Ont.-based Marz claims it is the first builder in Canada to make clean energy a standard feature in its new homes, thanks to a strategic alliance with Bullfrog Power, a Toronto-based electricity supplier that buys and distributes energy from renewable sources. In Ontario, Bullfrog draws power exclusively from wind and hydro facilities that have been certified as low impact by Environment Canada under its EcoLogo program.

For all of the houses Marz sells in 2010, homeowners will pay for the cost of conventional electricity, and the builder will cover the premium for their using renewable energy. Dan Gabriele, Marz’s vice president, estimates that his company’s costs would average about one Canadian dollar per house per day. “That’s probably a lot less than some of the other [sales] incentives Marz has offered in the past,” says Anthony Santilli, Bullfrog’s vice president of sales and marketing.

Marz is also powering its offices and job sites with renewable energy. All told, the builder expects to reduce its annual energy consumption by 1,395 megawatt hours, and lessen its environmental footprint by 297.1 tons of carbon dioxide, 916 kilograms of sulfur dioxide, and 377 kilograms of nitric oxide.

“We wanted to differentiate ourselves and go down a new path,” says Gabriele.

Offering clean energy could provide a marketing edge in the Canadian housing market, where harsher weather conditions already dictate higher performance standards for residential construction compared to the United States. “We got on this train in 1984,” notes John Kenward, COO of the Canadian Home Builders Association (CHBA) in Ottawa. The trade group’s new president, Victor Fiume of Durham Homes, has long been an Energy Star builder. (In Canada, Energy Star is at least as rigorous as LEED. The Canadian government’s R-2000 certification program is the country’s gold standard when it comes to energy efficiency).

David Foster, CHBA’s director of environmental affairs, notes that Ontario’s utility companies are in the final stages of retrofitting all of the province’s residential and commercial buildings with “smart meters” as a prelude to moving towards time-of-use electricity rates.

In 2012, new building codes scheduled to go into effect in Ontario will make Energy Star “more of the norm” for residential construction, says Ken Elsey, president of the Canadian Energy Efficiency Alliance. The provinces of Manitoba, British Columbia, and Quebec are also gravitating towards stricter codes. But for the time being, Elsey estimates that only around 20% of the houses built in Ontario meet existing Energy Star standards.

“While I applaud Marz for calling attention to Bullfrog, they’re wasting their money if they aren’t building their house envelopes to Energy Star or R-2000,” Elsey says.

While Marz does not automatically build its homes to Energy Star or R-2000 specs, the company is a registered Energy Star builder, has built homes to those specifications, and offers Energy Star as an option to all of its home buyers. (Its homes range from 1,400-square-foot condos selling for $250,000, to 4,000-square-foot estates selling for more than $1 million.)

Gabriele says his company views its arrangement with Bullfrog Power as a “value added” feature for its customers. And while he’s not sure how many new homeowners will continue using Bullfrog as their energy provider after the contract expires, he points to the cable packages that virtually all builders in Ontario offer. “It’s up to the cable provider to sign up owners” after the first year, and the vast majority of owners stay with the provider. “We’re using that as the basic premise for our energy program.”

Santilli says Bullfrog sees its agreement with Marz Homes as a springboard to get more builders to incorporate renewable energy into their marketing. Right now, Bullfrog provides renewable power to about 8,000 homes in six provinces. (Those homes draw power from their regional electricity grids, into which Bullfrog replaces what its customers consume with energy from renewable sources.)

Clean energy is widely accessible in Canada, which generates more than three-quarters of its electricity needs from sources — primarily hydro and nuclear — which don’t emit greenhouse gases. Quebec, Manitoba, and British Columbia draw as much as 80% of their electricity from hydro facilities alone. Ontario plans to close its four coal-fired plants by 2014, and coal accounted for only 7% of the province’s energy last year, the lowest level in 45 years, according to the Toronto Sun. Wind, which right now accounts for only 1% of the country’s electricity output, is projected to generate more than 20% of the Canada’s energy needs by 2025, according to the Canadian Wind Energy Association.

But the Canadian government’s goal to boost renewable energy to 90% of its total generation by 2020 is encountering funding challenges and even internal skepticism. “It’s doable, but it’s going to take some will to achieve,” admits Santilli.

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Reload.Land 2025: Berlin's Premier Electric Motorcycle Festival Returns

Reload.Land 2025 returns to Berlin with electric motorcycles, e-scooters, test rides, a conference on sustainability, custom builds, a silent ride, networking, innovators, brands, enthusiasts, and an electronic afterparty, spotlighting Europe's cutting-edge electromobility scene.

 

Key Points

Reload.Land 2025 is Berlin's electric motorcycle festival with test rides, panels, custom bikes, and a city silent ride.

✅ Test rides for electric motorcycles and e-scooters

✅ Conference on technology, sustainability, and policy

✅ Custom exhibition, Silent Ride, and electronic afterparty

 

Reload.Land, Europe's pioneering festival dedicated to electric motorcycles, is set to return for its third edition on June 7–8, 2025. Held at the Napoleon Komplex in Berlin, a city advancing sustainable mobility initiatives, this event promises to be a significant gathering for enthusiasts, innovators, and industry leaders in the realm of electric mobility.

A Hub for Electric Mobility Enthusiasts

Reload.Land serves as a platform for showcasing the latest advancements in electric two-wheelers, reflecting broader electricity innovation trends, including motorcycles, e-scooters, and custom electric bikes. Attendees will have the opportunity to test ride a diverse selection of electric vehicles from various manufacturers, providing firsthand experience of the evolving landscape of electromobility.

Highlights of the Festival

  • Custom Exhibition: A curated display of unique electric motorcycles and vehicles, highlighting the creativity and innovation within the electric mobility sector, from custom builders to Daimler's electrification plan shaping supply chains.

  • Reload.Land Conference: Engaging panel discussions and presentations from industry experts, focusing on topics such as cutting-edge technology, sustainability, including electricity demand from e-mobility projections, and the future of electric transportation.

  • Silent Ride: A group electric-only ride through the streets of Berlin, alongside projects like the city's electric flying ferry initiative, offering participants a unique experience of the city while promoting the quiet and clean nature of electric vehicles.

  • Official Afterparty: An evening celebration featuring electronic music, providing attendees with an opportunity to unwind and network in a vibrant atmosphere.
     

Community and Networking Opportunities

Reload.Land is not just an event; it's a movement that brings together a global community of riders, innovators, and brands. The festival fosters an environment where like-minded individuals can connect, share ideas, and collaborate on shaping the future of electric mobility, with similar gatherings like Everything Electric in Vancouver amplifying awareness worldwide. 

Event Details

  • Dates: June 7–8, 2025

  • Location: Napoleon Komplex, Modersohnstraße 35–45, 10245 Berlin, Germany.

  • Entry Fee: €10 (Children up to 14 years free)

Reload.Land 2025 promises to be a landmark event in the electric mobility calendar, offering a comprehensive look at the innovations shaping the future of transportation, echoing the public enthusiasm seen at EV events in Regina this year. Whether you're a seasoned rider, an industry professional, or simply curious about electric vehicles, Reload.Land provides a unique opportunity to immerse yourself in the world of electric motorcycles.

 

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Rio Tinto seeking solutions that transform heat from underground mines into electricity

Rio Tinto waste heat-to-electricity initiative captures underground mining thermal energy at Resolution Copper, Arizona, converting it to renewable power for cooling systems and microgrids, advancing decarbonization, energy efficiency, and the miner's 2050 carbon-neutral goal.

 

Key Points

A program converting underground thermal energy into on-site electricity to cut emissions and support mine cooling.

✅ Captures low-grade heat from rock and geothermal water.

✅ Generates electricity for ventilation, refrigeration, microgrids.

✅ Scalable, safe, and grid- or storage-ready for peak demand.

 

The world’s second-largest miner, Rio Tinto announced that it is accepting proposals for solutions that transform waste heat into electricity for reuse from its underground operations.

In a press release, the company said this initiative is aimed at drastically reducing greenhouse gas emissions, even as energy-intensive projects like bitcoin mining operations expand, so that it can achieve its goal of becoming carbon neutral by 2050.

Initially, the project would be implemented at the Resolution copper mine in Arizona, which Rio owns together with BHP (ASX, LON: BHP). At this site, massive electrically-driven refrigeration and ventilation systems, aligned with broader electrified mining practices, are in charge of cooling the work environment because of the latent heat from the underground rock and groundwater. 

THE INITIATIVE IS AIMED AT REDUCING GREENHOUSE GAS EMISSIONS SO THAT RIO CAN ACHIEVE ITS GOAL OF BECOMING CARBON NEUTRAL BY 2050

“When operating, the Resolution copper mine will be a deep underground block cave mine some 7,000 feet (~2 kilometres) deep, with ambient air temperatures ranging between 168°F to 180°F (76°C to 82°C), conditions that, during heat waves, when bitcoin mining power demand can strain local grids, further heighten cooling needs, and underground water at approximately 194°F (90°C),” the media brief states.

“Rio Tinto is seeking solutions to capture and reuse the heat from underground, contributing towards powering the equipment needed to cool the operations. The solution to capture and convert this thermal energy into electrical energy, such as emerging thin-film thermoelectrics, should be safe, environmentally friendly and cost-effective.”

The miner also said that, besides capturing heat for reuse, the solution should generate electrical energy from low range temperatures below the virgin rock temperature and/or from the high thermal water coming from the underground rock, similar to using transformer waste heat for heating in the power sector. 

At the same time, the solution should be scalable and easily transported through the many miles of underground tunnels that will be built to ventilate, extract and move copper ore to the surface.

Rio requires proposals to offer the possibility of distributing the electrical energy generated back into the electrical grid from the mining operation or stored and used at a later stage when energy is required during peak use periods, especially as jurisdictions aim to use more electricity for heat in colder seasons. 

 

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Fire in manhole leaves thousands of Hydro-Québec customers without power

Montreal Power Outage linked to Hydro-Que9bec infrastructure after an underground explosion and manhole fire in Rosemont–La Petite–Patrie, disrupting the STM Blue Line and forcing strategic, cold-weather grid restoration on Be9langer Street.

 

Key Points

Outage from an underground blast and manhole fire disrupted STM service; Hydro-Que9bec restored the grid in cold weather.

✅ Peak impact: 41,000 customers; 10,981 still without power by 7:00 p.m.

✅ STM Blue Line restored after afternoon shutdown; Be9langer Street reopened.

✅ Hydro-Que9bec pacing restoration to avoid grid overload in cold weather.

 

Hydro-Québec says a power outage affecting Montreal is connected to an underground explosion and a fire in a manhole in Rosemont—La Petite–Patrie. 

The fire started in underground pipes belonging to Hydro-Québec on Bélanger Street between Boyer and Saint-André streets, according to Montreal firefighters, who arrived on the scene at 12:18 p.m.

The electricity had to be cut so that firefighters could get into the manhole where the equipment was located.

At the peak of the shutdown, nearly 41,000 customers were without power across Montreal.  As of 7:00 p.m., 10,981 clients still had no power.

In similar storms, Toronto power outages have persisted for hundreds, underscoring restoration challenges.

Hydro-Québec spokesperson Louis-Olivier Batty said the utility is being strategic about how it restores power across the grid. 

Because of the cold, and patterns seen during freezing rain outages, it anticipates that people will crank up the heat as soon as they get their electricity back, and that could trigger an overload somewhere else on the network, Batty said.

The Metro's Blue line was down much of the afternoon, but the STM announced the line was back up and running just after 4:30 p.m.

Bélanger Street was blocked to traffic much of the afternoon, however, it has now been reopened.

Batty said once the smoke clears, Hydro-Québec workers will take a look at the equipment to see what failed. 

 

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OPG, TVA Partner on New Nuclear Technology Development

OPG-TVA SMR Partnership advances advanced nuclear technology and small modular reactors for 24/7 carbon-free baseload power, enabling net-zero goals, cross-border licensing, and deployment within a North American clean energy hub.

 

Key Points

A cross-border effort by OPG and TVA to develop, license, and deploy SMRs for reliable, carbon-free baseload power.

✅ Coordinates design, licensing, construction, and operations

✅ Supports 24/7 baseload, net-zero targets, and energy security

✅ Leverages Darlington and Clinch River early site permits

 

Two of North America's leading nuclear utilities unveiled a pioneering partnership to develop advanced nuclear technology as an integral part of a clean energy future and creating a North American energy hub. Ontario Power Generation, whose OPG's SMR commitment is well established, and the Tennessee Valley Authority will jointly work to help develop small modular reactors as an effective long-term source of 24/7 carbon-free energy in both Canada and the U.S.

The agreement allows the companies to coordinate their explorations into the design, licensing, construction and operation of small modular reactors.

"As leaders in our industry and nations, OPG and TVA share a common goal to decarbonize energy generation while maintaining reliability and low-cost service, which our customers expect and deserve," said Jeff Lyash, TVA President and CEO. "Advanced nuclear technology will not only help us meet our net-zero carbon targets but will also advance North American energy security."

"Nuclear energy has long been key to Ontario's clean electricity grid, and is a crucial part of our net-zero future," said Ken Hartwick, OPG President and CEO. "Working together, OPG and TVA will find efficiencies and share best practices for the long-term supply of the economical, carbon-free, reliable electricity our jurisdictions need, supported by ongoing Pickering life extensions across Ontario's fleet."

OPG and TVA have similar histories and missions. Both are based on public power models that developed from renewable hydroelectric generation before adding nuclear to their generation mixes. Today, nuclear generation accounts for significant portions of their carbon-free energy portfolios, with Ontario advancing the Pickering B refurbishment to sustain capacity.

Both are also actively exploring SMR technologies. OPG is moving forward with plans to deploy an SMR at its Darlington nuclear facility in Clarington, ON, as part of broader Darlington SMR plans now underway. The Darlington site is the only location in Canada licensed for new nuclear with a completed and accepted Environmental Assessment. TVA currently holds the only Nuclear Regulatory Commission Early Site Permit in the U.S. for small modular reactor deployment at its Clinch River site near Oak Ridge, TN.

No exchange of funding is involved. However, the collaboration agreement will help OPG and TVA reduce the financial risk that comes from development of innovative technology, as well as future deployment costs.

"TVA has the most recent experience completing a new nuclear plant in North America at Watts Bar and that knowledge is invaluable to us as we work toward the first SMR groundbreaking at Darlington," said Hartwick. "Likewise, because we are a little further along in our construction timing, TVA will gain the advantage of our experience before they start work at Clinch River."

"It's a win-win agreement that benefits all of those served by both OPG and TVA, as well as our nations," said Lyash. "Moving this technology forward is not only a significant step in advancing a clean energy future and Canada's climate goals, but also in creating a North American energy hub."

"With the demand for clean electricity on the rise around the world, Ontario's momentum is growing. The world is watching Ontario as we advance our work to fully unleash our nuclear advantage, alongside a premiers' SMR initiative that underscores provincial collaboration. I congratulate OPG and TVA – two great industry leaders – for working together to deploy SMRs and showcase and apply Canada's nuclear expertise that will deliver economic, health and environmental benefits for all of us to enjoy," said Todd Smith, Ontario Minister of Energy.

"The changing climate is a global crisis that requires global solutions. The partnership between the Tennessee Valley Authority and Ontario Power Generation to develop and deploy advanced nuclear technology is exactly the kind of innovative collaboration that is needed to quickly bring the next generation of nuclear carbon-free generation to market. I applaud the leadership that both companies are demonstrating to further strengthen our cross-border relationships," said Maria Korsnick, President and CEO, Nuclear Energy Institute.

 

 

 

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Major U.S. utilities spending more on electricity delivery, less on power production

U.S. Utility Spending Shift highlights rising transmission and distribution costs, grid modernization, and smart meters, while generation expenses decline amid fuel price volatility, capital and labor pressures, and renewable integration across the power sector.

 

Key Points

A decade-long trend where utilities spend more on delivery and grid upgrades, and less on electricity generation costs.

✅ Delivery O&M, wires, poles, and meters drive rising costs

✅ Generation spending declines amid fuel price changes and PPI

✅ Grid upgrades add reliability, resilience, and renewable integration

 

Over the past decade, major utilities in the United States have been spending more on delivering electricity to customers and less on producing that electricity, a shift occurring as electricity demand is flat across many regions.

After adjusting for inflation, major utilities spent 2.6 cents per kilowatthour (kWh) on electricity delivery in 2010, using 2020 dollars. In comparison, spending on delivery was 65% higher in 2020 at 4.3 cents/kWh, and residential bills rose in 2022 as inflation persisted. Conversely, utility spending on power production decreased from 6.8 cents/kWh in 2010 (using 2020 dollars) to 4.6 cents/kWh in 2020.

Utility spending on electricity delivery includes the money spent to build, operate, and maintain the electric wires, poles, towers, and meters that make up the transmission and distribution system. In real 2020 dollar terms, spending on electricity delivery increased every year from 1998 to 2020 as utilities worked to replace aging equipment, build transmission infrastructure to accommodate new wind and solar generation amid clean energy transition challenges that affect costs, and install new technologies such as smart meters to increase the efficiency, reliability, resilience, and security of the U.S. power grid.

Spending on power production includes the money spent to build, operate, fuel, and maintain power plants, as well as the cost to purchase power in cases where the utility either does not own generators or does not generate enough to fulfill customer demand. Spending on electricity production includes the cost of fuels including natural gas prices alongside capital, labor, and building materials, as well as the type of generators being built.

Other utility spending on electricity includes general and administrative expenses, general infrastructure such as office space, and spending on intangible goods such as licenses and franchise fees, even as electricity sales declined in recent years.

The retail price of electricity reflects the cost to produce and deliver power, the rate of return on investment that regulated utilities are allowed, and profits for unregulated power suppliers, and, as electricity prices at 41-year high have been reported, these components have drawn increased scrutiny.

In 2021, demand for consumer goods and the energy needed to produce them has been outpacing supply, though power demand sliding in 2023 with milder weather has also been noted. This difference has contributed to higher prices for fuels used by electric generators, especially natural gas. The increased cost for fuel, capital, labor, and building materials, as seen in the U.S. Bureau of Labor Statistics’ Producer Price Index, is increasing the cost of power production for 2021. U.S. average electricity prices have been higher every month of this year compared with 2020, according to our Monthly Electric Power Industry Report.

 

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Opinion: UK Natural Gas, Rising Prices and Electricity

European Energy Market Crisis drives record natural gas and electricity prices across the EU, as LNG supply constraints, Russian pipeline dependence, marginal pricing, and renewables integration expose volatility in liberalised power markets.

 

Key Points

A 2021 surge in European gas and electricity prices from supply strains, demand rebounds, and marginal pricing exposure.

✅ Record TTF gas and day-ahead power prices across Europe

✅ LNG constraints and Russian pipeline dependence tightened supply

✅ Debate over marginal pricing vs regulated models intensifies

 

By Ronan Bolton

The year 2021 was a turbulent one for energy markets across Europe, as Europe's energy nightmare deepened across the region. Skyrocketing natural gas prices have created a sense of crisis and will lead to cost-of-living problems for many households, as wholesale costs feed through into retail prices for gas and electricity over the coming months.

This has created immediate challenges for governments, but it should also encourage us to rethink the fundamental design of our energy markets as we seek to transition to net zero, with many viewing it as a wake-up call to ditch fossil fuels across the bloc.

This energy crisis was driven by a combination of factors: the relaxation of Covid-19 lockdowns across Europe created a surge in demand, while cold weather early in the year diminished storage levels and contributed to increasing demand from Asian economies. A number of technical issues and supply-side constraints also combined to limit imports of liquefied natural gas (LNG) into the continent.

Europe’s reliance on pipeline imports from Russia has once again been called into question, as Gazprom has refused to ride to the rescue, only fulfilling its pre-existing contracts. The combination of these, and other, factors resulted in record prices – the European benchmark price (the Dutch TTF Gas Futures Contract) reached almost €180/MWh on 21 December, with average day-ahead electricity prices exceeding €300/MWh across much of the continent in the following days.

Countries which rely heavily on natural gas as a source of electricity generation have been particularly exposed, with governments quickly put under pressure to intervene in the market.

In Spain the government and large energy companies have clashed over a proposed windfall tax on power producers. In Ireland, where wind and gas meet much of the country’s surging electricity demand, the government is proposing a €100 rebate for all domestic energy consumers in early 2022; while the UK government is currently negotiating a sector-wide bailout of the energy supply sector and considering ending the gas-electricity price link to curb bills.

This follows the collapse of a number of suppliers who had based their business models on attracting customers with low prices by buying cheap on the spot market. The rising wholesale prices, combined with the retail price cap previously introduced by the Theresa May government, led to their collapse.

While individual governments have little control over prices in an increasingly globalised and interconnected natural gas market, they can exert influence over electricity prices as these markets remain largely national and strongly influenced by domestic policy and regulation. Arising from this, the intersection of gas and power markets has become a key site of contestation and comment about the role of government in mitigating the impacts on consumers of rising fuel bills, even as several EU states oppose major reforms amid the price spike.

Given that renewables are constituting an ever-greater share of production capacity, many are now questioning why gas prices play such a determining role in electricity markets.

As I outline in my forthcoming book, Making Energy Markets, a particular feature of the ‘European model’ of liberalised electricity trade since the 1990s has been a reliance on spot markets to improve the efficiency of electricity systems. The idea was that high marginal prices – often set by expensive-to-run gas peaking plants – would signal when capacity limits are reached, providing clear incentives to consumers to reduce or delay demand at these peak periods.

This, in theory, would lead to an overall more efficient system, and in the long run, if average prices exceeded the costs of entering the market, new investments would be made, thus pushing the more expensive and inefficient plants off the system.

The free-market model became established during a more stable era when domestically-sourced coal, along with gas purchased on long-term contracts from European sources (the North Sea and the Netherlands), constituted a much greater proportion of electricity generation.

While prices fluctuated, they were within a somewhat predictable range, and provided a stable benchmark for the long-term contracts underpinning investment decisions. This is no longer the case as energy markets become increasingly volatile and disrupted during the energy transition.

The idea that free price formation in a competitive market, with governments standing back, would benefit electricity consumers and lead to more efficient systems was rooted in sound economic theory, and is the basis on which other major commodity markets, such as metals and agricultural crops, have been organised for decades.

The free-market model applied to electricity had clear limitations, however, as the majority of domestic consumers have not been exposed directly to real-time price signals. While this is changing with the roll-out of smart meters in many countries, the extent to which the average consumer will be willing or able to reduce demand in a predicable way during peak periods remains uncertain.

Also, experience shows that governments often come under pressure to intervene in markets if prices rise sharply during periods of scarcity, thus undermining a basic tenet of the market model, with EU gas price cap strategies floated as one option.

Given that gas continues to play a crucial role in balancing supply and demand for electricity, the options available to governments are limited, illustrating why rolling back electricity prices is harder than it appears for policymakers. One approach would be would be to keep faith with the liberalised market model, with limited interventions to help consumers in the short term, while ultimately relying on innovations in demand side technologies and alternatives to gas as a means of balancing systems with high shares of variable renewables.

An alternative scenario may see a return to old style national pricing policies, involving a move away from marginal pricing and spot markets, even as the EU prepares to revamp its electricity market in response. In the past, in particular during the post-WWII decades, and until markets were liberalised in the 1990s, governments have taken such an approach, centrally determining prices based on the costs of delivering long term system plans. The operation of gas plants and fuel procurement would become a much more regulated activity under such a model.

Many argue that this ‘traditional model’ better suits a world in which governments have committed to long-term decarbonisation targets, and zero marginal cost sources, such as wind and solar, play a more dominant role in markets and begin to push down prices.

A crucial question for energy policy makers is how to exploit this deflationary effect of renewables and pass-on cost savings to consumers, whilst ensuring that the lights stay on.

Despite the promise of storage technologies such as grid-scale batteries and hydrogen produced from electrolysis, aside from highly polluting coal, no alternative to internationally sourced natural gas as a means of balancing electricity systems and ensuring our energy security is immediately available.

This fact, above all else, will constrain the ambitions of governments to fundamentally transform energy markets.

Ronan Bolton is Reader at the School of Social and Political Science, University of Edinburgh and Co-Director of the UK Energy Research Centre. His book Making Energy Markets: The Origins of Electricity Liberalisation in Europe is to be published by Palgrave Macmillan in 2022.

 

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