Sailmaker looks to generate current

By Salem News


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Doyle Sailmakers, a local company with an international reach, may be on the verge of turning ocean currents into electric currents, Gov. Deval Patrick learned on a visit to the Salem sail loft recently.

Doyle is working with a New Hampshire company to fashion an efficient underwater turbine to harness steady, underwater currents for power. The design of the turbine's blades relies on Doyle's deep understanding of how sails power boats.

The potential for a sailmaker to help bolster the state's green economy and jobs was not lost on Patrick.

"What I learned today is there are some very, very intriguing new technologies being developed here," Patrick said.

Patrick, Salem Mayor Kim Driscoll and state Rep. John Keenan, D-Salem, and their respective entourages visited Doyle's headquarters in a new industrial park on Swampscott Road.

Doyle Sailmakers started in August 1982 in Marblehead at a time when there were 10 or 12 sailmakers in town, owner Robbie Doyle said. Several years ago, it moved to Salem, where it employs 35 people locally, down two or three from a few years ago.

In addition, there are 70 Doyle sail lofts around the world, and the company not only makes and services sails for local day sailors, its sails propel some of the world's largest and most expensive super yachts.

The sailmaker's motto, "Better Engineered Sails," may take on a whole new meaning if the company can create efficient underwater power turbines.

The governor and officials toured the cavernous sail loft, gingerly stepping on slick floors as workers knelt to work on sails spread around the 32,000-square-foot facility.

"I have never had so many blue blazers in my facility at once," said Doyle's wife, Janet.

While Patrick liked what he saw, he did not come bearing state help right away.

"I don't know yet what we can do, but one of the conversations we were having is what their needs are to help them get to the next stage," Patrick said.

The state has, through the Regional Greenhouse Gas Initiative, some resources the state can tap to invest in green technologies, Patrick said.

Massachusetts is one of 10 states that sell power plant emission allowances through auctions and invest the proceeds in energy-efficient and renewable energy projects, according to RGGI's website.

"Doyle grew and expanded and helped... embrace that technology because of a city investment and a state investment to actually put them here," Driscoll said. "They used to be in Marblehead, a much smaller company, a much smaller footprint. Now they are here, building sails, building airships, talking about other innovation."

Driscoll pointed out the building that houses the sail loft used to house Maynard Plastics. Several years ago, the facility was sold and carved into industrial condominiums.

"Now it's 10 different companies," many of which focus on innovation, Driscoll said. Driscoll met with Doyle a week ago, and, after she did so, she decided to take Patrick out to see what they were working on.

"You could see they are not designing it as a renewable energy product," Driscoll said. "They are designing it as an economic way to deliver electricity that happens to have a lot of renewable benefits."

So how did a sail company come to design an underwater power turbine?

Part of the reason, Doyle said, is the company takes an engineering approach to sail making. Doyle studied applied physics at Harvard University, and Doyle's son, Tyler, is the company's chief engineer.

About a year ago, Robert Houvener, president and founder of ScaleTera Renewable Energy LLC of Hollis, N.H., approached Doyle to create a new, more efficient water turbine using sail material.

The idea was to build big blades out of sail fabric that might withstand ocean currents.

"It turned out it was not cost-effective," Robbie Doyle said. But Doyle kept on working on the project.

"I loved everything I saw," Tyler said. "I had been working on wind turbines for the year or two before that." Tyler had been put off by the wind turbine's enormous cost for not a lot of power.

"The second you looked at the economics of this project, it just made so much more sense," Tyler said.

Turbines helped mills power the industrial revolution by harnessing power from swift-flowing rivers. However, traditional water turbines require high-speed currents of 8 to 10 knots and building structures that can stand up to that type of force, making them too expensive to build.

Doyle's technology requires slower but steady currents of about 3 knots. The turbines can be assembled in standard shipyards and don't rely on special, and expensive, ships and facilities.

The goal is to someday harness the currents of the Gulf Stream, the swift Atlantic Ocean currents off the East Coast or the Bosphorus Strait in Turkey.

"We had never built a propeller blade in our life," Robbie Doyle said, "but, again, it's just like a twisted sail, it's no different."

If all goes according to plan, Robbie Doyle said it could be a billion dollars-plus business in six years.

"We just have to come up with a technology, which we've done," Doyle said. "Now we just have to build it."

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Construction starts on disputed $1B electricity corridor

New England Clean Energy Connect advances despite court delays, installing steel poles on a Maine corridor for Canadian hydropower, while legal challenges seek environmental review; permits, jobs, and grid upgrades drive the renewable transmission project.

 

Key Points

An HV line in Maine delivering 1,200 MW of Canadian hydropower to New England to cut emissions and stabilize costs.

✅ Appeals court pauses 53-mile new section; upgrades continue

✅ 1,200 MW hydropower aims to cut emissions, stabilize rates

✅ Permits issued; environmental review litigation ongoing

 

Construction on part of a $1 billion electricity transmission corridor through sparsely populated woods in western Maine is on hold because of legal action, echoing Clean Line's Iowa withdrawal amid court uncertainty, but that doesn't mean all building has been halted.

Workers installed the first of 829 steel poles Tuesday on a widened portion of the existing corridor that is part of the project near The Forks, as the groundwork is laid for the 145-mile ( 230-kilometre ) New England Clean Energy Connect, a project central to Maine's debate over the 145-mile line moving forward.

The work is getting started even though the 1st U.S. Circuit Court of Appeals delayed construction of a new 53-mile ( 85-kilometre ) section.

Three conservation groups are seeking an injunction to delay the project while they sue to force the U.S. Army Corps of Engineers to conduct a more rigorous environmental review.

In western Maine, workers already have staged heavy equipment and timber “mats” that will be used to prevent the equipment from damaging the ground. About 275 Maine workers already have been hired, and more would be hired if not for the litigation, officials said.

“This project has always promised to provide an economic boost to Maine’s economy, and we are already seeing those benefits take shape," Thorn Dickinson, CEO of the New England Clean Energy Connect, said Tuesday.

The electricity transmission line would provide a conduit for up to 1,200 megawatts of Canadian hydropower, reducing greenhouse emissions and stabilizing energy costs in New England as states pursue Connecticut's market overhaul to improve market design, supporters say.

The project, which would be fully funded by Massachusetts ratepayers to meet the state's clean energy goals after New Hampshire rejected a Quebec-Massachusetts proposal elsewhere, calls for construction of a high-voltage power line from Mount Beattie Township on the Canadian border to the regional power grid in Lewiston, Maine.

Critics have been trying to stop the project, reflecting clashes over New Hampshire hydropower in the region, saying it would destroy wilderness in western Maine. They also say that the environmental benefits of the project have been overstated.

In addition to the lawsuit, opponents have submitted petitions seeking to have a statewide vote, even as a Maine court ruling on Hydro-Quebec exports has reshaped the legal landscape.

Sandi Howard, a leading opponent of the project, said the decision by the company to proceed showed “disdain for everyday Mainers” by ignoring permit appeals and ongoing litigation.

“For years, CMP has pushed the false narrative that their unpopular and destructive project is a ‘done deal’ to bully Mainers into submission on this for-profit project. But to be clear, we won’t stop until Maine voters (their customers), have the chance to vote,” said Howard, who led the referendum petition drive for the No CMP Corridor PAC.

The project has received permits from the Army Corps, Maine Department of Environmental Protection, Maine Land Use Planning Commission and Maine Public Utilities Commission.

The final approval came in the form of a presidential permit issued last month from the U.S. Department of Energy, providing green light for the interconnect at the Canadian border, even as customer backlash to utility acquisitions elsewhere underscores public scrutiny.

 

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Alberta Advances Electricity Plans with Rate of Last Resort

Alberta Rate of Last Resort provides a baseline electricity price, boosting energy reliability, affordability, and consumer protection amid market volatility, aligning with grid modernization, integration, pricing transparency, and oversight from the Alberta Utilities Commission.

 

Key Points

A fallback electricity rate ensuring affordable, reliable power and consumer protection during market volatility.

✅ Guarantees a stable baseline price when markets spike

✅ Supports vulnerable customers lacking competitive offers

✅ Overseen by AUC to balance protection and competition

 

The Alberta government has announced significant strides in its electricity market reforms, unveiling a new plan under new electricity rules that aims to enhance energy reliability and affordability for consumers. This initiative, highlighted by the introduction of a "rate of last resort," is a critical response to ongoing challenges in the province's electricity sector, particularly following recent market volatility and increasing consumer concerns about rising electricity prices across the province.

Understanding the Rate of Last Resort

The "rate of last resort" (RLR) is designed to ensure that all Albertans have access to affordable electricity, even when they face challenges securing a competitive rate in the open market. This measure is particularly beneficial for those who may not have the means or the knowledge to navigate complex energy contracts, such as low-income families or seniors.

Under this new plan, the RLR will serve as a safety net, guaranteeing a stable and predictable rate for customers who find themselves without a competitive provider. This move is seen as a crucial step in addressing the needs of vulnerable populations who might otherwise be at risk of being shut out of the energy market.

Market Volatility and Consumer Protection

Alberta's electricity market has faced significant fluctuations over the past few years, and is headed for a reshuffle as policymakers respond to unpredictability in pricing and service availability. The rise in energy costs has caused distress among consumers, with many advocating for stronger protections against sudden price hikes.

The government's recent decision to implement the RLR is a direct acknowledgment of these concerns. By creating a baseline rate, officials aim to provide consumers with peace of mind, knowing that there is a fallback option should market conditions turn unfavorable. This initiative complements other measures aimed at enhancing consumer protections, including improved transparency in pricing, the consumer price cap on power bills being advanced, and the regulation of energy suppliers.

Broader Implications for Alberta’s Energy Landscape

This plan is not only about consumer protection; it also represents a broader shift towards a more sustainable and stable energy market in Alberta, aligning with proposed electricity market changes under consideration. The introduction of the RLR is part of a comprehensive strategy that includes investments in renewable energy and infrastructure improvements. By modernizing the grid and promoting cleaner energy sources, the government aims to reduce dependency on fossil fuels while maintaining reliability and affordability.

Additionally, this move aligns with the province's goals to meet climate targets and transition to a more sustainable energy future as Alberta is changing how it produces and pays for electricity through policy updates. As the demand for clean energy grows, Alberta is positioning itself to be a leader in this transformation, appealing to both residents and businesses committed to sustainability.

Public and Industry Reactions

The announcement has garnered mixed reactions from various stakeholders. While consumer advocacy groups have largely praised the government's efforts to protect consumers and ensure affordable electricity, some industry experts express concerns about potential long-term impacts on competition, arguing the market needs competition to remain dynamic. They argue that while the RLR provides immediate relief, it could disincentivize companies from offering competitive rates, leading to a less dynamic market in the future.

The Alberta Utilities Commission (AUC) is expected to play a pivotal role in overseeing the implementation of the RLR, ensuring that it operates effectively and that any unintended consequences are addressed swiftly. This regulatory oversight will be crucial in balancing consumer protection with the need for a competitive energy market.

Conclusion

As Alberta forges ahead with its electricity market reforms, the introduction of the rate of last resort marks a significant step in enhancing consumer protection and ensuring energy affordability. While challenges remain, the government's proactive approach reflects a commitment to addressing the needs of all Albertans, particularly those most vulnerable to market fluctuations.

In this evolving energy landscape, the RLR will serve not only as a safety net for consumers but also as a foundation for a more sustainable and reliable electricity system. As Alberta continues to adapt to changing energy demands and climate considerations, the effectiveness of these measures will be closely monitored, shaping the future of the province’s electricity market.

 

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A resilient Germany is weathering the energy crunch

German Energy Price Brakes harness price signals in a market-based policy, cutting gas consumption, preserving industrial output, and supporting CO2 reduction, showcasing Germany's resilience and adaptation while protecting households and businesses across Europe.

 

Key Points

Fixed-amount subsidies preserving price signals to curb gas use, shield consumers, and sustain industrial output.

✅ Maintains incentives via market-based price signals

✅ Cuts gas consumption without distorting EU markets

✅ Protects households and industry while curbing CO2

 

German industry and society are once again proving much more resilient and adaptable than certain people feared. Horror scenarios of a dangerous energy rationing or a massive slump in our economy have often been bandied about. But we are nowhere near that. With a challenging year just behind us, this is good news — not only for Germany, but also for Europe, where France-Germany energy cooperation has strengthened solidarity.

Companies and households reacted swiftly to the sharp increases in energy prices, in line with momentum in the global energy transition seen across markets. They installed more efficient heating or production facilities, switched to alternatives and imported intermediate products. The results are encouraging: German households and businesses have reduced gas consumption significantly, despite recent cold weather. From the start of the war in Ukraine to mid-December industrial gas consumption in Germany was (temperature-adjusted) around 20 per cent lower than the average level for the preceding three years. Even if some firms have cut back production, especially in energy-intensive sectors, industrial output as a whole has only fallen by about 1 per cent since the start of 2022. Added to this, in a survey released by the Ifo institute in November, over a third of German companies saw the potential to reduce gas consumption further without endangering output.

Instead of imposing excessive laws and regulations, we have relied on price signals and the prudence of market participants to create the right incentives and reduce gas consumption, as falling costs like record-low solar power prices continue to reinforce those signals across sectors.

We will follow this approach in coming months, when energy savings will remain important, even as the EU electricity outlook anticipates sharply higher demand by 2050. Our latest relief measures will not distort price signals. To this end, the Bundestag approved gas and electricity price brakes in its final session in 2022. They are designed to function without any intervention in markets or prices. This system will pay out a fixed amount relative to previous years’ consumption and the current difference to a reference price — regardless of current consumption.

Energy price brakes are the main component of Germany’s “protective shield”, which makes up to €200bn available for measures in 2022 to 2024. Seen in relation to the German economy’s size, its past heavy reliance on Russian energy imports and the fact that the measures will expire in 2024, these are balanced and expedient mechanisms. In contrast to instruments used in other countries, our new arrangements will not affect the price formation process driven by supply and demand, or on incentives to save gas. Companies and households will continue to save the full market price when they reduce consumption by a unit of gas or electricity. In this way, the price brakes also avoid the creation of additional demand for gas at the expense of consumers in other European countries, even as Europe’s Big Oil turning electric signals broader structural shifts in energy markets. No one need fear that competition will be distorted or that gas will be bought up. Indeed, a recent IMF working paper on cushioning the impact of high energy prices on households explicitly praises the German energy price brakes.

Current developments confirm the effectiveness of a market-based approach — and show that we should also rely on price signals when it comes to reducing CO₂ emissions, as suggested by IEA CO2 trends in recent years. Last year, households and companies had only a few weeks to adapt, yet we have already seen a strong response. The effect of CO₂ prices can be even stronger, as adaptation is possible over a much longer time and they additionally affect expectations and long-term decisions. Regulatory interventions and subsidy schemes, even if well targeted, cannot compete with market co-ordination and incentives that support individual decision-making and promote innovation.

Europe and Germany can weather this crisis without a collapse in industrial production. We also have an opportunity to deal efficiently with the move to climate neutrality, aligned with Germany’s hydrogen strategy for imported low-carbon fuels. In both cases, we should have confidence in price signals as well as in the power of people and business to innovate and adapt.

 

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British Columbians can access more in EV charger rebates

B.C. EV Charging Rebates boost CleanBC incentives as NRCan and ZEVIP funding covers up to 75% of Level 2 and DC fast-charger purchase and installation costs for homes, workplaces, condos, apartments, and fleet operators.

 

Key Points

Incentives in B.C. cover up to 75% of Level 2 and DC fast charger costs for homes, workplaces, and fleets.

✅ Up to 75% back; Level 2 max $5,000; DC fast max $75,000 for fleets.

✅ Eligible sites: homes, workplaces, condos, apartments, fleet depots.

✅ Funded by CleanBC with NRCan ZEVIP; time-limited top-up.

 

The Province and Natural Resources Canada (NRCan) are making it more affordable for people to install electric vehicle (EV) charging stations in their homes, businesses and communities, as EV demand ramps up across the province.

B.C. residents, businesses and municipalities can receive higher rebates for EV charging stations through the CleanBC Go Electric EV Charger Rebate and Fleets programs. For a limited time, funding will cover as much as 75% of eligible purchase and installation costs for EV charging stations, which is an increase from the previous 50% coverage.

“With electric vehicles representing 13% of all new light-duty vehicles sold in B.C. last year, our province has the strongest adoption rate of electric vehicles in Canada. We’re positioning ourselves to become leaders in the EV industry,” said Bruce Ralston, B.C.’s Minister of Energy, Mines and Low Carbon Innovation. “We’re working with our federal partners to increase rebates for home, workplace and fleet charging, and making it easier and more affordable for people to make the switch to electric vehicles.”

With a $2-million investment through NRCan’s Zero-Emission Vehicle Infrastructure Program (ZEVIP) to top up the Province’s EV Charger Rebate program, workplaces, condominiums and apartments can get a rebate for a Level 2 charging station for as much as 75% of purchase and installation costs to a maximum of $5,000. As many as 360 EV chargers will be installed through the program.

“We’re making electric vehicles more affordable and charging more accessible where Canadians live, work and play,” said Jonathan Wilkinson, federal Minister of Natural Resources. “Investing in more EV chargers, like the ones announced today in British Columbia, will put more Canadians in the driver’s seat on the road to a net-zero future and help achieve our climate goals.”

Through the CleanBC Go Electric Fleets program and in support of B.C. businesses that own and operate fleet vehicles, NRCan has invested $1.54 million through ZEVIP to top up rebates. Fleet operators can get combined rebates from NRCan and the Province for a Level 2 charging station as much as 75% to a maximum of $5,000 of purchase and installation costs, and 75% to a maximum of $75,000 for a direct-current, fast-charging station. As many as 450 EV chargers will be installed through the program.

CleanBC is a pathway to a more prosperous, balanced and sustainable future. It supports government’s commitment to climate action to meet B.C.’s emission targets and build a cleaner, stronger economy.

Quick Facts:

  • A direct-current fast charger on the BC Electric Highway allows an EV to get 100-300 kilometres of range from 30 minutes of charging.
  • Faster chargers, which give more range in less time, are coming out every year.
  • A Level 2 charger allows an EV to get approximately 30 kilometres of range per hour of charging.
  • It uses approximately the same voltage as a clothes dryer and is usually installed in homes, workplaces or for fleets to get a faster charge than a regular outlet, or in public places where people might park for a longer time.
  • A key CleanBC action is to strengthen the Zero-Emission Vehicles Act to require light-duty vehicle sales to be 26% zero-emission vehicles (ZEVs) by 2026, 90% by 2030 and 100% by 2035, five years ahead of the original target.
  • At the end of 2021, B.C. had more than 3,000 public EV charging stations and almost 80,000 registered ZEVs.

Learn More:

To learn more about home and workplace EV charging-station rebates, eligibility and application processes, visit: https://goelectricbc.gov.bc.ca/   

To learn more about the Fleets program, visit: https://pluginbc.ca/go-electric-fleets/    

To learn more about Natural Resources Canada’s Zero-Emission Vehicle Infrastructure Program, visit:
https://www.nrcan.gc.ca/energy-efficiency/transportation-alternative-fuels/zero-emission-vehicle-infrastructure-program/21876

 

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Cleaning up Canada's electricity is critical to meeting climate pledges

Canada Clean Electricity Standard targets a net-zero grid by 2035, using carbon pricing, CO2 caps, and carbon capture while expanding renewables and interprovincial trade to decarbonize power in Alberta, Saskatchewan, and Ontario.

 

Key Points

A federal plan to reach a net-zero grid by 2035 using CO2 caps, carbon pricing, carbon capture, renewables, and trade.

✅ CO2 caps and rising carbon prices through 2050

✅ Carbon capture required on gas plants in high-emitting provinces

✅ Renewables build-out and interprovincial trade to balance supply

 

A new tool has been proposed in the federal election campaign as a way of eradicating the carbon emissions from Canada’s patchwork electricity system. 

As the country’s need for power grows through the decarbonization of transportation, industry and space heating, the Liberal Party climate plan is proposing a clean energy standard to help Canada achieve a 100% net-zero-electricity system by 2035, aligning with Canada’s net-zero by 2050 target overall. 

The proposal echoes a report released August 19 by the David Suzuki Foundation and a group of environmental NGOs that also calls for a clean electricity standard, capping power-sector emissions, and tighter carbon-pricing regulations. The report, written by Simon Fraser University climate economist Mark Jaccard and data analyst Brad Griffin, asserts that these policies would effectively decarbonize Canada’s electricity system by 2035.

“Fuel switching from dirty fossil fuels to clean electricity is an essential part of any serious pathway to transition to a net-zero energy system by 2050,” writes Tom Green, climate policy advisor to the Suzuki Foundation, in a foreword to the report. The pathway to a net-zero grid is even more important as Canada switches from fossil fuels to electric vehicles, space heating and industrial processes, even as the Canadian Gas Association warns of high transition costs.

Under Jaccard and Griffin’s proposal, a clean electricity standard would be established to regulate CO2 emissions specifically from power plants across Canada. In addition, the plan includes an increase in the carbon price imposed on electricity system releases, combined with tighter regulation to ensure that 100% of the carbon price set by the federal government is charged to electricity producers. The authors propose that the current scheduled carbon price of $170 per tonne of CO2 in 2030 should rise to at least $300 per tonne by 2050.

In Alberta, Saskatchewan, Ontario, New Brunswick and Nova Scotia, the 2030 standard would mean that all fossil-fuel-powered electricity plants would require carbon capture in order to comply with the standard. The provinces would be given until 2035 to drop to zero grams CO2 per kilowatt hour, matching the 2030 standard for low-carbon provinces (Quebec, British Columbia, Manitoba, Newfoundland and Labrador and Prince Edward Island). 

Alberta and Saskatchewan targeted 
Canada has a relatively clean electricity system, as shown by nationwide progress in electricity, with about 80% of the country’s power generated from low- or zero-emission sources. So the biggest impacts of the proposal will be felt in the higher-carbon provinces of Alberta and Saskatchewan. Alberta has a plan to switch from coal-based electric power to natural gas generation by 2023. But Saskatchewan is still working on its plan. Under the Jaccard-Griffin proposal, these provinces would need to install carbon capture on their gas-fired plants by 2030 and carbon-negative technology (biomass with carbon capture, for instance) by 2035. Saskatchewan has been operating carbon capture and storage technology at its Boundary Dam power station since 2014, but large-scale rollout at power plants has not yet been achieved in Canada. 

With its heavy reliance on nuclear and hydro generation, Ontario’s electricity supply is already low carbon. Natural gas now accounts for about 7% of the province’s grid, but the clean electricity standard could pose a big challenge for the province as it ramps up natural-gas-generated power to replace electricity from its aging Pickering station, scheduled to go out of service in 2025, even as a fully renewable grid by 2030 remains a debated goal. Pickering currently supplies about 14% of Ontario’s power. 

Ontario doesn’t have large geological basins for underground CO2 storage, as Alberta and Saskatchewan do, so the report says Ontario will have to build up its solar and wind generation significantly as part of Canada’s renewable energy race, or find a solution to capture CO2 from its gas plants. The Ontario Clean Air Alliance has kicked off a campaign to encourage the Ontario government to phase out gas-fired generation by purchasing power from Quebec or installing new solar or wind power.

As the report points out, the federal government has Supreme Court–sanctioned authority to impose carbon regulations, such as a clean electricity standard, and carbon pricing on the provinces, with significant policy implications for electricity grids nationwide.

The federal government can also mandate a national approach to CO2 reduction regardless of fuel source, encouraging higher-carbon provinces to work with their lower-carbon neighbours. The Atlantic provinces would be encouraged to buy power from hydro-heavy Newfoundland, for example, while Ontario would be encouraged to buy power from Quebec, Saskatchewan from Manitoba, and Alberta from British Columbia.

The Canadian Electricity Association, the umbrella organization for Canada’s power sector, did not respond to a request for comment on the Jaccard-Griffin report or the Liberal net-zero grid proposal.

Just how much more clean power will Canada need? 
The proposal has also kicked off a debate, and an IEA report underscores rising demand, about exactly how much additional electricity Canada will need in coming decades.

In his 2015 report, Pathways to Deep Decarbonization in Canada, energy and climate analyst Chris Bataille estimated that to achieve Canada’s climate net-zero target by 2050 the country will need to double its electricity use by that year.

Jaccard and Griffin agree with this estimate, saying that Canada will need more than 1,200 terawatt hours of electricity per year in 2050, up from about 640 terawatt hours currently.

But energy and climate consultant Ralph Torrie (also director of research at Corporate Knights) disputes this analysis.

He says large-scale programs to make the economy more energy efficient could substantially reduce electricity demand. A major program to install heat pumps and replace inefficient electric heating in homes and businesses could save 50 terawatt hours of consumption on its own, according to a recent report from Torrie and colleague Brendan Haley. 

Put in context, 50 terawatt hours would require generation from 7,500 large wind turbines. Applied to electric vehicle charging, 50 terawatt hours could power 10 million electric vehicles.

While Torrie doesn’t dispute the need to bring the power system to net-zero, he also doesn’t believe the “arm-waving argument that the demand for electricity is necessarily going to double because of the electrification associated with decarbonization.” 

 

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N.S. approves new attempt to harness Bay of Fundy's powerful tides

Bay of Fundy Tidal Energy advances as Nova Scotia permits Jupiter Hydro to test floating barge platforms with helical turbines in Minas Passage, supporting renewable power, grid-ready pilots, and green jobs in rural communities.

 

Key Points

A Nova Scotia tidal energy project using helical turbines to generate clean power and create local jobs.

✅ Permits enable 1-2 MW prototypes near Minas Passage

✅ Floating barge platforms with patented helical turbines

✅ PPA at $0.50/kWh with Nova Scotia Power

 

An Alberta-based company has been granted permission to try to harness electricity from the powerful tides of the Bay of Fundy.

Nova Scotia has issued two renewable energy permits to Jupiter Hydro.

Backers have long touted the massive energy potential of Fundy's tides -- they are among the world's most powerful -- but large-scale commercial efforts to harness them have borne little fruit so far, even as a Scottish tidal project recently generated enough power to supply nearly 4,000 homes elsewhere.

The Jupiter application says it will use three "floating barge type platforms" carrying its patented technology. The company says it uses helical turbines mounted as if they were outboard motors.

"Having another company test their technology in the Bay of Fundy shows that this early-stage industry continues to grow and create green jobs in our rural communities," Energy and Mines Minister Derek Mombourquette said in a statement.

The first permit allows the company to test a one-megawatt prototype that is not connected to the electricity grid.

The second -- a five-year permit for up to two megawatts -- is renewable if the company meets performance standards, environmental requirements and community engagement conditions.

Mombourquette also authorized a power purchase agreement that allows the company to sell the electricity it generates to the Nova Scotia grid through Nova Scotia Power for 50 cents per kilowatt hour.

On its web site, Jupiter says it believes its approach "will prove to be the most cost effective marine energy conversion technology in the world," even as other regional utilities consider initiatives like NB Power's Belledune concept for turning seawater into electricity.

The one megawatt unit would have screws which are about 5.5 metres in diameter.

The project is required to obtain all other necessary approvals, permits and authorizations.

It will be located near the Fundy Ocean Research Center for Energy in the Minas Passage and will use existing electricity grid connections.

A study commissioned by the Offshore Energy Research Association of Nova Scotia says by 2040, the tidal energy industry could contribute up to $1.7 billion to Nova Scotia's gross domestic product and create up to 22,000 full-time jobs, a transition that some argue should be planned by an independent body to ensure reliability.

Last month, Nova Scotia Power said it now generates 30 per cent of its power from renewables, as the province moves to increase wind and solar projects after abandoning the Atlantic Loop.

The utility says 18 per cent came from wind turbines, nine per cent from hydroelectric and tidal turbines and three per cent by burning biomass across its fleet.

However, over half of the province's electrical generation still comes from the burning of coal or petroleum coke, even as environmental advocates push to reduce biomass use in the mix. Another 13 per cent come from burning natural gas and five per cent from imports.

 

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