New Trade Rules May Stifle Scotland Renewables

India Electricity Production 2017 surged to 1,160 BU, ranking third globally; rising TWh output with 334 GW capacity, strong renewables and thermal mix, 7% CAGR in generation, and growing demand, investments, and FDI inflows.

Key Points

India's 2017 power output reached 1,160 BU, third globally, supported by 334 GW capacity, rising renewables, and 7% CAGR.

✅ 1,160 BU generated; third after China and the US

✅ Installed capacity 334 GW; 65% thermal, rising renewables

✅ Generation CAGR ~7%; demand, FDI, investments rising

India now generates around 1,160.1 billion units of electricity in financial year 2017, up 4.72% from the previous year, and amid surging global electricity demand that is straining power systems. The country is behind only China which produced 6,015 terrawatt hours (TWh. 1 TW = 1,000,000 megawatts) and the US (4,327 TWh), and is ahead of Russia, Japan, Germany, and Canada.

India’s electricity production grew 34% over seven years to 2017, and the country now produces more energy than Japan and Russia, which had 27% and 8.77% more electricity generation capacity installed, respectively, than India seven years ago.

India produced 1,160.10 billion units (BU) of electricity–one BU is enough to power 10 million households (one household using average of about 3 units per day) for a month–in financial year (FY) 2017. Electricity production stood at 1,003.525 BU between April 2017-January 2018, according to a February 2018 report by India Brand Equity Foundation (IBEF), a trust established by the commerce ministry.

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With a production of 1,423 BU in FY 2016, India was the third largest producer and the third largest consumer of electricity in the world, behind China (6,015 BU) and the United States (4,327 BU).

With an annual growth rate of 22.6% capacity addition over a decade to FY 2017, renewables beat other power sources–thermal, hydro and nuclear. Renewables, however, made up only 18.79% of India’s energy, up 68.65% since 2007, and globally, low-emissions sources are expected to cover most demand growth in the coming years. About 65% of installed capacity continues to be thermal.

As of January 2018, India has installed power capacity of 334.4 gigawatt (GW), making it the fifth largest installed capacity in the world after European Union, China, United States and Japan, and with much of the fleet coal-based, imported coal volumes have risen at times amid domestic supply constraints.

The government is targeting capacity addition of around 100 GW–the current power production of United Kingdom–by 2022, as per the IBEF report.

Electricity generation grew at 7% annually

India achieved a 34.48% growth in electricity production by producing 1,160.10 BU in 2017 compared to 771.60 BU in 2010–meaning that in these seven years, electricity production in India grew at a compound annual growth rate (CAGR) of 7.03%, while thermal power plants' PLF has risen recently amid higher demand and lower hydro.

Generation capacity grew at 10% annually

Of 334.5 GW installed capacity as of January 2018–up 60% from 132.30 GW in 2007–thermal installed capacity was 219.81 GW. Hydro and renewable energy installed capacity totaled 44.96 GW and 62.85 GW, respectively, said the report.

The CAGR in installed capacity over a decade to 2017 was 10.57% for thermal power, 22.06% for renewable energy–the fastest among all sources of power–2.51% for hydro power and 5.68% for nuclear power.

Growing demand, higher investments will drive future growth

Growing population and increasing penetration of electricity connections, along with increasing per-capita usage would provide further impetus to the power sector, said the report.

Power consumption is estimated to increase from 1,160.1 BU in 2016 to 1,894.7 BU in 2022, as per the report, though electricity demand fell sharply in one recent period.

Increasing investment remained one of the driving factors of power sector growth in the country.

Power sector has a 100% foreign direct investment (FDI) permit, which boosted FDI inflows in the sector.

Total FDI inflows in the power sector reached $12.97 billion (Rs 83,713 crore) during April 2000 to December 2017, accounting for 3.52% of FDI inflows in India, the report said.

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Champlain Hudson Power Express connects Hydro-Québec hydropower to the New York grid via a 1.25 GW high voltage transmission line, enabling renewable energy imports, grid decarbonization, storage synergy, and reduced fossil fuel generation.

Key Points

A 1.25 GW cross-border transmission project delivering Hydro-Québec hydropower to New York City to displace fossil power.

✅ 1.25 GW buried HV line from Quebec to Astoria, Queens

✅ Supports renewable imports and grid decarbonization in NYC

✅ Enables two-way trade and reservoir storage synergy

Last week, Quebec Premier François Legault took to Twitter to celebrate after New York State authorities tentatively approved the first new transmission line in three decades, the Champlain Hudson Power Express, that would connect Quebec’s vast hydroelectric network to the northeastern U.S. grid.

“C’est une immense nouvelle pour l’environnement. De l’énergie fossile sera remplacée par de l’énergie renouvelable,” he tweeted, or translated to English: “This is huge news for the environment. Fossil fuels will be replaced by renewable energy.”

The proposed construction of a 1.25 gigawatt transmission line from southern Quebec to Astoria, Queens, known as the Champlain Hudson Power Express, ties into a longer term strategy by Hydro Québec: in the coming decade, as cities such as New York and Boston look to transition away from fossil fuel-generated electricity and decarbonize their grids, Hydro-Québec sees opportunities to supply them with energy from its vast network of 61 hydroelectric generating stations and other renewable power, as Quebec has closed the door on nuclear power in recent years.

Already, the provincial utility is one of North America’s largest energy producers, generating $2.3 billion in net income in 2020, and planning to increase hydropower capacity over the near term. Hydro-Quebec has said it intends to increase exports and had set a goal of reaching $5.2 billion in net income by 2030, though its forecasts are currently under review.

But just as oil and gas companies have encountered opposition to nearly every new pipeline, Hydro-Québec is finding resistance as it seeks to expand its pathways into major export markets, which are all in the U.S. northeast. Indeed, some fossil fuel companies that would be displaced by Hydro-Québec are fighting to block the construction of its new transmission lines.

“Linear projects — be it a transmission line or a pipeline or highway or whatever — there’s always a certain amount of public opposition,” Gary Sutherland, director of strategic affairs and stakeholder relations for Hydro-Québec, told the Financial Post, “which is a good thing because it makes the project developer ask the right questions.”

While Sutherland said he isn’t expecting opposition to the line into New York, he acknowledged Hydro-Québec also didn’t fully anticipate the opposition encountered with the New England Clean Energy Connect, a 1.2 gigawatt transmission line that would cost an estimated US$950 million and run from Quebec through Maine, eventually connecting to Massachusetts’ grid.

In Maine, natural gas and nuclear energy companies, which stand to lose market share, and also environmentalists, who oppose logging through sensitive habitat, both oppose the project.

In August, Maine’s highest court invalidated a lease for the land where the lines were slated to be built, throwing permits into question. Meanwhile, Calpine Corporation and Vistra Energy Corp., both Texas-based companies that operate natural gas plants in Maine, formed a political action committee called Mainers for Local Power. It has raised nearly US$8 million to fight the transmission line, according to filings with the Maine Ethics Commission.

Neither Calpine nor Vistra could be reached for comment by the time of publication.

“It’s been 30 years since we built a transmission line into the U.S. northeast,” said Sutherland. “In that time we have increased our exports significantly … but we haven’t been able to build out the corresponding transmission to get that energy from point A to point B.”

Indeed, since 2003, Hydro-Québec’s exports outside the province have grown from roughly two terrawatts per year to more than 30 terrawatts, including recent deals with NB Power to move more electricity into New Brunswick. The provincial utility produces around 210 terrawatts annually, but uses less than 178 terrawatts in Quebec.

Linear projects — be it a transmission line or a pipeline or highway or whatever — there’s always a certain amount of public opposition

In Massachusetts, it has signed contracts to supply 9.4 terrawatts annually — an amount roughly equivalent to 8 per cent of the New England region’s total consumption. Meanwhile, in New York, Hydro-Québec is in the final stages of negotiating a 25-year contract to sell 10.4 terawatts — about 20 per cent of New York City’s annual consumption.

In his tweets, Legault described the New York contract as being worth more than $20 billion over 25 years, although Hydro Québec declined to comment on the value because the contract is still under negotiation and needs approval by New York’s Public Services Commission — expected by mid-December.

Both regions are planning to build out solar and wind power to meet their growing clean energy needs and reach ambitious 2030 decarbonization targets. New York has legislated a goal of 70 per cent renewable power by that time, while Massachusetts has called for a 50 per cent reduction in emissions in the same period.

Hydro-Quebec signage is displayed on a manhole cover in Montreal. PHOTO BY BRENT LEWIN/BLOOMBERG FILES
According to a 2020 paper titled “Two Way Trade in Green Electrons,” written by three researchers at the Center for Energy and Environmental Policy Research at the Massachusetts’ Institute for Technology, Quebec’s hydropower, which like fossil fuels can be dispatched, will help cheaply and efficiently decarbonize these grids.

“Today transmission capacity is used to deliver energy south, from Quebec to the northeast,” the researchers wrote, adding, “…in a future low-carbon grid, it is economically optimal to use the transmission to send energy in both directions.”

That is, once new transmission lines and wind and solar power are built, New York and Massachusetts could send excess energy into Quebec where it could be stored in hydroelectric reservoirs until needed.

“This is the future of this northeast region, as New York state and New England are decarbonizing,” said Sutherland. “The only renewable energies they can put on the grid are intermittent, so they’re going to need this backup and right to the north of them, they’ve got Hydro-Québec as backup.”

Hydro-Québec already sells roughly 7 terrawatts of electricity per year into New York on the spot market, but Sutherland says it is constrained by transmission constraints that limit additional deliveries.

And because transmission lines can cost billions of dollars to build, he said Hydro-Québec needs the security of long-term contracts that ensure it will be paid back over time, aligning with its broader $185-billion transition strategy to reduce reliance on fossil fuels.

Sutherland expressed confidence that the Champlain Hudson Power Express project would be constructed by 2025. He noted its partners, Blackstone-backed Transmission Developers, have been working on the project for more than a decade, and have already won support from labour unions, some environmental groups and industry.

The project calls for a barge to move through Lake Champlain and the Hudson River, and dig a trench while unspooling and burying two high voltage cables, each about 10-12 centimetres in diameter. In certain sections of the Hudson River, known to have high concentrations of PCP pollutants, the cable would be buried underground alongside the river.

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Iraq Electricity Crisis intensifies as summer heat drives demand; households face power outages, reliance on private generators, distorted tariffs, and strained grid capacity despite government reforms, Siemens upgrades, and IEA warnings.

Key Points

A supply-demand gap causing outages, generator reliance, and grid inefficiencies across Iraq, worsened by summer peaks.

✅ Siemens deal to upgrade generation and grid

✅ Progressive tariffs to curb demand and waste

✅ Private generators fill gaps but raise costs

At a demonstration in June 2018, protesters in Basra loaded a black box resembling a coffin with the inscription “Electricity” onto the roof of a car. This was one demonstration of how much of a political issue electricity is in Iraq.

With what is likely to be another hot summer ahead, there is increasing pressure on the Baghdad government to improve access to electricity and water.

Many Iraqis blame the government for not providing adequate services despite the country’s oil wealth. Protests in southern Iraq last year turned violent, with demonstrators attacking governmental and political parties’ buildings; in neighboring Iran, blackouts also sparked protests over outages.

“It is very hard” to deal with the electricity issues, said Iraqi journalist Methaq al-Fayyadh, adding that the lack of reliable electricity was not a new problem and affects most parts of the country.

Dozens of people protested June 1 in Karbala against prices for new generators and demanded an improvement to the electricity situation.

In anticipation of high temperatures during Eid al-Fitr, the Electricity Ministry called on governorates to adhere to allocated quotas and told the public to ration electricity.

“Outages remain a daily occurrence for most households because increasing generating capacity has been outrun by increasing demand for electricity, as surging demand worldwide demonstrates,” noted the International Energy Agency (IAE) in April.

This is particularly the case, the authors said, as the hot summer months, when temperatures can top 50 degrees Celsius, drive up the use of air conditioning.

The Iraqi government has made improving the electricity supply one of its priorities, including nuclear power plans under consideration. The Electricity Ministry, headed by Luay al-Khatteeb, announced in May that national electricity production had reached 17 gigawatts.

Khatteeb presented comparative electricity data for May from 2018 and 2019, indicating production increases on every day of the month. IEA data indicate that available electricity supply has increased over the past five years and the gap between supply and demand has widened.

The government signed an agreement with German company Siemens this year to upgrade Iraq’s electricity grid, and in parallel deals with Iran to rehabilitate and develop the grid were finalized, according to Iranian officials. The agreement “includes the addition of new and highly efficient power generation capacity, rehabilitation and upgrade of existing plants and the expansion of transmission and distribution networks,” Siemens said.

The Iraqi prime minister’s office said the 4-year plan would be worth $15.7 billion. The first phase includes the installation of 13 transformer stations, cooling systems for power stations and building a 500-megawatt, gas-fired power plant south of Baghdad.

In an interview with Al-Monitor, Khatteeb said radical changes would happen in 2020, stating that the current situation was not “ideal” but “better” because of steps taken to create more energy, amid discussions on energy cooperation with Iran that could shape implementation.

Robert Tollast, of the Iraq Energy Institute, said the economics of the electricity system is distorted. Subsidies ensured that electricity provided by the national grid is almost free, he said. However, while the subsidies were designed to help the poor, the tariff system disadvantages them and does not create incentives to consume electricity more efficiently, he said.

A large part of families’ electricity expenditures goes to operators of privately owned generators, which run on fuel. These neighbourhood generators are used to close gaps in the electricity supply but are expensive, and regional fuel arrangements such as ENOC’s swap of Iraqi fuel have highlighted supply constraints. Generator operators have sometimes worked with armed groups to prevent upgrades to the grid that could hurt their business.

Until 1990, the Iraq electricity sector was considered among the best in the region. That legacy was destroyed by successive wars and international sanctions. With Iraq’s population growing at a rate of 1 million per year, peak demand is projected to double by 2030 if left unchecked, the IEA estimated.

Tollast said efforts to improve the distribution system and increase capacity are key but it is important “to tackle the problem from the demand side.” This entails implementing a progressive tariff scheme so users pay more if they consume more, he said. There is a “tremendous use of energy per capita in Iraq,” Tollast said.

In the current tariff structure, consumers pay a fixed price if they use more than 4,000-kilowatt hours per year, a relatively low amount, meaning the price per unit drops the more one consumes.

Any change to the tariff system must be accompanied by a “political campaign” to explain the changes, said Tollast, adding that more investment in the electricity sector and a “change in culture” of using electricity was needed. “The current system is unsustainable, even with high oil prices,” he said.

Fayyadh said people don’t expect the government will be able to fix the electricity issue before summer, having failed to do so in the past.

Tollast struck a more optimistic tone, saying it was unlikely that Iran, which supplies about 40% of Iraq’s power, would cut its export of electricity to Iraq this year as it did in 2018. He added that the water situation was better than last year when the country experienced drought. Iraq has also been processing more flare gas, which can be used to generate electricity.

“There is an expectation that this year might not be as bad as last year,” he concluded.

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CAISO Clean Energy Transition outlines California's path to 100% carbon-free power by 2045, scaling renewables, battery storage, and offshore wind while safeguarding grid reliability, managing natural gas, and leveraging Western markets like EDAM.

Key Points

CAISO Clean Energy Transition is the plan to reach 100% carbon-free power by 2045 while maintaining grid reliability.

✅ Target: add 7 GW/year to reach 120 GW capacity by 2045

✅ Battery storage up 30x; smooths intermittent solar and wind

✅ EDAM and WEIM enhance imports, savings, and reliability

Mark Rothleder, Chief Operating Officer and Senior Vice President at the California Independent System Operator (CAISO), which manages roughly 80% of California’s electric grid, has expressed cautious optimism about meeting the state's ambitious clean energy targets while keeping the lights on across the grid. However, he acknowledges that this journey will not be without its challenges.

California aims to transition its power system to 100% carbon-free sources by 2045, ensuring a reliable electricity supply at reasonable costs for consumers. Rothleder, aware of the task's enormity, likens it to a complex car repair performed while the vehicle is in motion.

Recent achievements have demonstrated California's ability to temporarily sustain its grid using clean energy sources. According to Rothleder, the real challenge lies in maintaining this performance round the clock, every day of the year.

Adding thousands of megawatts of renewable energy into California’s existing 50-gigawatt system, which needs to expand to 120 gigawatts to meet the 2045 goal, poses a significant challenge, though recent grid upgrade funding offers some support for needed infrastructure. CAISO estimates that an addition of 7 gigawatts of clean power per year for the next two decades is necessary, all while ensuring uninterrupted power delivery.

While natural gas currently constitutes California's largest single source of power, Rothleder notes the need to gradually decrease reliance on it, even as it remains an operational necessity in the transition phase.

In 2023, CAISO added 5,660 megawatts of new power to the grid, with plans to integrate over 1,100 additional megawatts in the next six to eight months of 2024. Battery storage, crucial for mitigating the intermittent nature of wind and solar power, has seen substantial growth as California turns to batteries for grid support, increasing 30-fold in three years.

Rothleder emphasizes that electricity reliability is paramount, as consumers always expect power availability. He also highlights the potential of offshore wind projects to significantly contribute to California's power mix by 2045.

The offshore wind industry faces financial and supply chain challenges despite these plans. CAISO’s 20-year outlook indicates a significant increase in utility-scale solar, requiring extensive land use and wider deployment of advanced inverters for grid stability.

Addressing affordability is vital, especially as California residents face increasing utility bills. Rothleder suggests a broader energy cost perspective, encompassing utility and transportation expenses.

Despite smooth grid operations in 2023, challenges in previous years, including extreme weather-induced power outages driven by climate change, underscore the need for a robust, adaptable grid. California imports about a quarter of its power from neighbouring states and participates in the Western Energy Imbalance Market, which has yielded significant savings.

CAISO is also working on establishing an extended day-ahead electricity market (EDAM) to enhance the current energy market's success, building on insights from a Western grid integration report that supports expanded coordination.

Rothleder believes that a thoughtfully designed, diverse power system can offer greater reliability and resilience in the long run. A future grid reliant on multiple, smaller power sources such as microgrids could better absorb potential losses, ensuring a more reliable electricity supply for California.

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California Storm Outages and Landslides strain utilities, trigger flooding, road closures, and debris flows, causing widespread power cuts and infrastructure damage as emergency response teams race to restore service, clear slides, and support evacuations.

Key Points

California Storm Outages and Landslides are storm-driven power cuts and slope failures disrupting roads and utilities.

✅ Tens of thousands face prolonged power outages across regions

✅ Landslides block highways, damage property, hinder access

✅ Crews restore grids, clear debris, support shelters and evacuees

California is grappling with a dual crisis of power outages and landslides following a severe storm that has swept across the state. The latest reports indicate widespread disruptions affecting thousands of residents and significant infrastructure damage. This storm is not only a test of California's emergency response capabilities but also a stark reminder of the increasing vulnerability of the state to extreme weather events, and of the U.S. electric grid in the face of climate stressors.

Storm’s Impact on California

The recent storm, which hit California with unprecedented intensity, has unleashed torrential rain, strong winds, and widespread flooding. These severe weather conditions have overwhelmed the state’s infrastructure, leading to significant power outages that are affecting numerous communities. According to local utilities, tens of thousands of homes and businesses are currently without electricity. The outages have been exacerbated by the combination of heavy rain and gusty winds, which have downed power lines and damaged electrical equipment.

In addition to the power disruptions, the storm has triggered a series of landslides across various regions. The combination of saturated soil and intense rainfall has caused several hillside slopes to give way, leading to road closures and property damage. Emergency services are working around the clock to address the aftermath of these landslides, but access to affected areas remains challenging due to blocked roads and ongoing hazardous conditions.

Emergency Response and Challenges

California’s emergency response teams are on high alert as they coordinate efforts to manage the fallout from the storm. Utility companies are deploying repair crews to restore power as quickly as possible, but the extensive damage to infrastructure means that some areas may be without electricity for several days. The state’s Department of Transportation is also engaged in clearing debris from landslides and repairing damaged roads to ensure that emergency services can reach affected communities.

The response efforts are complicated by the scale of the storm’s impact. With many areas experiencing both power outages and landslides, the logistical challenges are immense. Emergency shelters have been set up to provide temporary refuge for those displaced by the storm, but the capacity is limited, and there are concerns about overcrowding and resource shortages.

Community and Environmental Implications

The storm’s impact on local communities has been profound. Residents are facing not only the immediate challenges of power outages and unsafe road conditions but also longer-term concerns about recovery and rebuilding. Many individuals have been forced to evacuate their homes, and local businesses are struggling to cope with the disruption.

Environmental implications are also significant. The landslides and flooding have caused considerable damage to natural habitats and have raised concerns about water contamination and soil erosion. The impact on the environment could have longer-term consequences for the state’s ecosystems and water supply.

Climate Change and Extreme Weather

This storm underscores a growing concern about the increasing frequency and intensity of extreme weather events linked to climate change. California has been experiencing a rise in severe weather patterns, including intense storms, prolonged droughts, and extreme heat waves that strain the grid. These changes are putting additional strain on the state’s infrastructure and emergency response systems.

Experts have pointed out that while individual storms cannot be directly attributed to climate change, the overall trend towards more extreme weather is consistent with scientific predictions. As such, there is a pressing need for California to invest in infrastructure improvements and resilience measures, and to consider accelerating its carbon-free electricity mandate to better withstand future events.

Looking Ahead

As California deals with the immediate aftermath of this storm, attention will turn to recovery and rebuilding efforts. The state will need to address the damage caused by power outages and landslides while also preparing for future challenges posed by climate change.

In the coming days, the focus will be on restoring power, clearing debris, and providing support to affected communities. Long-term efforts will likely involve reassessing infrastructure vulnerabilities, improving emergency response protocols, and investing in climate resilience measures across the grid.

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BC Ferries Island Class hybrid ferries deliver quiet, battery-electric travel with shore power readiness, lower emissions, and larger capacity on northern routes, protecting marine wildlife while replacing older vessels on Powell River and Texada services.

Key Points

Hybrid-electric ferries using batteries and diesel for quiet, low-emission service, ready for shore power upgrades.

✅ Operate 20% electric at launch; future full-electric via shore power

✅ 300 passengers, 47 vehicles; replacing older, smaller vessels

✅ Quieter transits help protect West Coast whales and marine habitat

In a champagne celebration, BC Ferries welcomed two new, hybrid-electric ships into its fleet Wednesday. The ships arrived in Victoria last month, and are expected to be in service on northern routes by the summer.

The Island Aurora and Island Discovery have the ability to run on either diesel or electricity.

"The pressure on whales on the West Coast is very intense right now," said BC Ferries CEO Mark Collins. "Quiet operation is very important. These ships will be gliding out of the harbor quietly and electrically with no engines running, that will be really great for marine space."

BC Ferries says the ships will be running on electricity 20 per cent of the time when they enter service, but the company hopes they can run on electricity full-time in the future. That would require the installation of shoreline power, which the company hopes to have in place in the next five to 10 years. Each ship costs around $40-million, a price tag that the federal government partially subsidized through CIB support as part of the electrification push.

When the two ships begin running on the Powell River to Texada, and Port McNeill, Alert Bay, and Sointula routes, two older vessels will be retired.

On Kootenay Lake, an electric-ready ferry is slated to begin operations in 2023, reflecting the province's wider shift.

"They are replacing a 47-car ferry, but on some routes they will be replacing a 25-car ferry, so those routes will see a considerable increase in service," said Collins.

Although the ships will not be servicing Colwood, the municipality's mayor is hoping that one day, they will.

"We can look at an electric ferry when we look at a West Shore ferry that would move Colwood residents to Victoria," said Mayor Rob Martin, noting that across the province electric school buses are hitting the road as well. "Here is a great example of what BC Ferries can do for us."

BC Ferries says it will be adding four more hybrid ships to its fleet by 2022, and is working on adding hybrid ships that could run from Victoria to Tsawwassen, similar to Washington State Ferries' hybrid upgrade underway in the region. 

B.C’s first hybrid-electric ferries arrived in Victoria on Saturday morning ushering in a new era of travel for BC Ferries passengers, as electric seaplane flights are also on the horizon for the region.

“It’s a really exciting day for us,” said Tessa Humphries, spokesperson for BC Ferries.

It took the ferries 60 days to arrive at the Breakwater District at Ogden Point. They came all the way from Constanta, Romania.

“These are battery-equipped ships that are designed for fully electric operation; they are outfitted with hybrid technology that bridges the gap until the EV charging infrastructure and funding is available in British Columbia,” said Humphries.

The two new "Island Class" vessels arrived at about 9 a.m. to a handful of people eagerly wanting to witness history.

Sometime in the next few days, the transport ship that brought the new ferries to B.C. will go out into the harbor and partially submerge to allow them to be offloaded, Humphries said.

The transfer process could happen in four to five days from now. After the final preparations are finished at the Breakwater District, the ships will be re-commissioned in Point Hope Maritime and then BC Ferries will officially take ownership.

“We know a lot of people are interested in this so we will put out advisory once we have more information as to a viewing area to see the whole process,” said Humphries.

Both Island Class ferries can carry 300 passengers and 47 vehicles. They won’t be sailing until later this year, but Humphries tells CTV News they will be named by the end of February. 

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