Power surge blows meters off homes

Electrically Smart Roads integrate solar road surfaces, inductive charging, IoT sensors, AI analytics, and V2X to power lighting, deicing, and monitoring, reducing grid dependence while enabling dynamic EV charging and real-time traffic management.

Key Points

Electrically smart roads generate power, sense conditions, and charge EVs using solar, IoT, AI, and dynamic infrastructure.

✅ Solar surfaces, verges, and gantries generate on-site electricity

✅ Inductive lanes enable dynamic EV charging at highway speeds

✅ Embedded IoT sensors and AI deliver real-time traffic insights

As more and more capabilities are added to roads instead of simply covering a country with extra roads, they are starting to make their own electricity, notably as solar road surface but then with added silent wind turbines, photovoltaic verges and barriers and more.

That toll gate, street light and traffic monitoring system all need electricity. Later, roads that deice and charge vehicles at speed will need huge amounts of electricity. For now, electricity for road systems is provided by very expensive infrastructure to the grid, and grid flexibility for EVs remains a concern, except for a few solar/ wind street lights in China and Korea for example. However, as more and more capabilities are added to roads instead of simply covering a country with extra roads, they are starting to make their own electricity, notably as solar road surface but then with added silent wind turbines, photovoltaic verges and barriers and more. There is also highly speculative work in the USA and UK on garnering power from road surface movement using piezoelectrics and electrodynamics and even its heat. 

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China plans to create an intelligent transport system by 2030. The country hopes to build smart roads that will not only be able to charge electric cars as they drive but also monitor temperature, traffic flow and weight load using artificial intelligence. Indeed, like France, the Netherlands and the USA, where U.S. EV charging capacity is under scrutiny, it already has trials of extended lengths of solar road which cost no more than regular roads. In an alternative approach, vehicles go under tunnels of solar panels that also support lighting, light-emitting signage and monitoring equipment using the electricity made where it is needed. See the IDTechEx Research report, Electrically Smart Roads 2018-2028 for more.

Raghu Das, CEO of IDTechEx says, "The spiral vertical axis wind turbines VAWT in Asia rarely rotate because they are too low but much higher versions are planned on large UK roadside vehicle charging centres that should work well. H shaped VAWT is also gaining traction - much slower and quieter than the propeller shape which vibrates and keeps you awake at night in an urban area.

The price gap between the ubiquitous polycrystalline silicon solar cell and the much more efficient single crystal silicon is narrowing. That means that road furniture such as bus shelters and smart gantries will likely go for more solar rather than adding wind power in many cases, a shift mirrored by connected solar tech in homes, because wind power needs a lot of maintenance and its price is not dropping as rapidly."

The IDTechEx Research report, Off Grid Electric Vehicle Charging: Zero Emission 2018-2028 analyses that aspect, while vehicle-to-grid strategies may complement grid resources. The prototype of a smart road is already in place on an expressway outside of Jinan, providing better traffic updates as well as more accurate mapping. Verizon's IoT division has launched a project around intelligent asphalt, which it thinks has the potential to significantly reduce fossil fuel emissions and save time by reducing up to 44% of traffic backups. It has partnered with Sacramento, California, to test this theory.

"By embedding sensors into the pavement as well as installing cameras on traffic lights, we will be able to study and analyze the flow of traffic. Then, we will take all of that data and use it to optimize the timing of lights so that traffic flows easier and travel times are shorter," explains Sean Harrington, vice president of Verizon Smart Communities.

Colorado's Department of Transportation has recently announced its intention to be the first state to pilot smart roads by striking a five-year deal with a smart road company to test the technology. Like planned auto-deicing roads elsewhere, the aim of this project is, first and foremost, to save lives. The technology will detect when a car suddenly leaves a road and send emergency assistance to the area. The IDTechEx Research report Electrically Smart Roads 2018-2028 describes how others work on real time structural monitoring of roads and embedded interactive lighting and road surface signage.

"Smart pavement can make that determination and send that information directly into a vehicle," Peter Kozinski, director of CDOT's RoadX division, tells the Denver Post. "Data is the new asphalt of transportation."   Sensors, processors and other technology are embedded in the Colorado road to extend capability beyond accidents and reach into better road maintenance. Fast adoption relies on the ability to rapidly install sensor-laden pavement or lay concrete slabs. Attention therefore turns to fast adaptation of existing roads. Indeed, even for the heavy coil arrays used for dynamic vehicle charging, even as state power grids face new challenges, in Israel there are machines that can retrofit into the road surface at a remarkable two kilometres of cut and insert in a day.

"It's hard to imagine that these things are inexpensive, with all the electronics in them," Charles Schwartz, a professor of civil and environmental engineering at the University of Maryland, tells the Denver Post concerning the vehicle sensing project, "but CDOT is a fairly sophisticated agency, and this is an interesting pilot project. We can learn a lot, even if the test is only partially successful."

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BC Hydro LNG Load Forecast signals rising electricity demand from LNG Canada, Woodfibre, and Tilbury, aligning Site C dam capacity with BCUC review, hydroelectric supply, and a potential fourth project in feasibility study British Columbia.

Key Points

BC Hydro's projection of LNG-driven power demand, guiding Site C capacity, BCUC review, and grid planning.

✅ Includes LNG Canada, Woodfibre, and Tilbury load requests

✅ Aligns Site C hydroelectric output with industrial electrification

✅ Notes feasibility study for a fourth LNG project

Despite recent project cancellations, such as the Siwash Creek independent power project now in limbo, BC Hydro still expects three LNG projects — and possibly a fourth, which is undergoing a feasibility study — will need power from its controversial and expensive Site C hydroelectric dam.

In a letter sent to the British Columbia Utilities Commission (BCUC) on Oct. 3, BC Hydro’s chief regulatory officer Fred James said the provincially owned utility’s load forecast includes power demand for three proposed liquefied natural gas projects because they continue to ask the company for power.

The letter and attached report provide some detail on which of the LNG projects proposed in B.C. are more likely to be built, given recent project cancellations.

The documents are also an attempt to explain why BC Hydro continues to forecast a surge in electricity demand in the province, as seen in its first call for power in 15 years driven by electrification, even though massive LNG projects proposed by Malaysia’s state owned oil company Petronas and China’s CNOOC Nexen have been cancelled.

An explanation is needed because B.C.’s new NDP government had promised the BCUC would review the need for the $9-billion Site C dam, which was commissioned to provide power for the province’s nascent LNG industry, amid debates over alternatives like going nuclear among residents. The commission had specifically asked for an explanation of BC Hydro’s electric load forecast as it relates to LNG projects by Wednesday.

The three projects that continue to ask BC Hydro for electricity are Shell Canada Ltd.’s LNG Canada project, the Woodfibre LNG project and a future expansion of FortisBC’s Tilbury LNG storage facility.

None of those projects have officially been sanctioned but “service requests from industrial sector customers, including LNG, are generally included in our industrial load forecast,” the report noted, even as Manitoba Hydro warned about energy-intensive customers in a separate notice.

In a redacted section of the report, BC Hydro also raises the possibility of a fourth LNG project, which is exploring the need for power in B.C.

“BC Hydro is currently undertaking feasibility studies for another large LNG project, which is not currently included in its Current Load Forecast,” one section of the report notes, though the remainder of the section is redacted.

The Site C dam, which has become a source of controversy in B.C. and was an important election issue, is currently under construction and, following two new generating stations recently commissioned, is expected to be in service by 2024, a timeline which had been considered to provide LNG projects with power by the time they are operational.

BC Hydro’s letter to the BCUC refers to media and financial industry reports that indicate global LNG markets will require more supply by 2023.

“While there remains significant uncertainty, global LNG demand will continue to grow and there is opportunity for B.C. LNG,” the report notes.

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Africa Energy Access Funding faces disbursement bottlenecks as SDG 7 goals demand investment in decentralized solar, minigrids, and rural electrification; COVID-19 pressures donors, requiring faster approvals, standardized documentation, and stronger project preparation and due diligence.

Key Points

Financing to expand Africa's electrification, advancing SDG 7 via disbursement to decentralized solar and minigrids.

✅ Accelerates investment for SDG 7 and rural electrification

✅ Prioritizes decentralized solar, minigrids, and utilities

✅ Speeds approvals, standard docs, and project preparation

The time frame from final funding approval to disbursement can be the most painful part of any financing process, and the access-to-electricity sector is not spared.

Amid the global spread of the coronavirus over the last few weeks, there have been several funding pledges to promote access to electricity in Africa. In March, the African Development Bank and other partners committed $160 million for the Facility for Energy Inclusion to boost electricity connectivity in Africa through small-scale solar systems and minigrids. Similarly, the Export-Import Bank of the United States allocated $91.5 million for rural electrification in Senegal.

Rockefeller chief wants to redefine 'energy poverty'

Rajiv Shah, president of The Rockefeller Foundation, believes that SDG 7 on energy access lacks ambition. He hopes to drive an effort to redefine it.

Currently, funding is not being adequately deployed to help achieve universal access to energy. The International Energy Agency’s “Africa Energy Outlook 2019” report estimated that an almost fourfold increase in current annual access-to-electricity investments — approximately $120 billion a year over the next 20 years — is required to provide universal access to electricity for the 530 million people in Africa that still lack it.

While decentralized renewable energy across communities, particularly solar, has been instrumental in serving the hardest-to-reach populations, tracking done by Sustainable Energy for All — in the 20 countries with about 80% of those living without access to sustainable energy — suggests that decentralized solar received only 1.2% of the total electricity funding.

The spread of COVID-19 is contributing significantly to Africa’s electricity challenges across the region, creating a surge in the demand for energy from the very important health facilities, an exponential increase in daytime demand as a result of most people staying and working indoors, and a rise from some food processing companies that have scaled up their business operations to help safeguard food security, among others. Thankfully — and rightly so — access-to-electricity providers are increasingly being recognized as “essential service” providers amid the lockdowns across cities.

To start tackling Africa’s electricity challenges more effectively, “funding-ready” energy providers must be able to access and fulfill the required conditions to draw down on the already pledged funding. What qualifies as “funding readiness” is open to argument, but having a clear, commercially viable business and revenue model that is suitable for the target market is imperative.

Developing the skills required to navigate the due-diligence process and put together relevant project documents is critical and sometimes challenging for companies without prior experience. Typically, the final form of all project-related agreements is a prerequisite for the final funding approval.

In addition, having the right internal structures in place — for example, controls to prevent revenue leakage, an experienced management team, a credible board of directors, and meeting relevant regulatory requirements such as obtaining permits and licenses — are also important indicators of funding readiness.

1. Support for project preparation. Programs — such as the Private Financing Advisory Network and GET.invest’s COVID-19 window — that provide business coaching to energy project developers are key to helping surmount these hurdles and to increasing the chances of these projects securing funding or investment. Donor funding and technical-assistance facilities should target such programs.

2. Project development funds. Equity for project development is crucial but difficult to attract. Special funds to meet this need are essential, such as the $760,000 for the development of small-scale renewable energy projects across sub-Saharan Africa recently approved by the African Development Bank-managed Sustainable Energy Fund for Africa.

3. Standardized investment documentation. Even when funding-ready energy project developers have secured investors, delays in fulfilling the typical preconditions to draw down funds have been a major concern. This is a good time for investors to strengthen their technical assistance by supporting the standardization of approval documents and funding agreements across the energy sector to fast-track the disbursement of funds.

4. Bundled investment approvals and more frequent approval sessions. While we implement mechanisms to hasten the drawdown of already pledged funding, there is no better time to accelerate decision-making for new access-to-electricity funding to ensure we are better prepared to weather the next storm. Donors and investors should review their processes to be more flexible and allow for more frequent meetings of investment committees and boards to approve transactions. Transaction reviews and approvals can also be conducted for bundled projects to reduce transaction costs.

5. Strengthened local capacity. African countries must also commit to strengthening the local manufacturing and technical capacity for access-to-electricity components through fiscal incentives such as extended tax holidays, value-added-tax exemptions, accelerated capital allowances, and increased investment allowances.

The ongoing pandemic and resulting impacts due to lack of electricity have further shown the need to increase the pace of implementation of access-to-electricity projects. We know that some of the required capital exists, and much more is needed to achieve Sustainable Development Goal 7 — about access to affordable and clean energy for all — by 2030.

It is time to accelerate our support for access-to-electricity companies and equip them to draw down on pledged funding, while calling on donors and investors to speed up their funding processes to ensure the electricity gets to those most in need.

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Iran-Iraq Power Grid Deals reinforce electricity and natural gas ties, upgrading transmission in Karbala and Najaf, repairing transformers, easing sanctions bottlenecks, and weighing GCC interconnection to diversify supply and reduce distribution losses across Iraq.

Key Points

Agreements to rehabilitate Iraq's grid, cut losses, and secure power via Iranian gas, electricity, and upgrades.

✅ Reduce distribution losses in Karbala and Najaf

✅ Repair and replace damaged distribution transformers

✅ Coordinate payments to TAVANIR amid US sanctions

Iran and Iraq have finalized two deals to rehabilitate and develop the power grid of Iraq, while Iran is upgrading thermal plants to combined cycle at home to save energy, IRNA cited the Iranian Energy Minister Reza Ardakanian.

Ardakanian met his Iraqi counterpart Majid Mahdi Hantoush in Tehran on Tuesday evening for talks on further energy cooperation on the sidelines of Prime Minister Mustafa al-Kadhimi’s trip to the Islamic Republic on his first foreign visit.

“It was decided that the contracts related to reducing losses on the electricity distribution network in the provinces of Karbala and Najaf, as well as the contract for repairing Iraq’s distribution transformers would be finalized and signed,” the Iranian minister said.

Iraq relies on Iran for natural gas that generates as much as 45 percent of its electricity, with Iran supplying 40% of Iraq’s power according to sector reports. Iran transmits another 1,200 MW directly, and has regional power hub plans as well, making itself an indispensable energy source for its Arab neighbor, but the United States is trying to pry Baghdad away from Tehran’s orbit.

The US has been enlisting its companies and allies such as Saudi Arabia to replace Iran as Iraq’s source of energy.

Iran’s money from exports of gas and electricity has accumulated in bank accounts in Iraq, because US sanctions are preventing Tehran from repatriating it.

In January, an official said the sanctions were giving Iran a run for five billion dollars, “sedimenting” at the Central Bank of Iraq, because Tehran could not access it.

Ardakanian said the issue was brought up in the discussions on Tuesday and it was agreed that “the payment of part of TAVANIR (Iran Power Generation and Transmission Company)’s claims will start from the end of July”.

The US administration is pushing for a deal between Washington, Baghdad and six Persian Gulf states to connect Iraq’s nationwide power grid to that of the Persian Gulf Cooperation Council, while Uzbekistan looks to export power to Afghanistan as regional linkages expand.

The US State Department said in a statement last Thursday that the six countries that make up the (Persian) Gulf Cooperation Council Interconnection Authority (GCCIA) — Saudi Arabia, Kuwait, Bahrain, Qatar, Oman and the UAE — had affirmed their shared support for the project to supply electricity to Iraq.

Iraq needs more than 23,000 MW of electricity to meet its domestic demand, and is exploring nuclear power plans to tackle shortages, but years of war following the 2003 US invasion have left its power infrastructure in tatters and a deficit of some 7,000 MW.

In the past, officials in Baghdad have said there is no easy substitute to imports from Iran because it will take years to adequately build up Iraq’s energy infrastructure, and meeting summer electricity needs remains a persistent challenge.

They have said American demand acknowledges neither Iraq’s energy needs nor the complex relations between Baghdad and Tehran.

In addition to natural gas and electricity, Iraq imports a wide range of goods from Iran including food, agricultural products, home appliances, and air conditioners.

On Tuesday, the Iraqi prime minister said during a joint news conference with Iranian President Hassan Rouhani that the purpose of his trip to Tehran was to strengthen historical ties between the two countries, especially in light of the challenges they faced as a result of the coronavirus outbreak and the fall of oil prices.

“In the face of such challenges, we need coordination between the two countries in a way that serves the interests of Iran and Iraq.”

Both Iran and Iraq, Kadhimi said, suffer from economic problems, adding the two countries need comprehensive and inclusive cooperation to overcome them.

Kadhimi said Iran-Iraq relations are not merely due to the geographical location of the two countries and their 1,450-km border, adding the ties are based on religion and culture and rooted in history.

“I am reiterating to my brothers in the Islamic Republic of Iran that the Iraqi nation is eager to have excellent relations with the Islamic Republic of Iran based on the principle of non-interference in the internal affairs of the two countries.”

Kadhimi said Iran and Iraq fought against terrorism and Takfiri groups together, and the Islamic Republic of Iran was one of the first countries to stand by Iraq.

“We will not forget this. That is why Iraq has stood with Iran to help it overcome economic challenges and turned to a big market for trade with Iran,” he said.

“We seek stability in Iraq and our philosophy and view of Iran is that we consider Iran a stable, strong, prosperous and progressive country, and this fact is in the interest of Iraq and the territorial integrity of the region,” he added.

According to Kadhimi, the two sides discussed implementing agreements between them, including connecting their railway through Khorramshahr in Iran and Basra in Iraq, adding he was very confident the agreements would be implemented soon.

Iraq’s delegation included the ministers of foreign affairs, finance, health, and planning, as well as Kadhimi’s national security adviser, some of whom also met their Iranian counterparts.

Last year, Iran’s exports to Iraq amounted to nearly $9 billion, IRNA reported. It said the two nations will discuss increasing that amount to $20 billion.

“The two governments’ will is to expand bilateral trade to $20 billion,” Rouhani said after an hour-long meeting with the Iraqi prime minister.

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Rising Electricity Prices are driven by inflation, climate change, and the clean energy transition, affecting energy bills, grid resilience, and supply. Renewables, storage, and infrastructure upgrades shape costs, volatility, and long-term sustainability.

Key Points

Rising electricity prices stem from inflation, climate risk, and costs of integrating clean energy and storage into modern grids.

✅ Inflation raises fuel, materials, and labor costs for utilities

✅ Extreme weather damages infrastructure and strains peak demand

✅ Clean energy rollout needs storage, backup, and grid upgrades

In recent months, consumers have been grappling with a concerning trend: rising electricity prices across the country. This increase is not merely a fluctuation but a complex issue shaped by a confluence of factors including inflation, climate change, and the transition to clean energy. Understanding these dynamics is crucial for navigating the current energy landscape and preparing for its future.

Inflation and Its Impact on Energy Costs

Inflation, the economic phenomenon of rising prices across various sectors, has significantly impacted the cost of living, including electricity and natural gas prices for households. As the price of goods and services increases, so too does the cost of producing and delivering electricity. Energy production relies heavily on raw materials, such as metals and fuels, whose prices have surged in recent years. For instance, the costs associated with mining, transporting, and refining these materials have risen, thereby increasing the operational expenses for power plants.

Moreover, inflation affects labor costs, as wages often need to keep pace with the rising cost of living. As utility companies face higher expenses for both materials and labor, these costs are inevitably passed on to consumers in the form of higher electricity bills.

Climate Change and Energy Supply Disruptions

Climate change also plays a significant role in driving up electricity prices. Extreme weather events, such as hurricanes, heatwaves, and floods, have become more frequent and severe due to climate change. These events disrupt energy production and distribution by damaging infrastructure, impeding transportation, and affecting the availability of resources.

For example, hurricanes can knock out power plants and damage transmission lines, leading to shortages and higher costs. During periods of extreme summer heat across many regions, heatwaves can strain the power grid as increased demand for air conditioning pushes the system to its limits. Such disruptions not only lead to higher immediate costs but also necessitate costly repairs and infrastructure upgrades.

Additionally, the increasing frequency of natural disasters forces utilities to invest in more resilient infrastructure, as many utilities spend more on delivery to harden grids and reduce outages, which adds to overall costs. These investments, while necessary for long-term reliability, contribute to short-term price increases for consumers.

The Transition to Clean Energy

The shift towards clean energy is another pivotal factor influencing electricity prices. While renewable energy sources like wind, solar, and hydro power are crucial for reducing greenhouse gas emissions and combating climate change, their integration into the existing grid presents challenges.

Renewable energy infrastructure requires substantial initial investment. The construction of wind farms, solar panels, and the associated grid improvements involve significant capital expenditure. These upfront costs are often reflected in electricity prices. Moreover, renewable energy sources can be intermittent, meaning they do not always produce electricity at times of high demand. This intermittency necessitates the development of energy storage solutions and backup systems, which further adds to the costs.

Utilities are also transitioning from fossil fuel-based energy production to cleaner alternatives, a process that involves both technological and operational shifts and intersects with the broader energy crisis impacts on electricity, gas, and EVs nationwide. These changes can temporarily increase costs as utilities phase out old systems and implement new ones. While the long-term benefits of cleaner energy include environmental sustainability and potentially lower operating costs, the transition period can be financially burdensome for consumers.

The Path Forward

Addressing rising electricity prices requires a multifaceted approach. Policymakers must balance the need for immediate relief, as California regulators face calls for action amid soaring bills, with the long-term goals of sustainability and resilience. Investments in energy efficiency can help reduce overall demand and ease pressure on the grid. Expanding and modernizing energy infrastructure to accommodate renewable sources can also mitigate price volatility.

Additionally, efforts to mitigate climate change through improved resilience and adaptive measures can reduce the frequency and impact of extreme weather events, thereby stabilizing energy costs.

Consumer education is vital in this process. Understanding the factors driving electricity prices can empower individuals to make informed decisions about energy consumption and conservation. Furthermore, exploring energy-efficient appliances and practices can help manage costs in the face of rising prices.

In summary, the rising cost of electricity is a multifaceted issue influenced by inflation, climate change, and the transition to clean energy, and recent developments show Germany's rising energy costs in the coming year. While these factors pose significant challenges, they also offer opportunities for innovation and improvement in how we produce, distribute, and consume energy. By addressing these issues with a balanced approach, it is possible to navigate the complexities of rising electricity prices while working towards a more sustainable and resilient energy future.

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Enbridge Alberta CCS Project targets carbon capture and storage in Alberta, capturing emissions from industrial emitters to advance net-zero goals, leveraging carbon pricing, regulatory support, and a hub model despite a key partner's exit.

Key Points

A proposed Alberta carbon capture hub by Enbridge to store industrial emissions and support net-zero targets.

✅ Seeks emitters across power, oil and gas, and heavy industry

✅ Backed by carbon pricing, regulation, and net-zero mandates

✅ Faces high capex, storage risk, and anchor-tenant uncertainty

Enbridge Inc., a Canadian energy giant, is digging its heels in on its proposed carbon capture and storage (CCS) project in Alberta. This comes despite the recent withdrawal of Capital Power, a major potential emitter that was expected to utilize the CCS technology. Enbridge maintains the project remains viable, but questions linger about its future viability without a cornerstone anchor.

The CCS project, envisioned as a major carbon capture hub in Alberta, aimed to capture emissions from industrial facilities and permanently store them underground. This technology has the potential to play a significant role in reducing greenhouse gas emissions and mitigating the effects of climate change, alongside grid solutions like bridging the Alberta-B.C. electricity gap that can complement decarbonization efforts.

Capital Power's decision to shelve its $2.4 billion Genesee Generating Station project, which was designed to integrate with the CCS hub, threw a wrench into Enbridge's plans. The Genesee project was expected to be a key source of emissions for capture and storage, and its status is being weighed as Ottawa advances the federal coal plan to phase out unabated coal.

Enbridge, however, remains optimistic. The company cites ongoing discussions with other potential emitters interested in utilizing the CCS technology, amid new funding signals such as the U.S. DOE's $110M for CCUS that highlight momentum. They believe the project holds significant value despite Capital Power's departure.

"We are confident in the long-term viability of the project and continue to actively engage with potential customers," said Enbridge spokesperson Rachel Giroux. "Carbon capture and storage is a critical technology for achieving net-zero emissions, and we believe there is a strong business case for our CCS project."

Enbridge's confidence hinges on several factors. Firstly, they believe there is a growing appetite for CCS technology amongst industrial facilities facing increasing pressure to reduce their carbon footprint. Regulations and carbon pricing mechanisms, including new U.S. EPA power plant rules that test CCS readiness, could further incentivize companies to adopt CCS solutions.

Secondly, Enbridge highlights the potential for capturing emissions from not just power plants but also from other industrial sectors like oil and gas production and clean hydrogen projects in Canada, where reforming processes can generate CO2. This broader application could significantly increase the captured carbon volume and strengthen the project's economic viability.

However, skepticism remains. Critics point to the high upfront costs associated with CCS development and the nascent stage of the technology. They argue that without a guaranteed stream of captured emissions, the project might not be financially sound. Additionally, the long-term safety and effectiveness of large-scale carbon storage solutions remain under scrutiny.

The success of Enbridge's CCS project hinges on attracting new emitters. Replacing Capital Power's contribution will be a significant challenge. Enbridge will need to demonstrate the project's economic viability and navigate the complex regulatory landscape surrounding CCS technology.

The Alberta government's position on CCS is crucial. While the government has expressed support for the technology, the level of financial and regulatory incentives offered will significantly impact investor confidence, especially as the IEA net-zero outlook underscores Canada's need for much more electricity. A clear and stable policy framework will be essential for attracting emitters to the project.

The future of Enbridge's CCS project remains uncertain. Capital Power's withdrawal is a setback, but Enbridge's continued commitment suggests they believe the technology holds promise. Whether they can find enough emitters to justify the project's development will be a critical test. The outcome will have significant implications for the future of CCS technology in Alberta and Canada's broader efforts to achieve net-zero emissions, including Canada-Germany clean energy cooperation that seeks to scale low-carbon fuels.

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