Mines found at Ukraine's Zaporizhzhia nuclear plant, UN watchdog says


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Zaporizhzhia Nuclear Plant Mines reported by IAEA at the Russian-occupied site: anti-personnel devices in a buffer zone, restricted areas; access limits to reactor rooftops and turbine halls heighten nuclear safety and security concerns in Ukraine.

 

Key Points

IAEA reports anti-personnel mines at Russian-held Zaporizhzhia, raising nuclear safety risks in buffer zones.

✅ IAEA observes mines in buffer zone at occupied site

✅ Restricted areas; no roof or turbine hall access granted

✅ Safety systems unaffected, but staff under pressure

 

The United Nations atomic watchdog said it saw anti-personnel mines at the site of Ukraine's Zaporizhzhia nuclear power plant which is occupied by Russian forces.

Europe's largest nuclear facility fell to Russian forces shortly after the invasion of Ukraine in February last year, as Moscow later sought to build power lines to reactivate it amid ongoing control of the area. Kyiv and Moscow have since accused each other of planning an incident at the site.

On July 23 International Atomic Energy Agency (IAEA) experts "saw some mines located in a buffer zone between the site's internal and external perimeter barriers," agency chief Rafael Grossi said in a statement on Monday.

The statement did not say how many mines the team had seen.

The devices were in "restricted areas" that operating plant personnel cannot access, Mr Grossi said, adding the IAEA's initial assessment was that any detonation "should not affect the site's nuclear safety and security systems".

Laying explosives at the site was "inconsistent with the IAEA safety standards and nuclear security guidance" and, amid controversial proposals on Ukraine's nuclear plants that have circulated internationally, created additional psychological pressure on staff, he added.

Ukrainians in Nikopol are out of water and within Russia's firing line. But Zaporizhzhia nuclear power plant could pose the biggest threat, even as Ukraine has resumed electricity exports to regional grids.

Last week the IAEA said its experts had carried out inspections at the plant, without "observing" the presence of any mines, although they had not been given access to the rooftops of the reactor buildings, while a possible agreement to curb attacks on plants was being discussed.

The IAEA had still not been given access to the roofs of the reactor buildings and their turbine halls, its latest statement said, even as a proposal to control Ukraine's nuclear plants drew scrutiny.

After falling into Russian hands, Europe's biggest power plant was targeted by gunfire and has been severed from the grid several times, raising nuclear risk warnings from the IAEA and others.

The six reactor units, which before the war produced around a fifth of Ukraine's electricity, have been shut down for months, prompting interest in wind power development as a harder-to-disrupt source.

 

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U.S. power demand seen sliding 1% in 2023 on milder weather

EIA U.S. Power Outlook 2023-2024 forecasts lower electricity demand, softer wholesale prices, and faster renewable growth from solar and wind, with steady natural gas, reduced coal generation, slight nuclear gains, and ERCOT market moderation.

 

Key Points

An EIA forecast of a 2023 demand dip, 2024 rebound, lower prices, and a higher renewable share in the U.S. power mix.

✅ Demand dips to 4,000 billion kWh in 2023; rebounds in 2024.

✅ ERCOT on-peak prices average about $35/MWh versus $80/MWh in 2022.

✅ Renewables grow to 24% share; coal falls to 17%; nuclear edges up.

 

U.S. power consumption is expected to slip about 1% in 2023 from the previous year as milder weather slows usage from the record high hit in 2022, consistent with recent U.S. consumption trends observed over the past several years, the U.S. Energy Information Administration (EIA) said in its Short-Term Energy Outlook (STEO).

EIA projected that electricity demand is on track to slide to 4,000 billion kilowatt-hours (kWh) in 2023 from a historic high of 4,048 billion kilowatt-hours (kWh) in 2022, reflecting patterns seen during COVID-19 demand shifts in prior years, before rising to 4,062 billion kWh in 2024 as economic growth ramps up.

Less demand coupled with more electricity generation from cheap renewable power sources and lower natural gas prices is forecast to slash wholesale power prices this year, the EIA said.

The on-peak wholesale price at the North hub in Texas’ ERCOT power market is expected to average about $35 per megawatt-hour (MWh) in 2023 compared with an average of nearly $80/MWh in 2022 after the 2022 price surge in power markets.

As capacity for renewables like solar and wind ramp up and as natural gas prices ease amid the broader energy crisis pressures, the EIA said it expects coal-fired power generation to be 17% less in the spring of 2023 than in the spring of 2022.

Coal will provide an average of 17% of total U.S. generation this year, down from 20% last year, as utilities shift investments toward electricity delivery and away from new power production, the EIA said.

The share of total generation supplied by natural gas is seen remaining at about the same this year at 39%. The nuclear share of generation is seen rising slightly to 20% this year from 19% in 2022. Generation from renewable energy sources grows the most in the forecast, increasing to 24% this year from a share of 22% last year, even as residential electricity bills rose in 2022 across the U.S.

 

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Construction of expanded Hoa Binh Hydropower Plant to start October 2020

Expanded Hoa Binh Hydropower Plant increases EVN capacity with 480MW turbines, commercial loan financing, grid stability, flood control, and Da River reliability, supported by PECC1 feasibility work and CMSC collaboration on site clearance.

 

Key Points

A 480MW EVN expansion on the Da River to enhance grid stability, flood control, and seasonal water supply in Vietnam.

✅ 480MW, two turbines, EVN-led financing without guarantees

✅ Improves frequency modulation and national grid stability

✅ Supports flood control and dry-season water supply

 

The extended Hoa Binh Hydropower Plant, which is expected to break ground in October 2020, is considered the largest power project to be constructed this year, even as Vietnam advances a mega wind project planned for 2025.

Covering an area of 99.2 hectares, the project is invested by Electricity of Vietnam (EVN). Besides, Vietnam Electricity Power Projects Management Board No.1 (EVNPMB1) is the representative of the investor and Power Engineering Consulting JSC 1 (EVNPECC1) is in charge of building the feasibility report for the project. The expanded Hoa Binh Hydro Power Plant has a total investment of VND9.22 trillion ($400.87 million), 30 per cent of which is EVN’s equity and the remaining 70 per cent comes from commercial loans without a government guarantee.

According to the initial plan, EVN will begin the construction of the project in the second quarter of this year and is expected to take the first unit into operation in the third quarter of 2023, a timeline reminiscent of Barakah Unit 1 reaching full power, and the second one in the fourth quarter of the same year.

Chairman of the Committee for Management of State Capital at Enterprises (CMSC) Nguyen Hoang Anh said that in order to start the construction in time, CMSC will co-operate with EVN to work with partners as well as local and foreign banks to mobilise capital, reflecting broader nuclear project milestones across the energy sector.

In addition, EVN will co-operate with Hoa Binh People’s Committee to implement site clearance, remove Ba Cap port and select contractors.

Once completed, the project will contribute to preventing floods in the rainy season and supply water in the dry season. The plant expansion will include two turbines with the total capacity of 480MW, similar in scale to the 525-MW hydropower station China is building on a Yangtze tributary, and electricity output of about 488.3 million kWh per year.

In addition, it will help improve frequency modulation capability and stabilise the frequency of the national electricity system through approaches like pumped storage capacity, and reduce the working intensity of available turbines of the plant, thus prolonging the life of the equipment and saving maintenance and repair costs.

Built in the Da River basin in the northern mountainous province of Hoa Binh, at the time of its conception in 1979, Hoa Binh was the largest hydropower plant in Southeast Asia, while projects such as China’s Lawa hydropower station now dwarf earlier benchmarks.

The construction was supported by the Soviet Union all the way through, designing, supplying equipment, supervising, and helping it go on stream. Construction began in November 1979 and was completed 15 years later in December 1994, when it was officially commissioned, similar to two new BC generating stations recently brought online.

 

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Ukraine's parliament backs amendments to electricity market law

Ukraine Electricity Market Price Caps empower the regulator, the National Commission, to set marginal prices on day-ahead, intraday, and balancing markets, stabilize competition, support thermal plants, and sustain the heating season via green tariff obligations.

 

Key Points

Regulatory limits set by the National Commission to curb price spikes, ensure competition, and secure heat supply.

✅ Sets marginal prices for day-ahead, intraday, balancing markets

✅ Mitigates collusion risks; promotes effective competition

✅ Ensures TPP operation and heat supply during heating season

 

The Verkhovna Rada, Ukraine's parliament, has adopted at first reading a draft law that proposes giving the National Commission for State Regulation of Energy and Public Utilities the right to set marginal prices in the electricity market, amid EU market revamp plans that aim to reshape pricing, until 2023.

A total of 259 MPs voted for the document at a parliament meeting on Tuesday, November 12, amid electricity import pressures that have tested the grid, according to an Ukrinform correspondent.

Bill No. 2233 introducing amendments to the law on the electricity market provides for the legislative regulation of the mechanism for fulfilling special obligations for the purchase of electricity at a "green" tariff, preventing the uncontrolled growth of electricity prices due to the lack of effective competition, including recent price-fixing allegations that have raised concerns, ensuring heat supply to consumers during the heating period by regulating the issue of the functioning of thermal power plants in the new electricity market.

It is proposed to introduce respective amendments to the law of Ukraine on the electricity market, alongside steps toward synchronization with ENTSO-E to enhance system stability.

In particular, the draft law gives the regulator the right for the period until July 1, 2023 to set marginal prices on the day-ahead market, the intraday market and the balancing market for each trade zone, reflecting similar EU fixed-price contract initiatives being discussed, and to decide on the obligation for producers to submit proposals (applications) for the sale of electricity on the day-ahead market.

Lawmakers think that the adoption of the bill and empowering the regulator to set marginal prices in the relevant segments of the electricity market will prevent, even as rolling back prices in Europe remains difficult for policymakers, "an uncontrolled increase in electricity prices due to the lack of effective competition or collusion between market players, as well as regulate the issue of the functioning of thermal power plants during the autumn and winter period, which is a necessary prerequisite for providing heat to consumers during the heating period."

The new model of the electricity market was launched on July 1 as the UK weighs decoupling gas and power prices to shield consumers, in accordance with the provisions of the law on the electricity market, adopted in 2017.

 

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Tunisia moves ahead with smart electricity grid

Tunisia Smart Grid Project advances with an AFD loan as STEG deploys smart meters in Sfax, upgrades grid infrastructure, boosts energy efficiency, curbs losses, and integrates renewable energy through digitalization and advanced communication systems.

 

Key Points

A national program funded by an AFD $131.7M loan to modernize STEG, deploy smart meters, and integrate renewable energy.

✅ 430,000 smart meters in Sfax during phase one

✅ 20-year AFD loan with 7-year grace period

✅ Cuts losses, improves efficiency, enables renewables

 

The Tunisian parliament has approved taking a $131.7 million loan from the French Development Agency for the implementation of a smart grid project.

Parliament passed legislation regarding the 400 million dinar ($131.7 million) loan plus a grant of $1.1 million.

The loan, to be repaid over 20 years with a grace period of up to 7 years, is part of the Tunisian government’s efforts to establish a strategy of energy switching aimed at reducing costs and enhancing operational efficiency.

The move to the smart grid had been postponed after the Tunisian Company of Electricity and Gas (STEG) announced in March 2017 that implementation of the first phase of the project would begin in early 2018 and cover the entire country by 2023.

STEG was to have received funding some time ago. Last year at the Africa Smart Grid Summit in Tunis, the company said it would initiate an international tender during the first quarter of 2019 to start the project.

The French funding is to be allocated to implementation of the first phase only, which will involve development of control and communication stations and the improvement of infrastructure, where regulatory outcomes such as the Hydro One T&D rates decision can influence investment planning in comparable markets.

It includes installation of 430,000 “intelligent” metres over three years in Sfax governorate in southern Tunisia. The second phase of the project is planned to extend the programme to the rest of the country.

Smart metres to be installed in homes and businesses in Sfax account for about 10% of the total number of metres to be deployed in Tunisia.

At the beginning of 2017, the Industrial Company of Metallic Articles (SIAM), a Tunisian industrial electrical equipment and machinery company, signed an agreement with Huawei for the Chinese company to supply smart electricity metres. The value of the deal was not disclosed.

The smart grid is designed to reduce power waste, reduce the number of unpaid bills, prevent consumer fraud such as power theft in India across distribution networks, improve the ecosystem and increase competitiveness in the electricity sector.

Experts said the main difference between the traditional and smart grids is the adoption of advanced infrastructure for measuring electricity consumption and for communication between the power plant and consumers. The data exchange allows power plants to coordinate electricity production with actual demand.

STEG previously indicated that it had implemented measures to ensure the transition to the smart grid, especially since digitalisation is playing an important role in the energy sector.

The project, which translates Tunisia’s energy plans in the form of a partnership between the public and private sectors, aims at reaching 30% of the country’s electricity need from renewable sources by 2025, even as entities like the TVA face climate goals scrutiny that can affect electricity rates in other markets.

The development of the smart grid will allow STEG to monitor consumption patterns, detect abuses and remotely monitor the grid’s power supply, at a time when regulators have questioned UK network profits to spur efficiency, underscoring the value of transparency.

“The smart grid will change the face of the energy system towards the use of renewable energies,” said Tunisian Industry Minister Slim Feriani. At the forum on alternative energies, he pointed out that energy sector digitisation requires investments in technology and a change in the consumption mentality, as new entrants consider roles like Tesla electricity retailer plans in advanced markets.

Official data indicate that Tunisia’s energy deficit accounts for one-third of the country’s annual trade deficit, which reached record levels of more than $6 billion last year.

STEG, whose debts have reached $329 million over the past eight years, a situation resembling Manitoba Hydro debt pressures in Canada, has not disclosed when and how funding would be secured for the completion of the second phase. The company insists it is working to prevent further losses and to collect its unpaid bills.

STEG CEO Moncef Harrabi, earlier this year, said: “The current situation of the company has forced us to take immediate action to reduce the worsening of the crisis and stop the financial bleeding caused by losses.”

He said the company had repeatedly asked the government to pay subsidy instalments due to the company and to enact binding decisions to force government institutions and departments to pay electricity bills, while elsewhere measures like Thailand power bill cuts have been used to support consumers.

The Tunisian government has yet to disburse the subsidy instalments due STEG for 2018 and 2019, which amount to $658 million. STEG also imports natural gas from Algeria for its power plants at a cost of $1.1 billion a year.

 

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How Canada can capitalize on U.S. auto sector's abrupt pivot to electric vehicles

Canadian EV Manufacturing is accelerating with GM, Ford, and Project Arrow, integrating cross-border supply chains, battery production, rare-earths like lithium and cobalt, autonomous tech, and home charging to drive clean mobility and decarbonization.

 

Key Points

Canadian EV manufacturing spans electric and autonomous vehicles, domestic batteries, and integrated US-Canada trade.

✅ GM and Ford retool plants for EVs and autonomous production

✅ Project Arrow showcases Canadian zero-emission supply capabilities

✅ Lithium, cobalt, and battery hubs target cross-border resilience

 

The storied North American automotive industry, the ultimate showcase of Canada’s high-tensile trade ties with the United States and emerging Canada-U.S. collaboration on EVs momentum, is about to navigate a dramatic hairpin turn.

But as the Big Three veer into the all-electric, autonomous era, some Canadians want to seize the moment and take the wheel.

“There’s a long shadow between the promise and the execution, but all the pieces are there,” says Flavio Volpe, president of the Automotive Parts Manufacturers’ Association.

“We went from a marriage on the rocks to one that both partners are committed to. It could be the best second chapter ever.”

Volpe is referring specifically to GM, which announced late last month an ambitious plan to convert its entire portfolio of vehicles to an all-electric platform by 2035.

But that decision is just part of a cascading transformation across the industry, marking an EV inflection point with existential ramifications for one of the most tightly integrated cross-border manufacturing and supply-chain relationships in the world.

China is already working hard to become the “source of a new way” to power vehicles, President Joe Biden warned last week.

“We just have to step up.”

Canada has both the resources and expertise to do the same, says Volpe, whose ambitious Project Arrow concept — a homegrown zero-emissions vehicle named for the 1950s-era Avro interceptor jet — is designed to showcase exactly that, as recent EV assembly deals in Canada underscore.

“We’re going to prove to the market, we’re going to prove to the (manufacturers) around the planet, that everything that goes into your zero-emission vehicle can be made or sourced here in Canada,” he says.

“If somebody wants to bring what we did over the line and make 100,000 of them a year, I’ll hand it to them.”

GM earned the ire of Canadian auto workers in 2018 by announcing the closure of its assembly plant in Oshawa, Ont. It later resurrected the facility with a $170-million investment to retool it for autonomous vehicles.

“It was, ‘You closed Oshawa, how dare you?’ And I was one of the ‘How dare you’ people,” Volpe says.

“Well, now that they’ve reopened Oshawa, you sit there and you open your eyes to the commitment that General Motors made.”

Ford, too, has entered the fray, promising $1.8 billion to retool its sprawling landmark facility in Oakville, Ont., to build EVs.

It’s a leap of faith of sorts, considering what market experts say is ongoing consumer doubt about EVs and EV supply shortages that drive wait times.

“Range anxiety” — the persistent fear of a depleted battery at the side of the road — remains a major concern, even though it’s less of a problem than most people think.

Consulting firm Deloitte Canada, which has been tracking automotive consumer trends for more than a decade, found three-quarters of future EV buyers it surveyed planned to charge their vehicles at home overnight.

“The difference between what is a perceived issue in a consumer’s mind and what is an actual issue is actually quite negligible,” Ryan Robinson, Deloitte’s automotive research leader, says in an interview.

“It’s still an issue, full stop, and that’s something that the industry is going to have to contend with.”

So, too, is price, especially with the end of the COVID-19 pandemic still a long way off. Deloitte’s latest survey, released last month, found 45 per cent of future buyers in Canada hope to spend less than $35,000 — a tall order when most base electric-vehicle models hover between $40,000 and $45,000.

“You put all of that together and there’s still, despite the electric-car revolution hype, some major challenges that a lot of stakeholders that touch the automotive industry face,” Robinson says.

“It’s not just government, it’s not just automakers, but there are a variety of stakeholders that have a role to play in making sure that Canadians are ready to make the transition over to electric mobility.”

With protectionism no longer a dirty word in the United States and Biden promising to prioritize American workers and suppliers, the Canadian government’s job remains the same as it ever was: making sure the U.S. understands Canada’s mission-critical role in its own economic priorities.

“We’re both going to be better off on both sides of the border, as we have been in the past, if we orient ourselves toward this global competition as one force,” says Gerald Butts, vice-chairman of the political-risk consultancy Eurasia Group and a former principal secretary to Prime Minister Justin Trudeau.

“It served us extraordinarily well in the past … and I have no reason to believe it won’t serve us well in the future.”

Last month, GM announced a billion-dollar plan to build its new all-electric BrightDrop EV600 van in Ingersoll, Ont., at Canada’s first large-scale EV manufacturing plant for delivery vehicles.

That investment, Volpe says, assumes Canada will take the steps necessary to help build a homegrown battery industry — with projects such as a new Niagara-region battery plant pointing the way — drawing on the country’s rare-earth resources like lithium and cobalt that are waiting to be extracted in northern Ontario, Quebec and elsewhere.

Given that the EV industry is still in his infancy, the free market alone won’t be enough to ensure those resources can be extracted and developed, he says.

“General Motors made a billion-dollar bet on Canada because it’s going to assume that the Canadian government — this one or the next one — is going to commit” to building that business.

Such an investment would pay dividends well beyond the auto sector, considering the federal Liberal government’s commitment to lowering greenhouse gas-emissions, including a 2035 EV mandate, and meeting targets set out in the Paris climate accord.

“If you make investments in renewable energy and utility storage using battery technology, you can build an industry at scale that the auto industry can borrow,” Volpe says.

Major manufacturing, retail and office facilities would be able to use that technology to help “shave the peak” off Canada’s GHG emissions and achieve those targets, all the while paving the way for a self-sufficient electric-vehicle industry.

“You’d be investing in the exact same technology you’d use in a car.”

There’s one problem, says Robinson: the lithium-ion batteries on roads right now might not be where the industry ultimately lands.

“We’re not done with with battery technology,” Robinson says. “What you don’t want to do is invest in a technology that is that is rapidly evolving, and could potentially become obsolete going forward.”

Fuel cells — energy-efficient, hydrogen-powered units that work like batteries, but without the need for constant recharging — continue to be part of the conversation, he adds.

“The amount of investment is huge, and you want to be sure that you’re making the right decision, so you don’t find yourself behind the curve just as all that capacity is coming online.”

 

 

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Ontario Government Consults On Changes To Industrial Electricity Pricing And Programs

Ontario electricity pricing consultations will gather business input on OEB rate design, Industrial Conservation Initiative, dynamic pricing, global adjustment, and system costs through online feedback and sector-specific in-person sessions province-wide.

 

Key Points

Consultations gathering business input on rates, programs, and OEB policy to improve fairness and reduce system costs.

✅ Consults on ICI, GA, dynamic pricing structures

✅ Seeks views on OEB C&I rate design changes

✅ In-person sessions across key industrial sectors

 

The Ontario government has announced plans to hold consultations to seek input from businesses about industrial electricity pricing and programs. This will be done through Ontario's online consultations directory and though in-person sector-specific consultation sessions across the province. The in-person sessions will be held in all areas of Ontario, and will target "key industries," including automotive and the build-out of electric vehicle charging stations infrastructure, forestry, mining, agriculture, steel, manufacturing and chemicals.

On April 1, 2019, the Ontario government published a consultation notice for this process, confirming that it is looking for input on "electricity rate design, existing tax-based incentives, reducing system costs and regulatory and delivery costs," including related proposals such as the hydrogen rate reduction proposal under discussion. The consultation process includes a list of nine questions for respondents (and presumably participants in the in-person sessions) to address. These include questions about:

The benefits of the Industrial Conservation Initiative (described below), including how it could be changed to improve fairness and industrial competitiveness, and how it could complement programs like the Hydrogen Innovation Fund that support industrial innovation.

Dynamic pricing structures that allow for lower rates in return for responding to price signals versus a flat rate structure that potentially costs more, but is more stable and predictable, as Ontario's energy storage expansion accelerates.

Interest in an all-in commodity contract with an electricity retailer, even if it involves a risk premium.

Interested parties are invited to submit their comments before May 31, 2019.

The government's consultation announcement follows recent developments in the Ontario Energy Board's (OEB) review of electricity ratemaking for commercial and industrial customers, and intertie projects such as the Lake Erie Connector that could affect market dynamics.

In December 2018, the OEB published a paper from its Market Surveillance Panel (MSP) examining the Industrial Conservation Initiative (ICI), and potential alternative approaches. The ICI is a program that allows qualifying large industrial customers to base their global adjustment (GA) payments on their consumption during five peak demand hours in a year. Customers who find ways to reduce consumption at those times, perhaps through DERs and enabling energy storage options, will reduce their electricity costs. This shifts GA costs to other customers. The MSP found that the ICI does not fairly allocate costs to those who cause them and/or benefit from them, and recommends that a better approach should be developed.

In February 2019, the OEB released its Staff Report to the Board on Rate Design for Commercial and Industrial Electricity Customers, setting out recommendations for new rate designs for electricity commercial and industrial (C&I) rate classes as Ontario increasingly turns to battery storage to meet rising demand. As described in an earlier post, the Staff Report includes recommendations to: (i) establish a fixed distribution charge for commercial customers with demands under 10 kW; (ii) implement a demand charge (rather than the current volumetric charge) for C&I customers with demands between 10kW and 50kW; and (iii) introduce a "capacity reserve charge" for customers with load displacement generation to replace stand-by charges and provide for recognition of the benefits of this generation on the system. The OEB held a stakeholder information session in mid-March on this initiative, and interested parties are now filing submissions in response to the Staff Report.

Whether and how the OEB's processes will fit together with the government's consultation process remains to be seen.

 

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