Radiation found in Tokyo tap water

By Toronto Star


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A spike in radiation levels in Tokyo tap water spurred new fears about food safety as rising black smoke forced another evacuation of workers trying to stabilize Japan's radiation-leaking nuclear plant.

Radiation has seeped into vegetables, raw milk, the water supply and seawater since a magnitude-9 quake and killer tsunami crippled the Fukushima Daiichi power plant. Broccoli was added to a list of tainted vegetables, and U.S. officials announced a block on Japanese dairy and other produce from the region.

The crisis is emerging as the world's most expensive natural disaster on record, likely to cost up to $309 billion, according to a new government estimate. The death toll continued to rise, with more than 9,400 bodies counted and more than 14,700 people listed as missing.

Concerns about food safety spread to Tokyo after officials said tap water showed elevated levels: 210 becquerels per litre of iodine-131 — more than twice the recommended limit of 100 becquerels per litre for infants. The recommended limit for adults is 300 becquerels.

“It is really scary. It is like a vicious negative spiral from the nuclear disaster,” said Etsuko Nomura, a mother of two young children ages 2 and 5. “We have contaminated milk and vegetables, and now tap water in Tokyo, and I'm wondering what's next.”

Infants are particularly vulnerable to radioactive iodine, which can cause thyroid cancer, experts say. The limits refer to sustained consumption rates, and officials urged calm, saying parents should stop giving the tap water to babies, but that it was no worry if the infants already had consumed small amounts.

They said the levels posed no immediate health risk for older children or adults.

“Even if you drink this water for one year, it will not affect people's health,” Chief Cabinet Secretary Yukio Edano said.

Tokyo residents shouldn't worry, said Dr. Lim Sang-moo, director of nuclear medicine at the Korea Cancer Center Hospital in Seoul.

Parents might want to be more cautious if they have a choice. “Nobody wants to drink radioactive water,” he said. But “it's not a medical problem but a psychosocial problem: The stress that people get from the radioactivity is more dangerous than the radioactivity itself.”

Experts also say iodine-131 dissipates quickly in the air, with half of it disappearing every eight days.

Richard Wakeford, a public health radiologist at the University of Manchester in Britain, blamed the spike in radiation on a shift in winds from the nuclear plant toward Tokyo. He predicted lower levels in coming days once the wind shifts back to normal patterns.

“I imagine that bottled water is now quite popular in Tokyo,” he said.

Convenience stores around Tokyo began selling out of water soon after the news broke. At one downtown supermarket, clerk Toru Kikutaka said water purchases were limited to two, two-litre bottles per person, but the store still sold out almost immediately.

“I've never seen anything like this,” he said.

The latest reported food data showed sharp increases in radioactivity levels in a range of vegetables. In an area about 40 kilometres northwest of the plant, levels for one locally grown leafy green called kukitachina measured 82 times the government's limit for radioactive cesium and 11 times the limit for iodine.

The unsettling new development affecting Japan's largest city, home to some 13 million in the city centre, came as nuclear officials struggled to stabilize the hobbled reactor 220 kilometres to the north.

The quake and tsunami that struck off the east coast March 11 knocked out the plant's crucial cooling systems.

Explosions and fires followed in four of the plant's six reactors, leaking radioactive steam into the air. Progress in cooling down the facility has been intermittent, disrupted by rises in radiation, elevated pressure in reactors and overheated storage pools.

The plant operator had restored circuitry to bring power to all six units and turned on lights at Unit 3 for the first time since the disaster — a significant step toward restarting the cooling system.

It had hoped to restore power to cooling pumps at the unit within days, but experts warned the work included the risk of sparking fires as electricity is restored through equipment potentially damaged in the tsunami.

Tokyo Electric Power Co. manager Teruaki Kobayashi said the pump for Unit 3 had been tested and it was working. But officials weren't sure when they would be able to turn the power on to the pump.

In a new setback, black smoke billowed from Unit 3, prompting another evacuation of workers from the plant during the afternoon, Tokyo Electric officials said. They added that there had been no corresponding spike in radiation at the plant.

“We don't know the reason” for the smoke, said Hidehiko Nishiyama of the Nuclear and Industrial Safety Agency.

Nuclear agency official Kenji Kawasaki said workers would not be allowed to return to the plant until March 24, as it was too difficult to tell at night whether all the smoke had cleared.

As a precaution, officials have evacuated residents living within 20 kilometres of the plant and advised those up to 30 kilometres away to stay indoors to minimize exposure.

And for the first time, Edano suggested that those downwind of the plant, even if just outside the zone, should stay indoors with the windows shut tight.

Survivors, meanwhile, buried the dead from the disaster in makeshift coffins, resorting to wrapping some bodies in blue tarps.

In Higashimatsushima, about 320 kilometres northeast of Tokyo, soldiers lowered bare plywood coffins into the ground, saluting each casket, as families watched from a distance. Two young girls wept inconsolably, their father hugging them tight.

“I hope their spirits will rest in peace here at this temporary place,” said mourner Katsuko Oguni, 42.

Hundreds of thousands remained homeless, squeezed into temporary shelters without heat, warm food or medicine and no idea what to call home after the colossal wave swallowed up cities and towns along the coast.

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Renewable growth drives common goals for electricity networks across the globe

Energy Transition Grid Reforms address transmission capacity, interconnection, congestion management, and flexibility markets, enabling renewable integration and grid stability while optimizing network charges and access in Australia, Ireland, and Great Britain.

 

Key Points

Measures to expand transmission, boost flexibility, and manage congestion for reliable, low-carbon electricity systems.

✅ Transmission upgrades and interconnectors ease congestion

✅ Flexible markets, DER, and storage bolster grid stability

✅ Evolving network charges and access incentivize siting

 

Electricity networks globally are experiencing significant increases in the volume of renewable capacity as countries seek to decarbonise their power sectors, even as clean energy's 'dirty secret' highlights integration trade-offs, without impacting the security of supply. The scale of this change is creating new challenges for power networks and those responsible for keeping the lights on.

The latest insight paper from Cornwall Insight – Market design amidst global energy transition – looks into this issue. It examines the outlook for transmission networks, and how legacy design and policies are supporting decarbonisation, aligning with IRENA findings on renewables and shaping the system. The paper focuses on three key markets; Australia, Ireland and Great Britain (GB).

Australia's main priority is to enhance transmission capacity and network efficiency; as concerns over excess solar risking blackouts grow in distribution networks, without this, the transmission system will be a barrier to growth for decentralised flexibility and renewables. In contrast, GB and Ireland benefit from interconnection with other national markets. This provides them with additional levers that can be pulled to manage system security and supply. However, they are still trying to hone and optimise network flexibility in light of steepening decarbonisation objectives.

Unsurprisingly, renewable energy resources have been growing in all three markets, with Ireland regarded as a leader in grid integration, with this expected to continue for the foreseeable future. Many of these projects are often located in places where network infrastructure is not as well developed, creating pressure on system operation as a result.

In all three markets, unit charges are rising, driven by a reduced charging base as decentralised energy grows quickly. This combination of changes is leading to network congestion, a challenge mirrored by the US grid overhaul for renewables underway, as transmission network development struggles to keep up, and flexibility markets are being optimised and changed.

In summary, reforms are on-going in each jurisdiction to accommodate the rapid physical transformation of the generation mix. Each has its objectives and tensions which are reflective of wider global reform programmes being undertaken in most developed, liberalised and decarbonising energy markets.

Gareth Miller, CEO of Cornwall Insight, said: “Despite differences in market design and characteristics, all three markets are grappling with similar issues, that comes from committing to deep decarbonisation. This includes the most appropriate methods for charging for networks, managing access to them and dealing with issues such as network congestion and constraint.

“In all three countries, renewable projects are often placed in isolated locations, as seen in Scotland where more pylons are needed to keep the lights on, away from the traditional infrastructure that is closer to demand. However, as renewable growth is set to continue, the networks will need to transition from being demand-centric to more supply orientated.

“Both system operators and stakeholders will need to continually evaluate their market structures and designs to alleviate issues surrounding locational congestion and grid stability. Each market is at very different stages in the process in trying to improve any problems implementing solutions to allow for higher efficiencies in renewable energy integration.

“It is uncertain whether any of the proposed changes will fundamentally resolve the issues that come with increased renewables on the system. However, despite marked differences, they certainly could all learn from each other and elements of their network arrangements, as well as from US decarbonisation strategies research.”

 

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Alberta gives $40M to help workers transition from coal power jobs

Alberta Coal Transition Support offers EI top-ups, 75% wage replacement, retraining, tuition vouchers, and on-site advice for workers leaving thermal coal mines and coal-fired power plants during the provincial phase-out.

 

Key Points

Alberta Coal Transition Support is a $40M program providing EI top-ups, retraining, and tuition vouchers to coal workers.

✅ 75% EI top-up; province requests federal alignment

✅ Tuition vouchers and retraining for displaced workers

✅ On-site transition services; about 2,000 workers affected

 

Alberta is putting aside $40 million to help workers losing their jobs as the province transitions away from thermal coal mines and coal-fired power plants, a shift connected to the future of work in the electricity sector over the next decade.

Labour Minister Christina Gray says the money will top up benefits to 75 per cent of a worker’s previous earnings during the time they collect employment insurance, amid regional shifts such as how COVID-19 reshaped Saskatchewan in recent months.

Alberta is asking the federal government to not claw back existing benefits as the province tops up those EI benefits, as utilities face pressures like Manitoba Hydro cost-cutting during the pandemic, while also extending EI benefits for retiring coal workers.

Gray says even if the federal government does not step up, the province will provide the funds to match that 75 per cent threshold, a contrast to problems such as Kentucky miners' cold checks seen elsewhere.

There will also be help for workers in the form of tuition vouchers, retraining programs like the Nova Scotia energy training program that connects youth to the sector, and on-site transitioning advice.

The province estimates there are 2,000 workers affected.

 

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Latvia eyes electricity from Belarus nuclear plant

Latvia Astravets electricity imports weigh AST purchases from the Belarusian nuclear plant, impacting the Baltic grid, Lithuania market, energy security, and cross-border trading as Latvia seeks to mitigate supply risks and stabilize power flows.

 

Key Points

Proposed AST purchases of power from Belarus's Astravets plant to bolster Baltic grid supply via Lithuania.

✅ AST evaluates imports to mitigate supply risk

✅ Energy could enter Lithuania via existing trading route

✅ Debate centers on nuclear safety and Baltic grid impacts

 

Latvia’s electricity transmission system operator, AST, is looking at the possibility of purchasing electricity from the soon-to-be completed Belarusian nuclear power plant in Astravets, at a time when Ukraine's electricity exports have resumed in the region, long criticised by the Lithuanian government, Belsat TV has reported.

According to the Latvian media, the Latvian government is seeking to mitigate the risk of a possible drop in electricity supplies amid price spikes in Ireland highlighting dispatchable power concerns, given that energy trading between the Baltic states and third parties is currently carried out only through the Belarusian-Lithuanian border, including Latvian imports from Lithuania.

If AST starts importing electricity from the Belarusian plant to Latvia, in a pattern similar to Georgia's electricity imports during peak demand, the energy is expected to enter the Lithuanian market as well.

Such cross-border flows also mirror responses to Central Asia's electricity shortages seen recently.

The Lithuanian government has repeatedly criticised the nuclear power over national security and environmental safety concerns, as well as a number of emergencies that took place during construction, particularly as Europe is losing nuclear power and confronting energy security challenges.

Debates over infrastructure and safety have also intensified by projects like power lines to reactivate Zaporizhzhia in Ukraine.

The first Astravets reactor, which is being built close to the Lithuanian border in the Hrodno region, is expected to be operational by the end of 2019, a year that saw Belgium's nuclear exports rise across Europe.

 

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Secret Liberal cabinet document reveals Electricity prices to soar

Ontario Hydro Rate Relief Plan delivers short-term electricity bill cuts, while leaked cabinet forecasts show inflation-linked hikes, borrowing costs, and a Clean Energy Adjustment under the province's long-term energy plan.

 

Key Points

A provincial plan that cuts bills now but defers costs, projecting rate hikes and adding a Clean Energy Adjustment.

✅ 25% cut now, after 8% HST relief; extra 17% reduction applied.

✅ Forecast: inflation-linked hikes later; borrowing adds long-term costs.

✅ Clean Energy Adjustment line to repay deferred system costs.

 

The short-term gain of a 25 per cent hydro rate cut this summer could lead to long-term pain as a leaked cabinet document forecasts prices jumping again in five years.

In the briefing materials leaked and obtained by the Progressive Conservatives, rates will start rising 6.5 per cent a year in 2022 and top out at 10.5 per cent in 2028, when average monthly bills hit $215.

That would be up from $123 this year once the rate cut — the subject of long-awaited legislation to lower electricity rates unveiled Thursday by Energy Minister Glenn Thibeault — takes full effect. There will be another 17-per-cent cut in addition to the 8 per cent taken off bills in January when the provincial portion of the HST was waived.

The leaked papers overshadowed Thibeault’s efforts to tout the price break, which will be followed with four years of hydro rate increases at 2 per cent, roughly the rate of inflation.

Thibeault charged that the Conservatives used an “outdated” document to distract from the fact that they are the only major party without a plan for dealing with skyrocketing hydro rates, with a year to go until next June’s provincial election.

“It’s not a coincidence,” he told reporters, denying any plans for an eventual 10.5-per-cent rate hike and promising the government’s new long-term energy plan, due in a few months, will have better numbers.

“We are working hard right now to continue to pull costs out of the system.”

Opposition parties said the Liberal plan doesn’t deal with the underlying problems that have made electricity expensive and simply borrows money to spread the costs over a longer period of time, with $25 billion in interest charges over 30 years.

Some observers also noted that a deal with Quebec would not reduce hydro bills, highlighting concerns about lasting affordability.

“The price of electricity is going to skyrocket after the next election,” warned Conservative MPP Todd Smith (Prince Edward—Hastings).

“The government isn’t being honest with the people of Ontario when it comes to the price of electricity.”

The documents show average monthly bills peaking at $231 in the year 2047, before falling back to $210 the following year once the 30 years of interest payments are over.

Conservative sources say they obtained the papers stamped “confidential cabinet document” from a whistleblower after Thibeault’s rate cut plan was presented to cabinet ministers at a meeting in early March.

There is no date on the document, which the energy minister alternately dismissed as “inaccurate” or possibly one of many that have been prepared with different options in mind.

“We’ve had hundreds of briefings with hundreds of documents … I can’t comment on one graph when we’ve been looking at hundreds of scenarios.”

New Democrats, who have proposed a scheme to cut rates, if elected, also called the government plan an election ploy with Liberals lagging in the polls.

“We’re going to take on a huge debt so (Premier) Kathleen Wynne can look good on the hustings in the next few months, and for decades we’re going to pay for it,” said MPP Peter Tabuns (Toronto-Danforth).

Thibeault acknowledged the Liberal plan will start repaying borrowed money in the mid- or late 2020s and it will show up separately on hydro bills as the “Clean Energy Adjustment”, a kind of electricity recovery rate that could raise costs.

 

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Germany's Energy Crisis Deepens as Local Utilities Cry for Help

Germany energy liquidity crisis is straining municipal utilities as gas and power prices surge, margin calls rise, and Russian supply cuts bite, forcing state support, interventions, and emergency financing to stabilize households and businesses.

 

Key Points

A cash squeeze on German municipal utilities as soaring gas and power prices trigger margin calls and funding gaps.

✅ Margin calls and spot-market purchases strain cash flow

✅ State liquidity lines and EU collateral support proposed

✅ Gazprom cuts, Uniper distress heighten default risks

 

Germany’s fears that soaring power prices and gas prices could trigger a deeper crisis is starting to get real. 

Several hundred local utilities are coming under strain and need support, according to the head of Germany’s largest energy lobby group. The companies, generally owned by municipalities, supply households and small businesses directly and are a key part of the country’s power and gas network.

“The next step from the government and federal states must be to secure liquidity for these municipal companies,” Kerstin Andreae, chairwoman of the German Association of Energy and Water Industries, told Bloomberg in Berlin. “Prices are rising, and they have no more money to pay the suppliers. This is a big problem.”

Germany’s energy crunch intensified over the weekend after Russia’s Gazprom PJSC halted its key gas pipeline indefinitely, a stark wake-up call for policymakers to reduce fossil fuel dependence. European energy prices have surged again amid concerns over shortages this winter and fears of a worst-case energy scenario across the bloc. 

Many utilities are running into financial issues as they’re forced to cover missing Russian deliveries with expensive supplies on the spot market. German energy giant Uniper SE, which supplies local utilities, warned it will likely burn through a 7 billion-euro ($7 billion) government safety net and will need more help already this month.

Some German local utilities have already sought help, according to a government official, who asked not to be identified in line with briefing rules.  

With Europe’s largest economy already bracing for recession, Chancellor Olaf Scholz’s administration is battling on several fronts, testing the government’s financial capacity. The ruling coalition agreed Sunday on a relief plan worth about 65 billion euros -- part of an emerging energy shield package to contain the fallout of surging costs for households and businesses. 

Starting in October, local utilities will have to pay a levy for the gas acquired, which will further increase their financial burden, Andreae said.

Margin Calls
European gas prices are more than four times higher than usual for this time of year, underscoring why rolling back electricity prices is tougher than it appears for policymakers, as Russia cuts supplies in retaliation for sanctions related to its invasion of Ukraine. When prices peak, energy companies have to pay margin calls, extra collateral required to back their trades.

Read more: Energy Trade Risks Collapsing Over Margin Calls of $1.5 Trillion

The problem has hit local utilities in other countries as well. In Austria, the government approved a 2 billion-euro loan for Vienna’s municipal utility last month. 

The European Union is also planning help, floating gas price cap strategies among other tools. The bloc’s emergency measures will include support for electricity producers struggling to find enough cash to guarantee trades, according to European Commission President Ursula von der Leyen.

The situation has worsened in Germany as some of the country’s big gas importers are reluctant to sell more supplies to some of municipal companies amid fears they could default on payments, Andreae said. 

 

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Can COVID-19 accelerate funding for access to electricity?

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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