Blackout Feedback Posted, Seeks Further Comment

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As it prepares to issue its final report, the U.S.-Canadian Power Systems Outage Task Force has announced that a summary of the comments received on the Interim Report: Causes of the August 14th Blackout in the United States and Canada is now available at the Department of Energy (DOE) website: http://electricity.doe.gov.

"We are happy to provide the citizens of the U.S. and Canada another opportunity to review the recommendations submitted to the Power System Outage Task Force, and encourage them to participate," Jimmy Glotfelty, co-chair of the task force and director of DOE's Office of Electric Transmission and Distribution said.

The summary incorporates comments and recommendations received thus far from industry officials as well as the general public during the open comment period. This new comment period focuses on evaluating the abovementioned recommendations and comments. This review period will close on Feb. 11, 2004.

The Joint Task Force was created to determine the cause of the August 14 power outage that left 50 million people in 8 U.S. States and 1 Canadian province without power. Preliminary findings were published in an interim report in November 2003.

Public meetings were held in Cleveland, New York, and Ontario seeking public comment. Individuals are encouraged to submit further comments and recommendations to the Task Force electronically or by mail. Electronic submissions may be sent to poweroutage@nrcan.gc.ca or blackout.report@hq.doe.gov.

Paper submissions may be mailed to:

-- Dr. Nawal Kamel, special adviser to the deputy minister; Natural Resources Canada, 21st Floor, 580 Booth Street, ON K1A 0E4

-- Mr. James W. Glotfelty, director, Office of Electric Transmission and Distribution; U.S. Department of Energy, 1000 Independence Avenue, S.W. Ottawa, Washington, D.C. 20585

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How Electricity Gets Priced in Europe and How That May Change

EU Power Market Overhaul targets soaring electricity prices by decoupling gas from power, boosting renewables, refining price caps, and stabilizing grids amid inflation, supply shocks, droughts, nuclear outages, and intermittent wind and solar.

 

Key Points

EU plan to redesign electricity pricing, curb gas-driven costs, boost renewables, and protect consumers from volatility.

✅ Decouples power prices from marginal gas generation

✅ Caps non-gas revenues to fund consumer relief

✅ Supports grid stability with storage, demand response, LNG

 

While energy prices are soaring around the world, Europe is in a particularly tight spot. Its heavy dependence on Russian gas -- on top of droughts, heat waves, an unreliable fleet of French nuclear reactors and a continent-wide shift to greener but more intermittent sources like solar and wind -- has been driving electricity bills up and feeding the highest inflation in decades. As Europe stands on the brink of a recession, and with the winter heating season approaching, officials are considering a major overhaul of the region’s power market to reflect the ongoing shift from fossil fuels to renewables.

1. How is electricity priced? 
Unlike oil or natural gas, there’s no efficient way to save lots of electricity to use in the future, though projects to store electricity in gas pipes are emerging. Commercial use of large-scale batteries is still years away. So power prices have been set by the availability at any given moment. When it’s really windy or sunny, for example, then more is produced relatively cheaply and prices are lower. If that supply shrinks, then prices rise because more generators are brought online to help meet demand -- fueled by more expensive sources. The way the market has long worked is that it is that final technology, or type of plant, needed to meet the last unit of consumption that sets the price for everyone. In Europe this year, that has usually meant natural gas. 

2. What is the relationship between power and gas? 
Very close. Across western Europe, gas plants have been a vital part of the energy infrastructure for decades, with Irish price spikes highlighting dispatchable power risks, fed in large part by supplies piped in from Siberia. Gas-fired plants were relatively quick to build and the technology straightforward, at least compared with nuclear plants and burns cleaner than coal. About 18% of Europe’s electricity was generated at gas plants last year; in 2020 about 43% of the imported gas came from Russia. Even during the depths of the Cold War, there’d never been a serious supply problem -- until the relationship with Russia deteriorated this year after it invaded Ukraine. Diversifying away from Russia, such as by increasing imports of liquefied natural gas, requires new infrastructure that takes a lot of time and money.

3. Why does it work this way? 
In theory, the relationship isn’t different from that with coal, for example. But production hiccups and heatwave curbs on plants from nuclear in France to hydro in Spain and Norway significantly changed the generation picture this year, and power hit records as plants buckled in the heat. Since coal-fired and nuclear plants are generally running all the time anyway, gas plants were being called upon more often -- at times just to keep the lights on as summer temperatures hit records. And with the war in Ukraine resulting in record gas prices, that pushed up overall production costs. It’s that relationship that has made the surging gas price the driver for electricity prices. And since the continent is all connected, it has pushed up prices across the region. The value of the European power market jumped threefold last year, to a record 836 billion euros ($827 billion today).

4. What’s being considered? 
With large parts of European industry on its knees and households facing jumps in energy bills of several hundred percent, as record electricity prices ripple through markets, the pressure on governments and the European Union to intervene has never been higher. One major proposal is to impose a price cap on electricity from non-gas producers, with the difference between that and the market price channeled to relief for consumers. While it sounds simple, any such changes would rip up a market design that’s worked for decades and could threaten future investments because of unintended consequences.


5. How did this market evolve?
The Nordic region and the British market were front-runners in the 1990s, then Germany followed and is now the largest by far. A trader can buy and sell electricity delivered later on same day in blocks of an hour or even down to 15-minute periods, to meet sudden demand or take advantage of price differentials. The price for these contracts is decided entirely by the supply and demand, how much the wind is blowing or which coal plants are operating, for example. Demand tends to surge early in the morning and late afternoon. This system was designed when fossil fuels provided the bulk of power. Now there are more renewables, which are less predictable, with wind and solar surpassing gas in EU generation last year, and the proposed changes reflect that shift. 

6. What else have governments done?
There are also traders who focus on longer-dated contracts covering periods several years ahead, where broader factors such as expected economic output and the extent to which renewables are crowding out gas help drive prices. This year’s wild price swings have prompted countries including Germany, Sweden and Finland to earmark billions of euros in emergency liquidity loans to backstop utilities hit with sudden margin calls on their trading.

 

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Hydro-Quebec begins talks for $185-billion strategy to wean the province off fossil fuels

Hydro-Québec $185-Billion Clean Energy Plan accelerates hydroelectric upgrades, wind power expansion, solar and battery storage, pumped storage, and 5,000 km transmission lines to decarbonize Quebec, boost grid resilience, and attract bond financing and Indigenous partnerships.

 

Key Points

Plan to grow renewables, harden the grid, and fund Quebec's decarbonization with major investments.

✅ $110B new generation, $50B grid resilience by 2035

✅ Triple wind, add solar, batteries, and pumped storage

✅ 5,000 km lines, bond financing, Indigenous partnerships

 

Hydro-Québec is in the preliminary stages of dialogue with various financiers and potential collaborators to strategize the implementation of a $185-billion initiative aimed at transitioning Quebec away from fossil fuel dependency.

As the leading hydroelectric power producer in Canada, Hydro-Québec is set to allocate up to $110 billion by 2035 towards the development of new clean energy facilities, building on its hydropower capacity expansion in recent years, with an additional $50 billion dedicated to enhancing the resilience of its power grid, as revealed in a strategy announced last November. The remainder of the projected expenditure will cover operational costs.

This ambitious initiative has garnered significant interest from the financial sector, with the province's recent electricity for industrial projects also drawing attention, as noted by CEO Michael Sabia during a conference call with journalists where the utility's annual financial outcomes were discussed. Sabia reported receiving various proposals to fund the initiative, though specific partners were not disclosed. He expressed confidence in securing the necessary capital for the project's success.

Sabia highlighted three immediate strategies to increase power output: identifying new sites for hydroelectric projects while upgrading turbines at existing facilities, such as the Carillon Generating Station upgrade now underway for enhanced efficiency, expanding wind energy production threefold, and promoting energy conservation among consumers to optimize current power usage.

Additionally, Hydro-Québec aims to augment its solar and battery energy production and is planning to establish a pumped-storage hydroelectric plant to support peak demand periods. The utility also intends to construct 5,000 kilometers of new transmission lines, address Quebec-to-U.S. transmission constraints where feasible, and is set to double its capital expenditure to $16 billion annually, a significant increase from the investment levels during the James Bay hydropower project construction in the 1970s and 1980s.

To fund part of this expansive plan, Hydro-Québec will continue to access the bond market, having issued $3.7 billion in notes to investors last year despite facing several operational hurdles due to adverse weather conditions.

For the year 2023, Hydro-Québec reported a net income of $3.3 billion, marking a 28% decrease from the previous year's record of $4.56 billion. Factors such as insufficient snow cover, reduced spring runoff, and higher temperatures resulted in lower water levels in reservoirs, leading to a reduction in power exports and a $547-million decrease in external market sales compared to the previous year.

The utility experienced its lowest export volume in a decade but managed to leverage hedging strategies to secure 10.3 cents per kWh for exported power to markets including New Brunswick via recent NB Power agreements that expand interprovincial deliveries, nearly twice the average market rate, through forward contracts that cover up to half of its export volume for about a year in advance.

The success of Sabia's plan will partly depend on the cooperation of First Nations communities, as the proposed infrastructure developments are likely to traverse their ancestral territories. Relationships with some communities are currently tense, exemplified by the Innu of Labrador's $4-billion lawsuit against Hydro-Québec for damages related to land flooding for reservoir construction, and broader regional tensions in Newfoundland and Labrador that persist in the power sector.

Sabia has committed to involving First Nations and Inuit communities as partners in clean energy ventures, offering them ongoing financial benefits rather than one-off settlements, a principle he refers to as "economic reconciliation."

Recently, the Quebec government reached an agreement with the Innu of Pessamit, pledging $45 million to support local community development. This agreement outlines solutions for managing a nearby hydropower reservoir, such as the La Romaine complex in the region, and includes commitments for wind energy development.

Sabia is optimistic about building stronger, more positive relationships with various Indigenous communities, anticipating significant progress in the coming months and viewing this year as a potential milestone in transforming these relationships for the better.

 

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Renewables surpass coal in US energy generation for first time in 130 years

Renewables Overtake Coal in the US, as solar, wind, and hydro expand grid share; EIA data show an energy transition accelerated by COVID-19, slashing emissions, displacing fossil fuels, and reshaping electricity generation and climate policy.

 

Key Points

It refers to the milestone where US renewable energy generation surpassed coal, marking a pivotal energy transition.

✅ EIA data show renewables topped coal consumption in 2019.

✅ Solar, wind, and hydro displaced aging, costly coal plants.

✅ COVID-19 demand drop accelerated the energy transition.

 

Solar, wind and other renewable sources have toppled coal in energy generation in the United States for the first time in over 130 years, with the coronavirus pandemic accelerating a decline in coal that has profound implications for the climate crisis.

Not since wood was the main source of American energy in the 19th century has a renewable resource been used more heavily than coal, but 2019 saw a historic reversal, building on wind and solar reaching 10% of U.S. generation in 2018, according to US government figures.

Coal consumption fell by 15%, down for the sixth year in a row, while renewables edged up by 1%, even as U.S. electricity use trended lower. This meant renewables surpassed coal for the first time since at least 1885, a year when Mark Twain published The Adventures of Huckleberry Finn and America’s first skyscraper was erected in Chicago.

Electricity generation from coal fell to its lowest level in 42 years in 2019, with the US Energy Information Administration (EIA) forecasting that renewables will eclipse coal as an electricity source this year, while a global eclipse by 2025 is also projected. On 21 May, the year hit its 100th day in which renewables have been used more heavily than coal.

“Coal is on the way out, we are seeing the end of coal,” said Dennis Wamsted, analyst at the Institute for Energy Economics and Financial Analysis. “We aren’t going to see a big resurgence in coal generation, the trend is pretty clear.”

The ongoing collapse of coal would have been nearly unthinkable a decade ago, when the fuel source accounted for nearly half of America’s generated electricity, even as a brief uptick in 2021 was anticipated. That proportion may fall to under 20% this year, with analysts predicting a further halving within the coming decade.

A rapid slump since then has not been reversed despite the efforts of the Trump administration, which has dismantled a key Barack Obama-era climate rule to reduce emissions from coal plants and eased requirements that prevent coal operations discharging mercury into the atmosphere and waste into streams.

Coal releases more planet-warming carbon dioxide than any other energy source, with scientists warning its use must be rapidly phased out to achieve net-zero emissions globally by 2050 and avoid the worst ravages of the climate crisis.

Countries including the UK and Germany are in the process of winding down their coal sectors, and in Europe renewables are increasingly crowding out gas as well, although in the US the industry still enjoys strong political support from Trump.

“It’s a big moment for the market to see renewables overtake coal,” said Ben Nelson, lead coal analyst at Moody’s. “The magnitude of intervention to aid coal has not been sufficient to fundamentally change its trajectory, which is sharply downwards.”

Nelson said he expects coal production to plummet by a quarter this year but stressed that declaring the demise of the industry is “a very tough statement to make” due to ongoing exports of coal and its use in steel-making. There are also rural communities with power purchase agreements with coal plants, meaning these contracts would have to end before coal use was halted.

The coal sector has been beset by a barrage of problems, predominantly from cheap, abundant gas that has displaced it as a go-to energy source. The Covid-19 outbreak has exacerbated this trend, even as global power demand has surged above pre-pandemic levels. With plunging electricity demand following the shutting of factories, offices and retailers, utilities have plenty of spare energy to choose from and coal is routinely the last to be picked because it is more expensive to run than gas, solar, wind or nuclear.

Many US coal plants are ageing and costly to operate, forcing hundreds of closures over the past decade. Just this year, power companies have announced plans to shutter 13 coal plants, including the large Edgewater facility outside Sheboygan, Wisconsin, the Coal Creek Station plant in North Dakota and the Four Corners generating station in New Mexico – one of America’s largest emitters of carbon dioxide.

The last coal facility left in New York state closed earlier this year.

The additional pressure of the pandemic “will likely shutter the US coal industry for good”, said Yuan-Sheng Yu, senior analyst at Lux Research. “It is becoming clear that Covid-19 will lead to a shake-up of the energy landscape and catalyze the energy transition, with investors eyeing new energy sector plays as we emerge from the pandemic.”

Climate campaigners have cheered the decline of coal but in the US the fuel is largely being replaced by gas, which burns more cleanly than coal but still emits a sizable amount of carbon dioxide and methane, a powerful greenhouse gas, in its production, whereas in the EU wind and solar overtook gas last year.

Renewables accounted for 11% of total US energy consumption last year – a share that will have to radically expand if dangerous climate change is to be avoided. Petroleum made up 37% of the total, followed by gas at 32%. Renewables marginally edged out coal, while nuclear stood at 8%.

“Getting past coal is a big first hurdle but the next round will be the gas industry,” said Wamsted. “There are emissions from gas plants and they are significant. It’s certainly not over.”
 

 

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The UK’s energy plan is all very well but it ignores the forecast rise in global sea-levels

UK Marine Energy and Climate Resilience can counter sea level rise and storm surge with tidal power, subsea turbines, heat pumps, and flood barriers, delivering renewable electricity, stability, and coastal protection for the United Kingdom.

 

Key Points

Integrated use of tidal power, barriers, and heat pumps to curb sea level rise, manage storms, and green the UK grid.

✅ Tidal bridges and subsea turbines enhance baseload renewables

✅ Integrated barriers cut storm surge and river flood risk

✅ Heat pumps and marine heat networks decarbonize coastal cities

 

IN concentrating on electrically driven cars, the UK’s new ten-point energy plans, and recent UK net zero policies, ignores the elephant in the room.

It fails to address the forecast six-metre sea level rise from global warming rapidly melting the Greenland ice sheet.

Rising sea levels and storm surge, combined with increasingly heavy rainfall swelling our rivers, threaten not only hundreds of coastal communities but also much unprotected strategic infrastructure, including electricity systems that need greater resilience.

New nuclear power stations proposed in this United Kingdom plan would produce radioactive waste requiring thousands of years to safely decay.

This is hardly the solution for the Green Energy future, or the broader global energy transition, that our overlooked marine energy resource could provide.

Sea defences and barrier design, built and integrated with subsea turbines and heat pumps, can deliver marine-driven heat and power to offset the costs, not only of new Thames Barriers, but also future Severn, Forth and other barrages, while reducing reliance on high-GWP gases such as SF6 in switchgear across the grid.

At the Pentland Firth, existing marine turbine power could be enhanced by turbines deployed from new tidal bridges to provide much of UK’s electricity needs, as nations chart an electricity future that replaces fossil fuels, from its estimated 60 gigawatt capability.

Energy from Bluemull Sound could likewise be harvested and exported or used to enhance development around UK’s new space station at Unst.

The 2021 Climate Change Summit gives Glasgow the platform to secure Scotland’s place in a true green, marine energy future and help build an electric planet for the long term.

We must not waste this opportunity.

THERE is no vaccine for climate change.

It is, of course, wonderful news that such progress is being made in the development of Covid-19 vaccines but there is a risk that, no matter how serious the Covid crisis is, it is distracting attention, political will and resources from the climate crisis, a much longer term and more devastating catastrophe.

They are intertwined. As climate and ecological systems change, vectors and pathogens migrate and disease spreads.

What lessons can be learned from one to apply to the other?

Prevention is better than cure. We need to urgently address the climate crisis, charting a path to net zero electricity by the middle of the century, to help prevent future pandemics.

We are only as safe as the most vulnerable. Covid immunisation will protect the most vulnerable; to protect against the effects of climate change we need to look far more deeply. Global challenges require systemic change.

Neither Covid or climate change respect national borders and, for both, we need to value and trust science and the scientific experts and separate them from political posturing.

 

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Restrict price charged for gas and electricity - British MPs

UK Energy Price Cap aims to protect consumers on gas and electricity bills, tackling Big Six overcharging on default and standard variable tariffs, with Ofgem and MPs pushing urgent reforms to the broken market.

 

Key Points

A temporary absolute limit on default energy tariffs to shield consumers from overcharging on gas and electricity bills.

✅ Caps standard variable and default tariffs to protect loyalty.

✅ Targets Big Six pricing; oversight by Ofgem and BEIS MPs.

✅ Aims for winter protection while maintaining competition.

 

MPs are calling for a cap on the price of gas and electricity, with questions over the expected cost of a UK price cap amid fears consumers are being ripped off.

The Business, Energy and Industrial Strategy (BEIS) Select Committee says the Big Six energy companies have been overcharging for years.

MPs on the committee backed plans for a temporary absolute cap, noting debates over EU gas price cap strategies to fix what they called a "broken" energy market.

Labour's Rachel Reeves, who chairs the committee, said: "The energy market is broken. Energy is an essential good and yet millions of customers are ripped off for staying loyal to their energy provider.

"An energy price cap is now necessary and the Government must act urgently to ensure it is in place to protect customers next winter.

"The Big Six energy companies might whine and wail about the introduction of a price cap but they've been overcharging their customers on default and SVTs (standard variable tariffs) for years and their recent feeble efforts to move consumers off these tariffs has only served to highlight the need for this intervention."

The Committee also criticised Ofgem for failing to protect customers, especially the most vulnerable.

Draft legislation for an absolute cap on energy tariffs was published by the Government last year, and later developments like the Energy Security Bill have kept reform on the agenda.

But Business Secretary Greg Clark refused to guarantee that the flagship plans would be in place by next winter, despite warnings about high winter energy costs for households.

Committee members said there was a "clear lack of will" on the part of the Big Six to do what was necessary, including exploring decoupling gas and electricity prices, to deal with pricing problems.

A report from the committee found that customers are paying £1.4bn a year more than they should be under the current system.

Around 12 million households are stuck on poor-value tariffs, according to the report.

National assistance charity Citizens Advice said "loyal and vulnerable" customers had been "ripped off" for too long.

Chief executive Gillian Guy said: "An absolute cap, as recommended by the committee, is crucial to securing protection for the largest number of customers while continuing to provide competition in the market. This should apply to all default tariffs."

 

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New clean energy investment in developing nations slipped sharply last year: report

Developing Countries Clean Energy investment fell as renewable energy financing slowed in China; solar and wind growth lagged while coal power hit new highs, raising emissions risks for emerging markets and complicating climate change goals.

 

Key Points

Renewables investment and power trends in emerging nations: solar, wind, coal shifts, and steps toward decarbonization.

✅ Investment fell to $133b; China dropped to $86b

✅ Coal power rose to 6,900 TWh; 47% generation share

✅ New coal builds declined to 39 GW, decade low

 

New clean energy investment slid by more than a fifth in developing countries last year due to a slowdown in China, while the amount of coal-fired power generation jumped to a new high, reflecting global power demand trends, a recent annual survey showed.

Bloomberg New Energy Finance (BNEF) surveyed 104 emerging markets and found that developing nations were moving towards cleaner, low-emissions sources in many regions, but not fast enough to limit carbon dioxide emissions or the effects of climate change.

New investment in wind, solar and other clean energy projects dropped to $133 billion last year from $169 billion a year earlier, mainly due to a slump in Chinese investment, even as electricity investment globally surpasses oil and gas for the first time, the research showed.

China’s clean energy investment fell to $86 billion from $122 billion a year earlier, with dynamics in China's electricity sector also in focus. Investment by India and Brazil also declined, mainly due to lower costs for solar and wind.

However, the volume of coal-fired power generation produced and consumed in developing countries increased to a new high of 6,900 terrawatt hours (TWh) last year, even as renewables are poised to eclipse coal globally, from 6,400 TWh in 2017.

The increase of 500 TWh is equivalent to the power consumed in the U.S. state of Texas in one year, underscoring how surging electricity demand is putting power systems under strain. Coal accounted for 47% of all power generation across the 104 countries.

“The transition from coal toward cleaner sources in developing nations is underway,” said Ethan Zindler, head of Americas at BNEF. “But like trying to turn a massive oil tanker, it takes time.”

Despite the spike in coal-fired generation, the amount of new coal capacity which was added to the grid in developing countries declined, with Europe's renewables crowding out gas offering a contrasting pathway. New construction of coal plants fell to its lowest level in a decade last year of 39 gigawatts (GW).

The report comes a week ahead of United Nations climate talks in Madrid, Spain, where more than 190 countries will flesh out the details of an accord to limit global warming.

 

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