Is clean tech ChinaÂ’s moon shot?

By Reuters


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So far, wind turbines are not Sputnik. But one day they could be.

The global race to develop clean technology is not just about who can build the best solar parks or wind farms. It is also shaping up as a contest between Chinese-style capitalism and the more market-oriented approach fancied by the United States and Europe.

The question comes down to this: will China's highly capitalized command-and-control economy trump laissez-faire in a low-carbon shift that is widely portrayed as the next industrial revolution?

The failure in Copenhagen to agree to replace the Kyoto Protocol with a new global climate treaty when it expires in 2012 has thrown the focus on national measures. And by almost all accounts, the Chinese are coming on strong.

Beijing's top leaders have made clear their intention to have their nation dominate this new industry, up and down the value ladder. And in their quest for the prize, they are not burdened by concerns facing their Western counterparts — such as the impact of wind turbines on landscapes, higher energy prices for consumers, or investor returns.

"Developed markets need to be aware that China is gaining in this space," said David Russell, co-head of responsible investment at the 28 billion pound (US $45 billion) British universities pension fund, the Universities Superannuation Scheme (USS).

The recession has made it tougher for Europe and America to effect meaningful climate policy change. And with most major nations piling on debt to stimulate flagging economies, politicians likely will find it harder to earmark additional voter money for clean technology.

Instead, recession-hit Western economies are hoping the private sector can plug an estimated worldwide $150 billion annual funding gap to avoid more extreme droughts and floods.

But investors almost always follow the returns, and if the performance is not there, they are not likely to risk their capital. For example, Britain's USS allocates about half a percent of its assets to low-carbon and renewable energy funds, not including its investment in conventional energy companies, which themselves will have some green tinges.

It's hard to imagine the West filling the clean tech funding gap if pension funds — which are as influential as they are big — don't pony up more.

Russell says he would like to do more, but like other fund managers he has an obligation to pension holders. He and other fund managers say they won't allocate more to green because their first duty is to guarantee payouts for their members, and while clean tech stocks can yield decent returns, they are often small and risky.

Since a trough in global equities last March, energy efficiency stocks have risen 126 percent and clean energy and technology by 88 percent, compared with wider global stocks' 70 percent, a Deutsche report found this month.

But there are limited opportunities for investors. Oil majors, for example, dwarf the asset value of green companies, and cleantech funds can't move the dial for the big funds whose participation is necessary to close the funding gap.

Advantage, China?

Fortunately for the West, it's not so simple.

The global wind industry highlights diverging tactics between China and the West in developing important new markets.

China is leapfrogging global wind power rankings with a combination of aggressive growth targets and domestic support. It has doubled its entire installed capacity each year since 2005, according to the Global Wind Energy Council (GWEC).

This month, the British government announced plans for 32 gigawatts of offshore wind by 2020 — more than a third of its entire present electricity generating capacity now.

The plan also depends on 100 billion pounds of increasingly finicky private capital. And this is an election year.

"I think it will happen," said Benjamin Sykes, head of renewables technology at the UK government-funded Carbon Trust, which advises British companies on how to reduce their carbon footprint. "It's do-able."

Others are less sure. "I don't think it's achievable without a big redirection of investment focus," said investor Tom Murley, at private equity firm HgCapital.

Murley runs a 300-million euro infrastructure fund focused on renewable energy projects in western Europe, in wind power, biogas and solar. The fund has combined debt and equity assets worth over 1 billion euros.

"Will the capital flow to this sector? That's the big question mark. Offshore wind is still relatively new, as yet we don't really know how that equipment is going to perform in the long-run, whether that's really going to be a good investment," said Murley.

As he and other investors see it, British policymakers have to make a choice: either create bigger incentives for investors to underwrite offshore wind power or impose additional taxes on fossil fuels, which would make carbon-based energy less profitable.

Europe has the world's clearest, most ambitious renewable energy law, most analysts agree. A European Union directive requires that the 27-nation bloc get a fifth of its energy from renewable sources by 2020.

Germany is leading the charge there. It has the world's biggest solar power market because of aggressive market incentives that even Beijing has sought to mimic.

But China has its own distinct advantages. First and foremost is a "cozy relationship" between state-owned utilities, grid companies and banks, said Steve Sawyer, secretary-general of the Global Wind Energy Council.

China is expected to announce a target soon for about 150 gigawatts of wind power by 2020, which it would hit if it simply maintained present annual capacity growth, said Sawyer. The country also has two turbine makers, Sinovel and Goldwind, in the world top 10, according to the International Energy Agency.

Tao Wang, a climate policy expert with WWF China, said the country would this year develop its next five-year development plan to run from the start of 2011: this is likely to contain new steps to boost alternative energy.

"The Chinese government is essentially using the state banks and state power companies to support and foster a turbine industry," said Jefferies Bank analyst Michael McNamara.

It's not as if Western governments aren't involved in promoting wind turbines. The United States and Germany are the top two countries by installed power, and China edged out Spain into third place last year, according to GWEC.

How fast wind power develops in the United States depends on a climate and energy bill. If the United States passed a bill with an ambitious renewable energy target then "all bets are off" on the pace of growth, said Jefferies' McNamara.

But China has been on a tear — last year it installed more wind turbines than any other country, says GWEC.

Furthermore, Western businesses are worried China is freezing them out of this lucrative market, preferring to nurture its own nascent industries without subjecting them to competition.

"The state-owned energy company sets up its development arm and they then go to a state-owned bank to get the funding, and they go to a state-owned grid company to make sure they can get a grid connection, and then lo and behold! If there's a bidding process, the state-owned turbine manufacturers happen to win the contracts," said McNamara.

That process has annoyed some Western manufacturers. They say that despite being forced to build local factories in China, because of a "local content" rule for installed turbines, they were still passed over on major contracts.

Some Western analysts still believe a markets-oriented approach works best and will ultimately prevail.

They argue that subsidized inputs will result in a less efficient industry, more focused on volume than cost and quality. "The best solutions come out of a competitive environment," said the Carbon Trust's Sykes.

The focus on adding new capacity has also run ahead of grid connections, meaning many Chinese turbines may never actually produce electricity.

"They will look like wind farms, and they may spin like wind farms, but there's no guarantee that they will actually work like wind farms," said Michael Liebreich, chief executive of the research firm Bloomberg New Energy Finance.

Moreover, some in the West believe the United States still has an advantage in innovation. The owner of patents, not factories, will likely earn the biggest profits and win the technology race.

In a Reuters poll of 41 U.S. venture capital investors, more than three-quarters of respondents said the United States would be the best market for cleantech over the next five years, and 88 percent believed America was the best place to base this business in the same time period. China ranked as the second best market (with 16 percent of the total).

"The world has absolutely no hope of making any substantial impact on global warming without major scientific breakthroughs, almost all which will come from United States' innovation," said Robert Nelsen, co-founder and managing director of Arch Venture Partners.

An undeniable edge for China is its huge pile of foreign exchange reserves. The nation's clean energy industry has recently benefited from Beijing's aggressive economic stimulus, which included funds for energy-efficient buildings.

Signs of an overheating Chinese economy may turn that tap down for a spell. By contrast, Western economies are expected to spend much of their green recovery cash this year and next.

In recession-battered Western nations, and in China, the prime motives for promoting clean technology are jobs, profits and energy security — not climate change. That leaves no guarantee that there will be enough investment to fight global warming.

An estimated $150 billion invested globally last year was only about half what is required annually by 2015 to avoid dangerous climate change, the International Energy Agency estimates.

"There is a big funding gap. I would say we need at least a doubling by 2015," said Cecilia Tam, citing draft estimates the IEA published in June.

If over the next 20 years the world is to boost renewable power, build greener buildings and roll out more fuel-scrimping cars including hybrid and electric models, it must invest more than an additional $500 billion annually, according to Tam.

Many forms of renewable power are expected to be more expensive than their fossil fuel counterparts for at least another decade.

Given the incompatibility of communist-style targets with western democracies, how can free markets mobilize more green technology cash?

Western nations could boost clean investor returns with a tax on fossil fuels or guaranteed higher prices for renewable power. And aside from market levers, governments could adopt standards to make clean tech more attractive — requiring homes to install smart meters, for example — but rapid deployment doesn't seem politically palatable at the moment.

"It's worthwhile learning from the Chinese that these big transformations do require some exercise of public power," said James Cameron, vice-chairman of green investors and advisers Climate Change Capital.

Dutch pension asset manager APG has about 2 billion euros allocated to green investments, by the "broadest definition", said Rob Lake, head of sustainability. That compares with total assets of 206 billion euros.

"The reality at the moment is that investment in oil and gas is still attractive," said Lake.

But pension funds and other institutional investors can do more. Even if they don't put more of their own money into clean tech, they can use their clout to encourage more conventional energy companies to clean up, said Marcel Jeucken, head of responsible investment at the Netherlands-based, 86 billion euro PGGM pension asset manager.

Jeucken said his fund is "in constant dialogue" with Royal Dutch Shell, the oil major with a major investment in Canadian oil sands — where oil production entails more carbon emissions than conventional oil fields.

"We used our shareholder rights wherever possible," he added. "Climate is one of our focus areas, and within that we are working on oil sands. We initiated a trip to the oil and fields last year."

A discouraging sign for investors who were hoping environmental markets would soon take off is the cloudy future of cap-and-trade plans. Such schemes force coal plants and other polluters to buy carbon emissions permits. They add to the cost of electricity, and are proving a hard sell in the United States.

Opposition to cap-and-trade among U.S. Republicans and some Democrats could block the roll-out of a federal trading scheme which would limit the further growth of global carbon markets, valued at around $125 billion last year.

Furthermore, last month's U.N. summit in Copenhagen was expected to unveil an expansion of global trade in carbon offsets between rich and developing nations, but in the end they won no explicit mention in a weak, final declaration.

What all that means for traders is clear: "To tell you the truth I'm starting to look toward other commodities — uranium," said Laurent Segalen, head of emissions trading at Nomura.

Does all this suggest China is destined to win the clean tech race? Hardly, though it does seem to have a little more forward momentum than do its rivals these days.

But it's still very early goings, and there's more at stake than business success.

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BC Hydro activates "winter payment plan"

BC Hydro Winter Payment Plan lets customers spread electricity bills over six months during cold weather, easing costs amid colder-than-average temperatures in British Columbia, with low-income conservation support, energy-saving kits, and insulation upgrades.

 

Key Points

Allows BC Hydro customers to spread winter electricity bills over six months, with added low-income efficiency support.

✅ Spread Dec-Mar bills across six months

✅ Eases costs during colder-than-average temperatures

✅ Includes low-income conservation and energy-saving kits

 

As colder temperatures set in across the province again this weekend, BC Hydro says it is activating its winter payment plan to give customers the opportunity to spread out their electricity bills as demand can reach record levels during extreme cold periods.

"Our meteorologists are predicting colder-than-average temperatures will continue over the next of couple of months and we want to provide customers with help to manage their payments," said Chris O'Riley, BC Hydro's president.

All BC Hydro customers will be able to spread payments from the billing period spanning Dec. 1, 2017 to March 31, 2018 over a six-month period.

Cold weather in the second half of December 2017 led to surging electricity demand that was higher than the previous 10-year average and has at times hit all-time highs during peak usage periods, according to BC Hydro.

Hydro operations also respond to summer conditions, as drought and low rainfall can force adjustments in power generation strategies.

People who heat their homes with electricity — about 40 per cent of British Columbians —  have the highest overall bills in the province, $197 more in December than in July, when air conditioning use can affect energy costs.

This is the second year the Crown corporation has activated a cold-weather payment plan, part of broader customer assistance programs it offers.  

BC Hydro has also increased funding for its low-income conservation programs by $2.2 million for a total of $10 million over the next three years. 

The low-income program provides energy-saving kits that include things like free energy assessments, insulation upgrades and weather stripping. 

 

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France's nuclear power stations to limit energy output due to high river temperatures

France Nuclear Heatwave Output Restrictions signal reduced reactor capacity along the Rhone River, as EDF curbs output to meet cooling-water rules, balance the grid, integrate solar peaks, and limit impacts on power prices.

 

Key Points

EDF limits reactor output during heat to protect rivers and keep the grid stable under cooling-water rules.

✅ Cuts likely at midday/weekends when solar peaks

✅ Bugey, Saint Alban maintain minimum grid output

✅ France net exporter; price impact expected small

 

The high temperature warning has come early this year but will affect fewer nuclear power plants, amid a broader France-Germany nuclear dispute over atomic power policy that shapes regional energy flows.

High temperatures could halve nuclear power production at plants along France's Rhone River this week, as European power hits records during extreme heat. 

Output restrictions are expected at two nuclear plants in eastern France due to high temperature forecasts, nuclear operator EDF said, which may limit energy output during heatwaves. It comes several days ahead of a similar warning that was made last year but will affect fewer plants.

The hot weather is likely to halve the available power supply from the 3.6 GW Bugey plant from 13 July and the 2.6 GW Saint Alban plant from 16 July, the operator said.

However, production will be at least 1.8 GW at Bugey and 1.3 GW at Saint Alban to meet grid requirements, and may change according to grid needs, the operator said.

Kpler analyst Emeric de Vigan said the restrictions were likely to have little effect on output in practice. Cuts are likely only at the weekend or midday when solar output was at its peak so the impact on power prices would be slim.

During recent lockdowns, power demand held firm in Europe, offering context for current price dynamics.

He said the situation would need monitoring in the coming weeks, however, noting it was unusually early in the summer for such restrictions to be imposed.

Water temperatures at the Bugey plant already eclipsed the initial threshold for restrictions on 9 July, underscoring France's outage risks under heat-driven constraints. They are currently forecast to peak next week and then drop again, Refinitiv data showed.

"France is currently net exporting large amounts of power – single nuclear units' supply restrictions will not have the same effect as last year," Refinitiv analyst Nathalie Gerl said.

The Garonne River in southern France has the highest potential for critical levels of warming, but its Golfech plant is currently offline for maintenance until mid-August, the data showed, highlighting how Europe is losing nuclear power during critical periods.

"(The restrictions were) to be expected and it will probably occur more often," Greenpeace campaigner Roger Spautz said.

"The authorities must stick to existing regulations for water discharges. Otherwise, the ecosystems will be even more affected," he added.

 

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Hydro One and Alectra announce major investments to strengthen electricity infrastructure and improve local reliability in the Hamilton area

Hydro One and Alectra Hamilton Grid Upgrades will modernize electricity infrastructure with new transformers, protection devices, transmission and distribution improvements, tree trimming, pole replacements, and line refurbishments to boost reliability and reduce outages across region.

 

Key Points

A $250M plan to modernize Hamilton transmission and distribution, reducing outages and improving reliability by 2022.

✅ New transformers and protection devices to cut outages

✅ Refurbished 1915 line powering Hamilton West Mountain

✅ Tree trimming and pole replacements across 1,260 km

 

Hydro One Networks Inc. (Hydro One), Ontario's largest electricity transmission and distribution company whose delivery rates recently increased, and Alectra Utilities have announced they expect to complete approximately $250 million of work in the Hamilton area by 2022 to upgrade local electricity infrastructure and improve service reliability.

As part of these plans to strengthen the electricity grid in the Hamilton region, where utilities must adapt to climate change pressures, investments are expected to include:

installing quieter, more efficient transformers in four stations across Hamilton to assist in reducing the number of outages;
replacing protection and switching devices across the city to shorten outage restoration times, reflecting how transmission line work underpins reliability;
refurbishing a power line originally installed in 1915 that is critical to powering the Hamilton West Mountain area; and,
trimming hazardous trees across more than 1,260 km of overhead powerlines and replacing more than 270 poles.
Hydro One will be working with Alectra Utilities to replace aging infrastructure at Elgin transmission station.

"A loss of power grinds life to a halt, impacting businesses, families and productivity. That's why Hydro One is partnering with Alectra Utilities to support a growing local economy in Hamilton, while improving power reliability for its residents," said Jason Fitzsimmons, Chief Corporate Affairs and Customer Care Officer. "Replacing aging infrastructure and modernizing equipment is part of our plan to build a stronger, safer and more reliable electricity system for Ontario now and into the future." 

"Partnering with Hydro One to invest in our local community will create a safer, more resilient and reliable system for the future," said Max Cananzi, President, Alectra Utilities.  "In addition to investments in the transmission system, Alectra Utilities also plans to invest $235 million over the next five years to renew, upgrade and connect customers to the electrical distribution and supporting systems in Hamilton. Investments in the transmission and distribution systems in Hamilton will contribute to the long-term sustainability of our communities."

"I am pleased to see Hydro One and Alectra investing in modernizing local electricity infrastructure and improving reliability," said Member of Provincial Parliament, Donna Skelly.  "Safe and reliable power is essential to supporting local families, businesses and our community."

Across Ontario, First Nations call for action on urgently needed transmission lines highlight the importance of timely grid investments.

Hydro One's investments included in this announcement are captured in its previously disclosed future capital expenditures, amid proposed projects like the Meaford hydro project across Ontario.

Much of Hydro One's electricity system was built in the 1950s, and replacing aging assets is critical as delays affecting a cross-border transmission line elsewhere have shown. Its three-year, $5 billion investment plan supports safe and reliable power to communities across Ontario, and strong regulatory oversight illustrated by the ATCO Electric penalty helps maintain public trust.


 

 

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When paying $1 for a coal power plant is still paying too much

San Juan Generating Station eyed for $1 coal-plant sale, as Farmington and Acme propose CCS retrofit, meeting emissions caps and renewable mandates by selling captured CO2 for enhanced oil recovery via a nearby pipeline.

 

Key Points

A New Mexico coal plant eyed for $1 and a CCS retrofit to cut emissions and sell CO2 for enhanced oil recovery.

✅ $400M-$800M CCS retrofit; 90% CO2 capture target

✅ CO2 sales for enhanced oil recovery; 20-mile pipeline gap

✅ PNM projects shutdown savings; renewable and emissions mandates

 

One dollar. That’s how much an aging New Mexico coal plant is worth. And by some estimates, even that may be too much.

Acme Equities LLC, a New York-based holding company, is in talks to buy the 847-megawatt San Juan Generating Station for $1, after four of its five owners decided to shut it down. The fifth owner, the nearby city of Farmington, says it’s pursuing the bargain-basement deal with Acme to avoid losing about 1,600 direct and indirect jobs in the area amid a broader just transition debate for energy workers.

 

We respectfully disagree with the notion that the plant is not economical

Acme’s interest comes as others are looking to exit a coal industry that’s been plagued by costly anti-pollution regulations. Acme’s plan: Buy the plant "at a very low cost," invest in carbon capture technology that will lower emissions, and then sell the captured CO2 to oil companies, said Larry Heller, a principal at the holding group.

By doing this, Acme “believes we can generate an acceptable rate of return,” Heller said in an email.

Meanwhile, San Juan’s majority owner, PNM Resources Inc., offers a distinctly different view, echoing declining coal returns reported by other utilities. A 2022 shutdown will push ratepayers to other energy alternatives now being planned, saving them about $3 to $4 a month on average, PNM has said.

“We could not identify a solution that would make running San Juan Generating Station economical,” said Tom Fallgren, a PNM vice president, in an email.

The potential sale comes as a new clean-energy bill, supported by Governor Lujan Grisham, is working its way through the state legislature. It would require the state to get half of its power from renewable sources by 2030, and 100 percent by 2045, even as other jurisdictions explore small modular reactor strategies to meet future demand. At the same time, the legislation imposes an emissions cap that’s about 60 percent lower than San Juan’s current levels.

In response, Acme is planning to spend $400 million to $800 million to retrofit the facility with carbon capture and sequestration technology that would collect carbon dioxide before it’s released into the atmosphere, Heller said. That would put the facility into compliance with the pending legislation and, at the same time, help generate revenue for the plant.

The company estimates the system would cut emissions by as much as 90 percent, and the captured gas could be sold to oil companies, which uses it to enhance well recovery. The bottom line, according to Heller: “A winning financial formula.”

It’s a tricky formula at best. Carbon-capture technology has been controversial, even as new coal plant openings remain rare, expensive to install and unproven at scale. Additionally, to make it work at the San Juan plant, the company would need to figure out how to deliver the CO2 to customers since the nearest pipeline is about 20 miles (32 kilometers) away.

 

Reducing costs

Acme is also evaluating ways to reduce costs at San Juan, Heller said, including approaches seen at operators extending the life of coal plants under regulatory scrutiny, such as negotiating a cheaper coal-supply contract and qualifying for subsidies.

Farmington’s stake in the plant is less than 10 percent. But under terms of the partnership, the city — population 45,000 — can assume full control of San Juan should the other partners decide to pull out, mirroring policy debates over saving struggling nuclear plants in other regions. That’s given Farmington the legal authority to pursue the plant’s sale to Acme.

 

At the end of the day, nobody wants the energy

“We respectfully disagree with the notion that the plant is not economical,” Farmington Mayor Nate Duckett said by email. Ducket said he’s in better position than the other owners to assess San Juan’s importance “because we sit at Ground Zero.”

The city’s economy would benefit from keeping open both the plant and a nearby coal mine that feeds it, according to Duckett, with operations that contribute about $170 million annually to the local area.

While the loss of those jobs would be painful to some, Camilla Feibelman, a Sierra Club chapter director, is hard pressed to see a business case for keeping San Juan open, pointing to sector closures such as the Three Mile Island shutdown as evidence of shifting economics. The plant isn’t economical now, and would almost certainly be less so after investing the capital to add carbon-capture systems.

 

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West Coast consumers won't benefit if Trump privatizes the electrical grid

BPA Privatization would sell the Bonneville Power Administration's transmission lines, raising FERC-regulated grid rates for ratepayers, impacting hydropower and the California-Oregon Intertie under the Trump 2018 budget proposal in the Pacific Northwest region.

 

Key Points

Selling Bonneville's transmission grid to private owners, raising rates and returns, shifting costs to ratepayers.

✅ Trump 2018 budget targets BPA transmission assets for sale.

✅ Higher capital costs, taxes, and profit would raise transmission rates.

✅ California-Oregon Intertie and hydropower flows face price impacts.

 

President Trump's 2018 budget proposal is so chock-full of noxious elements — replacing food stamps with "food boxes," drastically cutting Medicaid and Medicare, for a start — that it's unsurprising that one of its most misguided pieces has slipped under the radar.

That's the proposal to privatize the government-owned Bonneville Power Administration, which owns about three-quarters of the high-voltage electric transmission lines in a region that includes California, Washington state and Oregon, serving more than 13.5 million customers. By one authoritative estimate, any such sale would drive up the cost of transmission by 26%-44%.

The $5.2-billon price cited by the Trump administration, moreover, is nearly 20% below the actual value of the Bonneville grid — meaning that a private buyer would pocket an immediate windfall of $1.2 billion, at the expense of federal taxpayers and Bonneville customers.

Trump's plan for Portland, Ore.-based Bonneville is part of a larger proposal to sell off other government-owned electricity bodies, including the Colorado-based Western Area Power Administration and the Oklahoma-based Southwestern Power Administration. But Bonneville is by far the largest of the three, accounting for nearly 90% of the total $5.8 billion the budget anticipates collecting from the sales. The proposal is also part of the administration's

Both plans are said to be politically dead-on-arrival in Washington. But they offer a window into the thinking in the Trump White House.

"The word 'muddle' comes to mind," says Robert McCullough, a respected Portland energy consultant, referring to the justification for the privatization sale included in the Trump budget.

The White House suggests that selling the Bonneville grid would result in lower costs. But that narrative, McCullough wrote in a blistering assessment of the proposal, "displays a severe lack of understanding about the process of setting transmission rates."

McCullough's assessment is an update of a similar analysis he performed when the privatization scheme was first raised by the Trump administration last year. In that analysis issued in June, McCullough said the proposal "raises the question of why these valuable assets would be sold at a discount — and who would get the benefit of the discounted price."

The implications of a sale could be dire for Californians. Bonneville is the majority owner of the California-Oregon Intertie, an electrical transmission system that carries power, including Columbia River-generated hydropower and other clean-energy generation in British Columbia that supports the regional exchange, south to California in the summer and excess California generation to the Pacific Northwest in the winter.

But the idea has drawn fire throughout the region. When it was first broached last year, the Public Power Council, an association of utilities in the Northwest, assailed it as an apparent "transfer of value from the people of the Northwest to the U.S. Treasury," drawing parallels to Manitoba Hydro governance issues elsewhere.

The region's political leaders had especially harsh words for the idea this time around. "Oregonians raised hell last year when Trump tried to raise power bills for Pacific Northwesterners by selling off Bonneville Power, and yet his administration is back at it again," Sen. Ron Wyden (D-Ore.) said after the idea reappeared. "Our investment shouldn't be put up for sale to free up money for runaway military spending or tax cuts for billionaires." Sen. Maria Cantwell (D-Wash.) promised in a statement to work to "stop this bad idea in its tracks."

The notion of privatizing Bonneville predates the Trump administration; it was raised by Bill Clinton and again by George W. Bush, who thought the public would gain if the administration could sell its power at market rates. Both initiatives failed.

The same free-enterprise ideology underlies the Trump proposal. Privatizing the transmission lines "encourages a more efficient allocation of economic resources and mitigates unnecessary risk to taxpayers," the budget asserts. "Ownership of transmission assets is best carried out by the private sector where there are appropriate market and regulatory incentives."

But that's based on a misunderstanding of how transmission rates are set, McCullough says. Transmission is essentially a monopoly enterprise, with rates overseen by the Federal Energy Regulatory Commission based on the grid's costs, and with federal scrutiny of public utilities such as the TVA underscoring that oversight. There's very little in the way of market "incentives" involved in transmission, since no one has come forward to build a competing grid.

Those include the owners' cost of capital — which would be much higher for a private owner than a government agency, McCullough observes, as Hydro One investor uncertainty demonstrates in practice. A private owner, unlike the government-owned Bonneville, also would owe federal income taxes, which would be passed on to consumers.

Then there's the profit motive. Bonneville "currently sells and delivers its power at cost," McCullough wrote last year. "Under a private regime, an investor-owned utility would likely charge a higher rate of return, a pattern seen when UK network profits drew regulatory rebukes."

None of these considerations appears to have been factored into the White House budget proposal. "Either there's an unsophisticated person at the Office of Management and Budget thinking up these numbers himself," McCullough told me, "or there would seem to be ongoing negotiations with an unidentified third party." No such buyer has emerged in the past, however.

What's left is a blind faith in the magic of the market, compounded by ignorance about how the transmission market operates. Put it together, and there's reason to wonder if Trump is even serious about this plan.

 

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NRC Begins Special Inspection at River Bend Nuclear Power Plant

NRC Special Inspection at River Bend reviews failures of portable emergency diesel generators, nuclear safety measures, and Entergy Operations actions after Fukushima; off-site power loss readiness, remote COVID-19 oversight, and corrective action plans are assessed.

 

Key Points

An NRC review of generator test failures at River Bend, assessing nuclear safety, root causes, and corrective actions.

✅ Evaluates failures of portable emergency diesel generators

✅ Reviews causal analyses and adequacy of corrective actions

✅ Remote COVID-19 oversight; public report expected within 45 days

 

The Nuclear Regulatory Commission has begun a special inspection at the River Bend nuclear power plant, part of broader oversight that includes the Turkey Point renewal application, to review circumstances related to the failure of five portable emergency diesel generators during testing. The plant, operated by Entergy Operations, is located in St. Francisville, La., as nations like France outage risks continue to highlight broader reliability concerns.

The generators are used to supply power to plant systems in the event of a prolonged loss of off-site electrical power coupled with a failure of the permanently installed emergency generators, a concern underscored by incidents such as the SC nuclear plant leak that shut down production for weeks. These portable generators were acquired as part of the facility's safety enhancements mandated by the NRC following the 2011 accident at the Fukushima Dai-ichi facility in Japan, and amid constraints like France limiting output from warm rivers, the emphasis on resilience remains.

The three-member NRC team will develop a chronology of the test failures and evaluate the licensee's causal analyses and the adequacy of corrective actions, informed by lessons from cases like Davis-Besse closure stakes that underscore risk management.

Due to the COVID-19 pandemic, they will complete most of their work remotely, while other regions address constraints such as high river temperatures limiting output for nuclear stations. An inspection report documenting the team's findings, released as global nuclear project milestones continue across the sector, will be publicly available within 45 days of the end of the inspection.
 

 

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