China to add $8 Billion in grid investment for 2008-2009

By Industrial Info Resources


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Benefitting from the $584 billion investment program and the associated 10 specific measures in promoting domestic power demand announced by the State Council of China early this month, insiders expect that the total investment in the nation's power grid by the end of 2009 will include an additional $8 billion in addition to the originally planned $110 billion.

Among the 10 specific measures, two are directly related to grid investment — namely, the improvement of the rural grid in accelerating the construction of infrastructures in rural areas and the acceleration of urban grid reformation and grid construction in the quake-hit area.

Of the total previously planned investment of $110 billion for the period from 2008 to 2009, the rural grid accounted for about 5%-8%, and the urban grid of 220 kilovolts (kV) or lower accounted for about 50%. The issuance of the recent new policy will promote investment in the grid by about 10%.

Enhanced investment in rural-grid construction will help improve the rural grid, which is currently a weak point in the national grid, as rural electricity supply companies in each province are mostly incapable of increasing investment because they are often operating at a loss. Specific implementation plans will be launched by the two national grid enterprises, the State Grid Corporation of China (SGC) and China Southern Power Grid Corporation shortly.

Enhanced investment in urban grid reformation is favorable for the improvement of urban distribution grids of 220 kV or lower. Insiders believe that implementing this policy will not necessarily squeeze out investment for sections of the grid operating at 500 kV or more. On the contrary, investment in trans-regional grid and the ultra-high voltage grid will also be enhanced.

On November 8, 2008, the SGC signed an agreement with the government of Shandong province to enhance the main grid construction as well as the construction of a reliable outsourcing transmission path and the ultra-high voltage grid in Shandong province.

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New York State Moratorium on Utility Disconnections During Emergencies

New York Utility Disconnection Ban protects residents during state emergencies, covering electric, gas, water, telecommunications, cable, and internet services, with penalties for noncompliance and options like deferred payment agreements and consumer protections.

 

Key Points

A proposed law barring shutoffs in state emergencies across electric, gas, water, telecom, cable, and internet.

✅ Applies during declared state and local emergencies statewide.

✅ Covers electric, gas, water, telecom, cable, and internet services.

✅ Noncompliance triggers penalties; payment plans required for arrears.

 

Governor Andrew M. Cuomo has announced a proposal to prohibit utility disconnections in regions that are under a state of emergency, addressing the energy insecurity many households face, as part of the 2021 State of the State. The Governor will propose legislation that will apply to electric, gas, water, telecommunications, cable and internet services. Utilities that fail to comply will be subject to penalties.

“In a year in which we dealt with an unprecedented pandemic, ferocious storms added insult to injury by knocking out power for hundreds of thousands of New Yorkers,” Governor Cuomo said. “Utility companies provide essential services, and we need to make sure they continue to provide them, rain or shine. That’s why we’re proposing legislation to make sure that New Yorkers, especially those living in regions under states of emergency, have access to these critical services to provide for themselves and their families.”

Governor Cuomo has taken a series of actions to protect New Yorkers’ access to utilities during the COVID-19 pandemic, including a suspension of shut-offs in New York and New Jersey, among other measures. Last year, the Governor signed legislation extending a moratorium that prevents utility companies from disconnecting utilities to residential households that are struggling with their bills due to the COVID-19 pandemic, a move mirrored by reconnection efforts in Ontario by Hydro One. Utility companies must instead offer these individuals a deferred payment agreement on any past-due balance. 

On November 19, Governor Cuomo announced that Con Edison now faces $25 million in penalties and possible license revocation from the New York State Public Service Commission, amid a broader review of retail energy markets by state regulators, following an investigation into the utility’s failed response during large-scale power outages in Manhattan and Brooklyn in July 2019. On November 2, Governor Cuomo announced that more than $328 million in home heating aid is now available, similar to Ontario bill support during the pandemic, for low- and middle-income New Yorkers who need assistance keeping their homes warm during the coming winter season.

The Governor has previously enacted some of the strongest and most progressive consumer protection and assistance programs in the country, including smart streetlights in Syracuse that reduce energy costs, and other initiatives. Governor Cuomo established New York’s energy affordability policy in 2016, as states pursue renewable energy ambitions that can affect rates, underscoring the need for affordability. The policy extended energy bill support to more than 152,000 additional New York families, ensuring that more than 920,000 New York families spend no more than 6 percent of their income on energy bills. Through this program, New York commits more than $238 million annually helping to keep the lights and heat on for our most vulnerable New Yorkers, while actively striving to expand coverage to additional families.

 

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Germany's Call for Hydrogen-Ready Power Plants

Germany Hydrogen-Ready Power Plants Tender accelerates the energy transition by enabling clean energy generation, decarbonization, and green hydrogen integration through retrofit and new-build capacity, resilient infrastructure, flexible storage, and grid reliability provisions.

 

Key Points

Germany tender to build or convert plants for hydrogen, advancing decarbonization, energy security, and clean power.

✅ Hydrogen-ready retrofits and new-build generation capacity

✅ Supports decarbonization, grid reliability, and flexible storage

✅ Future-proof design for green hydrogen supply integration

 

Germany, a global leader in energy transition and environmental sustainability, has recently launched an ambitious call for tenders aimed at developing hydrogen-ready power plants. This initiative is a significant step in the country's strategy to transform its energy infrastructure and support the broader goal of a greener economy. The move underscores Germany’s commitment to reducing greenhouse gas emissions and advancing clean energy technologies.

The Need for Hydrogen-Ready Power Plants

Hydrogen, often hailed as a key player in the future of clean energy, offers a promising solution for decarbonizing various sectors, including power generation. Unlike fossil fuels, hydrogen produces zero carbon emissions when used in fuel cells or burned. This makes it an ideal candidate for replacing conventional energy sources that contribute to climate change.

Germany’s push for hydrogen-ready power plants reflects the country’s recognition of hydrogen’s potential in achieving its climate goals. Traditional power plants, which typically rely on coal, natural gas, or oil, emit substantial amounts of CO2. Transitioning these plants to utilize hydrogen can significantly reduce their carbon footprint and align with Germany's climate targets.

The Details of the Tender

The recent tender call is part of Germany's broader strategy to incorporate hydrogen into its energy mix, amid a nuclear option debate in climate policy. The tender seeks proposals for power plants that can either be converted to use hydrogen or be built with hydrogen capability from the outset. This approach allows for flexibility and innovation in how hydrogen technology is integrated into existing and new energy infrastructures.

One of the critical aspects of this initiative is the focus on “hydrogen readiness.” This means that power plants must be designed or retrofitted to operate with hydrogen either exclusively or in combination with other fuels. The goal is to ensure that these facilities can adapt to the growing availability of hydrogen and seamlessly transition from conventional fuels without significant additional modifications.

By setting such requirements, Germany aims to stimulate the development of technologies that can handle hydrogen’s unique properties and ensure that the infrastructure is future-proofed. This includes addressing challenges related to hydrogen storage, transportation, and combustion, and exploring concepts like storing electricity in natural gas pipes for system flexibility.

Strategic Implications for Germany

Germany’s call for hydrogen-ready power plants has several strategic implications. First and foremost, it aligns with the country’s broader energy strategy, which emphasizes the need for a transition from fossil fuels to cleaner alternatives, building on its decision to phase out coal and nuclear domestically. As part of its commitment to the Paris Agreement and its own climate action plans, Germany has set ambitious targets for reducing greenhouse gas emissions and increasing the share of renewable energy in its energy mix.

Hydrogen plays a crucial role in this strategy, particularly for sectors where direct electrification is challenging. For instance, heavy industry and certain industrial processes, such as green steel production, require high-temperature heat that is difficult to achieve with electricity alone. Hydrogen can fill this gap, providing a cleaner alternative to natural gas and coal.

Moreover, this initiative helps Germany bolster its leadership in green technology and innovation. By investing in hydrogen infrastructure, Germany positions itself as a pioneer in the global energy transition, potentially influencing international standards and practices. The development of hydrogen-ready power plants also opens up new economic opportunities, including job creation in engineering, construction, and technology sectors.

Challenges and Opportunities

While the push for hydrogen-ready power plants presents significant opportunities, it also comes with challenges. Hydrogen production, especially green hydrogen produced from renewable sources, remains relatively expensive compared to conventional fuels. Scaling up production and reducing costs are critical for making hydrogen a viable alternative for widespread use.

Furthermore, integrating hydrogen into existing power infrastructure, alongside electricity grid expansion, requires careful planning and investment. Issues such as retrofitting existing plants, ensuring safe handling of hydrogen, and developing efficient storage and transportation systems must be addressed.

Despite these challenges, the long-term benefits of hydrogen integration are substantial, and a net-zero roadmap indicates electricity costs could fall by a third. Hydrogen can enhance energy security, reduce reliance on imported fossil fuels, and support global climate goals. For Germany, this initiative is a step towards realizing its vision of a sustainable, low-carbon energy system.

Conclusion

Germany’s call for hydrogen-ready power plants is a forward-thinking move that reflects its commitment to sustainability and innovation. By encouraging the development of infrastructure capable of using hydrogen, Germany is taking a significant step towards a cleaner energy future. While challenges remain, the strategic focus on hydrogen underscores Germany’s leadership in the global transition to a low-carbon economy. As the world grapples with the urgent need to address climate change, Germany’s approach serves as a model for integrating emerging technologies into national energy strategies.

 

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TransAlta brings online 119 MW of wind power in US

TransAlta Renewables US wind farms achieved commercial operation, adding 119 MW of wind energy capacity in Pennsylvania and New Hampshire, backed by PPAs with Microsoft, Partners Healthcare, and NHEC, and supported by tax equity financing.

 

Key Points

Two US wind projects totaling 119 MW, now online under PPAs and supported by tax equity financing.

✅ 119 MW online in Pennsylvania and New Hampshire

✅ PPAs with Microsoft, Partners Healthcare, and NHEC

✅ About USD 126 million raised via tax equity

 

TransAlta Renewables Inc says two US wind farms, with a total capacity of 119 MW and operated by its parent TransAlta Corp, became operational in December, amid broader build-outs such as Enel's 450-MW U.S. project coming online and, in Canada, Acciona's 280-MW Alberta wind farm advancing as well.

The 90-MW Big Level wind park in Pennsylvania started commercial operation on December 19. It sells power to technology giant Microsoft Corporation under a 15-year contract, reflecting big-tech procurement alongside Amazon's clean energy projects in multiple markets.

The 29-MW Antrim wind facility in New Hampshire is operational since December 24. It is selling power under 20-year contracts with Boston-based non-profit hospital and physicians network Partners Healthcare and New Hampshire Electric Co-op, mirroring East Coast activity at Amazon Wind Farm US East now fully operational.

The Canadian renewable power producer, which has economic interest in the two wind parks, said that upon their reaching commercial operations, it raised about USD 126 million (EUR 113m) of tax equity to partially fund the projects, as mega-deployments like Invenergy and GE's record North American project and capital plans such as a $200 million Alberta build by a Buffett-linked company underscore financing momentum.

"We continue to pursue additional growth opportunities, including potential drop-down transactions with TransAlta Corp," TransAlta Renewables president John Kousinioris commented.

The comment comes as TransAlta scrapped an Alberta wind project amid Alberta policy shifts.

 

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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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Plan to End E-Vehicle Subsidies Sparks Anger in Germany

Germany EV Subsidy Cut triggers budget-crisis fallout in the automotive industry, after a constitutional court ruling; EV incentives end, threatening electromobility adoption, manufacturer competitiveness, 2030 targets, and demand amid Chinese competition and weak global growth.

 

Key Points

A sudden end to Germany's EV incentives due to a budget shortfall after a court ruling, hurting automakers and adoption.

✅ Ends buyer rebates amid budget crisis ruling

✅ Risks 2030 EV targets and industry competitiveness

✅ Weak demand and China competition intensify

 

The German government has faced a backlash after abruptly ending an electric car subsidy scheme in a blow to the already struggling automotive industry.

The scheme is one of the casualties of a budget crisis caused by a shock constitutional court ruling in November that upended the government's spending plans.

The economy ministry said Saturday that Sunday would be the last day prospective buyers could apply for the scheme, which paid out thousands of euros per customer to partially cover the cost of buying an electric car today.

A spokesman for the ministry admitted it was an "unfortunate situation" for consumers who had been hoping to take advantage of the subsidy, but it had no choice "because there is no longer enough money available."

Analyst Ferdinand Dudenhoeffer from the Center for Automotive Research warned the decision could have dramatic consequences amid a Europe EV slump already pressuring demand.

"The competitiveness of [auto] manufacturers will now be severely damaged," Dudenhoeffer told the Rheinische Post newspaper.

The Handelsblatt business daily had already warned that scrapping the scheme risked jeopardizing Germany's plans to get 15 million electric cars on the road by 2030, even though the EU EV share grew during lockdowns earlier in the pandemic.

"This goal was already considered extremely unrealistic. Now it seems completely illusory," it wrote.

In the UK, analysts warn that electric cars could cost more if a post-Brexit deal is not reached, underscoring wider market uncertainties.

A total of around 10 billion euros ($1.1 billion) has been paid out since 2016 under the scheme for around 2.1 million electric vehicles, according to the economy ministry.

Germany's flagship automotive industry, including Volkswagen, has been struggling with the transition to electromobility due to a weak global economy and low levels of demand.

In addition, it is facing a serious challenge from homegrown rivals in China, one of its most important markets, as France moves to discourage Chinese EVs with new rules.

"The Chinese are massively expanding their car industry because they have customers. Our manufacturers no longer have any," Dudenhoeffer said, as France's incentive rules make the market tougher for Chinese brands.

Germany's highest court decided last month that the government had broken a constitutional debt rule when it transferred 60 billion euros earmarked for pandemic support to a climate fund.

The bombshell ruling blew a huge hole in spending plans and plunged Chancellor Olaf Scholz's three-way coalition into turmoil.

After adopting an emergency budget for 2023, Scholz and his junior coalition partners battled for weeks before finally finding an agreement for 2024.

 

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N.L. premier says Muskrat Falls costs are too great for optimism about benefits

Muskrat Falls financial impact highlights a hydro megaproject's cost overruns, rate mitigation challenges, and inquiry findings in Newfoundland and Labrador, with power exports, Churchill River generation, and subsea cables shaping long-term viability.

 

Key Points

It refers to the project's burden on provincial finances, driven by cost overruns, rate hikes, and debt risks.

✅ Costs rose to $12.7B from $6.2B; inquiry cites suppressed risks.

✅ Rate mitigation needed to offset power bill shocks.

✅ Exports via subsea cables may improve long-term viability.

 

Newfoundland and Labrador's premier says the Muskrat Falls hydro megaproject is currently too much of a massive financial burden for him to be optimistic about its long-term potential.

"I am probably one of the most optimistic people in this room," Liberal Premier Dwight Ball told the inquiry into the project's runaway cost and scheduling issues, echoing challenges at Manitoba Hydro that have raised similar concerns.

"I believe the future is optimistic for Newfoundland Labrador, of course I do. But I'm not going to sit here today and say we have an optimistic future because of the Muskrat Falls project."

Ball, who was re-elected on May 16, has been critical of the project since he was opposition leader around the time it was sanctioned by the former Tory government.

He said Friday that despite his criticism of the Labrador dam, which has seen costs essentially double to more than $12.7 billion, he didn't set out to celebrate a failed project.

He said he still wants to see Muskrat Falls succeed someday through power sales outside the province, but there are immediate challenges -- including mitigating power-rate hikes once the dam starts providing full power and addressing winter reliability risks for households.

"We were told the project would be $6.2 billion, we're at $12.7 (billion). We were never told this project would be nearly 30 per cent of the net debt of this province just six, seven years later," the premier said.

"I wanted this to be successful, and in the long term I still want it to be successful. But we have to deal with the next 10 years."

The nearly complete dam will harness Labrador's lower Churchill River to provide electricity to the province as well as Nova Scotia and potentially beyond through subsea cables, while the legacy of Churchill Falls continues to shape regional power arrangements.

Ball's testimony wraps up a crucial phase of hearings in the extensive public inquiry.

The inquiry has heard from dozens of witnesses, with current and former politicians, bureaucrats, executives and consultants, amid debates over Quebec's electricity ambitions in the region, shedding long-demanded light on what went on behind closed doors that made the project go sideways.

Some witnesses have suggested that estimates were intentionally suppressed, and many high-ranking officials, including former premiers, have denied seeing key information about risk.

On Thursday, Ball testified to his shock when he began to understand the true financial state of the project after he was elected premier in 2015.

On Friday, Ball said he has more faith in future of the offshore oil and gas industry, and emerging options like small nuclear reactors, for example, than a mismanaged project that has put immense pressure on residents already struggling to make ends meet.

After his testimony, Ball said he takes some responsibility for a missed opportunity to mitigate methylmercury risks downstream from the dam through capping the reservoir, in parallel with debates over biomass power in electricity generation, something he had committed to doing before it is fully flooded this summer.

Still to come is a third phase of hearings on future best practices for issues like managing large-scale projects and independent electricity planning, two public feedback sessions and closing submissions from lawyers.

The final report from the inquiry is due before Dec. 31.

 

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