Hydroelectric power a boon for Marana

China 2060 Carbon-Neutral Energy Transition projects tripled electricity, rapid electrification, wind and solar dominance, scalable hydrogen, CCUS, and higher carbon pricing to meet net-zero goals while decarbonizing heavy industry and transport.

Key Points

Shell's outlook for China to reach net zero by 2060 via electrification, renewables, hydrogen, CCUS, and carbon pricing.

✅ Power supply to 60% of energy; generation triples by 2060.

✅ Wind and solar reach 80% of electricity; coal declines sharply.

✅ Hydrogen scales to 17 EJ; CCUS and carbon pricing expand.

China may triple electricity generation to supply 60 percent of the country's total energy under Beijing's carbon-neutral goal by 2060, up from the current 23 per cent, according to Royal Dutch Shell.

Shell is one of the largest global investors in China's energy sector, with business covering gas production, petrochemicals and a retail fuel network. A leading supplier of liquefied natural gas, it has recently expanded into low-carbon business such as hydrogen power and electric vehicle charging.

In a rare assessment of the country's energy sector by an international oil major, Shell said China needed to take quick action this decade to stay on track to reach the carbon-neutrality goal.

China has mapped out plans to reach peak emissions by 2030, and aims to reduce coal power production over the coming years, but has not yet revealed any detailed carbon roadmap for 2060.

This includes investing in a reliable and renewable power system, including compressed air generation, and demonstrating technologies that transform heavy industry using hydrogen, biofuel and carbon capture and utilization.

"With early and systematic action, China can deliver better environmental and social outcomes for its citizens while being a force for good in the global fight against climate change," Mallika Ishwaran, chief economist of Shell International, told a webinar hosted by the company's China business.

Shell expects China's electricity generation to rise three-fold to more than 60 exajoules (EJ) in 2060 from 20 EJ in 2020, even amid power supply challenges reported recently.

Solar and wind power are expected to surpass coal as the largest sources of electricity by 2034 in China, reflecting projections that renewables will eclipse coal globally by mid-decade, versus the current 10 percent, rising to 80 percent by 2060, Shell said.

Hydrogen is expected to scale up to 17 EJ, or equivalent to 580 million tonnes of coal by 2060, up from almost negligible currently, adding over 85 percent of the hydrogen will be produced through electrolysis, supported by PEM hydrogen R&D across the sector, powered by renewable and nuclear electricity, Shell said.

Hydrogen will meet 16 percent of total energy use in 2060 with heavy industry and long-distance transport as top hydrogen users, the firm added.

The firm also expects China's carbon price to rise to 1,300 yuan (CDN$256.36) per tonne in 2060 from 300 yuan in 2030.

Nuclear, on a steady development track, and biomass will have niche but important roles for power generation in the years to come, Shell said.

Electricity generated from biomass, combined with carbon, capture, utilization and storage (CCUS), provide a source of negative emissions for the rest of the energy system from 2053, it added.

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British Columbia electricity rate increase will raise BC Hydro bills 3.75% over 2025-2026 to fund infrastructure, Site C, and clean energy, balancing affordability, reliability, and energy security while keeping prices below the North American average.

Key Points

BC will raise BC Hydro rates 3.75% in 2025-2026, about $3.75/month, to fund grid upgrades, Site C, and clean energy.

✅ 3.75% over 2025-2026; about $3.75/month on $100 average bill

✅ Funds Site C, grid maintenance, and clean energy capacity

✅ Keeps BC Hydro rates below North American averages

British Columbia's electricity rates will experience a 3.75% increase over the next two years, following an earlier 3% rate increase approval that set the stage, as confirmed by the provincial government on March 17, 2025. The announcement was made by Minister of Energy and Climate Solutions, Adrian Dix, who emphasized the decision's necessity for maintaining BC Hydro’s infrastructure while balancing affordability for residents.

For most households, the increase will amount to an additional $3.75 per month, based on an average BC Hydro bill of $100, though some coverage framed an earlier phase as a BC Hydro $2/month proposal that later evolved. While this may seem modest, the increase reflects a broader strategy to stabilize the utility's rates amidst economic challenges and ensure long-term energy security for the province.

Reasons Behind the Rate Hike

The rate increase comes during a period of rising costs in both global markets and local economies. According to Dix, the economic uncertainty stemming from trade dynamics and inflation has forced the government to act. Despite these pressures, and after a prior B.C. rate freeze to moderate impacts, the increase remains below cumulative inflation over the last several years, a move designed to shield consumers from the full force of these economic changes.

Dix also noted that, when adjusted for inflation, electricity rates in British Columbia in 2025 are effectively at the same price they were four decades ago. This stability, he argued, underscores the provincial government’s commitment to keeping rates as low as possible for residents, even as operating costs rise.

“We must take urgent action to protect British Columbians from the uncertainty posed by rising costs while building a strong, resilient electricity system for the long-term benefit of B.C.’s energy independence,” Dix said. He also highlighted the government's approach to minimizing the financial burden on consumers by keeping electricity costs well below the North American average.

Infrastructure and Maintenance Costs

The primary justification for the rate increase is to allow BC Hydro to continue its critical infrastructure development, including the Site C hydroelectric project, which is expected to become operational in the coming years. The increased costs of maintaining and upgrading the province's electricity grid also contribute to the need for higher rates.

The Site C project, a massive hydroelectric dam under construction on the Peace River, is expected to provide a substantial increase in clean, renewable energy capacity. However, such large-scale projects require significant investment and maintenance, both of which have contributed to the increased operating costs for BC Hydro.

A Strategic Move for Rate Stability

The provincial government has been clear that the rate increase will allow for a continuation of infrastructure development while keeping the rates manageable for consumers. The 3.75% increase will be spread across two years, with the first hike scheduled for April 1, 2025, reflecting the typical April rate changes BC Hydro implements, and the second for April 1, 2026.

Dix confirmed that the rate hike would still keep electricity costs among the lowest in North America, noting that British Columbians pay about half of what residents in Alberta pay for electricity. This is part of a broader effort by the provincial government to provide stable energy pricing while bolstering the transition to clean energy solutions, such as the Site C project and other renewable energy initiatives.

Addressing Public Concerns

Although the government has framed the increase as a necessary measure to ensure the province's long-term energy independence and reliability, the rate hikes are likely to face scrutiny from residents, particularly those already struggling with the rising cost of living, even as provinces like Ontario face their own Ontario hydro rate increase pressures this fall.

Public reactions to utility rate increases are often contentious, as residents feel the pressure of rising prices across various sectors, from housing to healthcare. However, the government has promised that the new rates will remain manageable, especially considering the relatively low rate increases compared to inflation and other regions where Manitoba Hydro scaled back a planned increase to temper impacts.

Furthermore, the increase comes as part of a broader strategy that aims to keep the overall impact on consumers as low as possible. Minister Dix emphasized that these rate increases were intended to ensure the continued reliability of BC Hydro’s services, without overwhelming ratepayers.

Long-Term Goals

Looking ahead, the province's strategy centers on not only maintaining affordable electricity rates but also reinforcing the importance of renewable energy, while some jurisdictions consider a 2.5% annual increase plan over multiple years to stabilize their grids. As climate change becomes an increasingly pressing issue, BC’s investments in clean energy projects like Site C aim to provide sustainable power for generations to come.

The government’s long-term vision involves building a resilient, energy-independent province that can weather future economic and environmental challenges. In this context, the rate increases are framed not just as a response to immediate inflationary pressures but as a necessary step in preparing BC’s energy infrastructure for the future.

The 3.75% rate increase set for 2025 and 2026 represents a balancing act between managing the financial health of BC Hydro and protecting consumers from higher costs. While the increase will have a modest effect on household bills, the long-term goal is to build a more robust and sustainable electricity system for British Columbia’s future. Through investments in clean energy and strategic infrastructure development, the province aims to keep electricity rates competitive while positioning itself as a leader in energy independence and climate action.

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Pumped Storage Hydroelectricity balances renewable energy, stabilizes the grid, and provides large-scale energy storage using reservoirs and reversible turbines, delivering flexible peak power, frequency control, and rapid response to variable wind and solar generation.

Key Points

A reversible hydro system that stores energy by pumping water uphill, then generates flexible peak power.

✅ Balances variable wind and solar with rapid ramping

✅ Stores off-peak electricity in upper reservoirs

✅ Enhances grid stability, frequency control, and reserves

The expense of hydroelectricity is moderately low, making it a serious wellspring of sustainable power. The hydro station burns-through no water, dissimilar to coal or gas plants. The commonplace expense of power from a hydro station bigger than 10 megawatts is 3 to 5 US pennies for every kilowatt hour, and Niagara Falls powerhouse upgrade projects show how modernization can further improve efficiency and reliability. With a dam and supply it is likewise an adaptable wellspring of power, since the sum delivered by the station can be shifted up or down quickly (as meager as a couple of moments) to adjust to changing energy requests.

When a hydroelectric complex is developed, the task creates no immediate waste, and it for the most part has an extensively lower yield level of ozone harming substances than photovoltaic force plants and positively petroleum product fueled energy plants, with calls to invest in hydropower highlighting these benefits. In open-circle frameworks, unadulterated pumped storage plants store water in an upper repository with no normal inflows, while pump back plants use a blend of pumped storage and regular hydroelectric plants with an upper supply that is renewed to a limited extent by common inflows from a stream or waterway.

Plants that don't utilize pumped capacity are alluded to as ordinary hydroelectric plants, and initiatives focused on repowering existing dams continue to expand clean generation; regular hydroelectric plants that have critical capacity limit might have the option to assume a comparable function in the electrical lattice as pumped capacity by conceding yield until required.

The main use for pumped capacity has customarily been to adjust baseload powerplants, however may likewise be utilized to decrease the fluctuating yield of discontinuous fuel sources, while emerging gravity energy storage concepts broaden long-duration options. Pumped capacity gives a heap now and again of high power yield and low power interest, empowering extra framework top limit.

In specific wards, power costs might be near zero or once in a while negative on events that there is more electrical age accessible than there is load accessible to retain it; despite the fact that at present this is infrequently because of wind or sunlight based force alone, expanded breeze and sun oriented age will improve the probability of such events.

All things considered, pumped capacity will turn out to be particularly significant as an equilibrium for exceptionally huge scope photovoltaic age. Increased long-distance bandwidth, including hydropower imports from Canada, joined with huge measures of energy stockpiling will be a critical piece of directing any enormous scope sending of irregular inexhaustible force sources. The high non-firm inexhaustible power entrance in certain districts supplies 40% of yearly yield, however 60% might be reached before extra capaciy is fundamental.

Pumped capacity plants can work with seawater, despite the fact that there are extra difficulties contrasted with utilizing new water. Initiated in 1966, the 240 MW Rance flowing force station in France can incompletely function as a pumped storage station. At the point when elevated tides happen at off-top hours, the turbines can be utilized to pump more seawater into the repository than the elevated tide would have normally gotten. It is the main enormous scope power plant of its sort.

Alongside energy mechanism, pumped capacity frameworks help control electrical organization recurrence and give save age. Warm plants are substantially less ready to react to abrupt changes in electrical interest, and can see higher thermal PLF during periods of reduced hydro generation, conceivably causing recurrence and voltage precariousness.

Pumped storage plants, as other hydroelectric plants, including new BC generating stations, can react to stack changes in practically no time. Pumped capacity hydroelectricity permits energy from discontinuous sources, (for example, sunlight based, wind) and different renewables, or abundance power from consistent base-load sources, (for example, coal or atomic) to be put something aside for times of more popularity.

The repositories utilized with siphoned capacity are tiny when contrasted with ordinary hydroelectric dams of comparable force limit, and creating periods are regularly not exactly a large portion of a day. This technique produces power to gracefully high top requests by moving water between repositories at various heights.

Now and again of low electrical interest, the abundance age limit is utilized to pump water into the higher store. At the point when the interest gets more noteworthy, water is delivered once more into the lower repository through a turbine. Pumped capacity plans at present give the most monetarily significant methods for enormous scope matrix energy stockpiling and improve the every day limit factor of the age framework. Pumped capacity isn't a fuel source, and shows up as a negative number in postings.

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India Solar Slowdown and Coal Surge highlights policy uncertainty, grid stability concerns, financing gaps, and land acquisition issues affecting renewable energy, emissions targets, energy security, storage deployment, and tendering delays across the solar value chain.

Key Points

Analysis of slowed solar growth and rising coal in India, examining policy, grid, finance, and emissions tradeoffs.

✅ Policy uncertainty and tender delays stall solar pipelines

✅ Grid bottlenecks, storage gaps, and curtailment risks persist

✅ Financing strains and DISCOM payment delays dampen investment

India, a global leader in renewable energy adoption where renewables surpassed coal in capacity recently, faces a pivotal moment as the growth of solar power output decelerates while coal generation sees an unexpected surge. This article examines the factors contributing to this shift, its implications for India's energy transition, and the challenges and opportunities it presents.

India's Renewable Energy Ambitions

India has set ambitious targets to expand its renewable energy capacity, including a goal to achieve 175 gigawatts (GW) of renewable energy by 2022, with a significant portion from solar power. Solar energy has been a focal point of India's renewable energy strategy, as documented in on-grid solar development studies, driven by falling costs, technological advancements, and environmental imperatives to reduce greenhouse gas emissions.

Factors Contributing to Slowdown in Solar Power Growth

Despite initial momentum, India's solar power growth has encountered several challenges that have contributed to a slowdown. These include policy uncertainties, regulatory hurdles, land acquisition issues, and financial constraints affecting project development and implementation, even as China's solar PV growth surged in recent years. Delays in tendering processes, grid connectivity issues, and payment delays from utilities have also hindered the expansion of solar capacity.

Surge in Coal Generation

Concurrently, India has witnessed an unexpected increase in coal generation in recent years. Coal continues to dominate India's energy mix, accounting for a significant portion of electricity generation due to its reliability, affordability, and existing infrastructure, even as wind and solar surpassed coal in the U.S. in recent periods. The surge in coal generation reflects the challenges in scaling up renewable energy quickly enough to meet growing energy demand and address grid stability concerns.

Implications for India's Energy Transition

The slowdown in solar power growth and the rise in coal generation pose significant implications for India's energy transition and climate goals. While renewable energy remains central to India's long-term energy strategy, and as global renewables top 30% of electricity generation worldwide, the persistence of coal-fired power plants complicates efforts to reduce carbon emissions and mitigate climate change impacts. Balancing economic development, energy security, and environmental sustainability remains a complex challenge for policymakers.

Challenges and Opportunities

Addressing the challenges facing India's solar sector requires concerted efforts to streamline regulatory processes, improve grid infrastructure, and enhance financial mechanisms to attract investment. Encouraging greater private sector participation, promoting technology innovation, and expanding renewable energy storage capacity are essential to overcoming barriers and accelerating solar power deployment, as wind and solar have doubled their global share in recent years, demonstrating the pace possible.

Policy and Regulatory Framework

India's government plays a crucial role in fostering a conducive policy and regulatory framework to support renewable energy growth and phase out coal dependence, particularly as renewable power is set to shatter records worldwide. This includes implementing renewable energy targets, providing incentives for solar and other clean energy technologies, and addressing systemic barriers that hinder renewable energy adoption.

Path Forward

To accelerate India's energy transition and achieve its renewable energy targets, stakeholders must prioritize integrated energy planning, grid modernization, and sustainable development practices. Investing in renewable energy infrastructure, promoting energy efficiency measures, and fostering international collaboration on technology transfer and capacity building are key to unlocking India's renewable energy potential.

Conclusion

India stands at a crossroads in its energy transition journey, balancing the need to expand renewable energy capacity while managing the challenges associated with coal dependence. By addressing regulatory barriers, enhancing grid reliability, and promoting sustainable energy practices, India can navigate towards a more diversified and resilient energy future. Embracing innovation, strengthening policy frameworks, and fostering public-private partnerships will be essential in realizing India's vision of a cleaner, more sustainable energy landscape for generations to come.

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Taiwan Power Blackout disrupts Taipei and commercial hubs after a Taoyuan natural gas plant error, triggering nationwide outage, grid failure, elevator rescues, power rationing, and the economic minister's resignation, as CPC Corporation restores supply.

Key Points

A nationwide Taiwan outage from human error at a Taoyuan gas plant, triggering rationing and a minister's resignation.

✅ Human error disrupted natural gas supply at Taoyuan plant

✅ 6.68 million users affected; grid failure across cities

✅ Minister Lee resigned; President Tsai ordered a review

Taiwan's economic minister resigned after power was knocked out in many parts of Taiwan, with regional parallels such as China power cuts highlighting grid vulnerabilities, including capital Taipei's business and high-end shopping district, due to an apparent "human error" at a key power plant.

Economic Affairs minister Lee Chih-kung tendered his resignation verbally to Premier Lin Chuan, United Daily News reported, citing a Cabinet spokesman. Lin accepted the resignation, the spokesman said according to the daily.

As many as 6.68 million households and commercial units saw their power supply cut or disrupted on Tuesday after "human error" disrupted natural gas supply at a power plant in northern Taiwan's Taoyuan, the semi-official Central News Agency reported, citing the government-controlled oil company CPC Corporation as saying.

The company added that power at the plant, Taiwan's biggest natural gas power plant, resumed two minutes later.

In New Taipei City, there were at least 27,000 reported cases of people being stuck in lifts. Photos in social media also showed huge crowds stranded in lift lobby in Taipei's iconic 101-storey Taipei 101 building.

Power rationing was implemented beginning 6pm, and, as seen in the National Grid short supply warning in other markets, such steps aim to stabilize supply, Central News Agency said. Power supply was gradually being restored beginning at about 9:40pm. news reports said.

President Tsai Ing-wen apologised for the blackout, noting parallels with Japan's near-blackouts that underscored grid resilience, and said that she has ordered all relevant departments to produce clear report in the shortest time possible.

"Electricity is not just a problem about people's livelihoods but also a national security issue. A comprehensive review must be carried out to find out how the electric power system can be so easily paralysed by human error," said Ms Tsai in a Facebook post.

Taiwan has been at risk of a power shortage after a recent typhoon knocked down a power transmission tower in Hualien county along the eastern coast of Taiwan, rather than a demand-driven slowdown like the China power demand drop during pandemic factory shutdowns. This reduced the electricity supply by 1.3million kilowatts, or about 4 per cent of the operating reserve.

That was followed by the breakdown of a power generator at Taiwan's largest power plant, which further reduced the operating reserve by 1.5 per cent.

The situation is worsened by the ongoing heatwave that has hit Taiwan, with temperatures soaring to 38 degrees Celsius over the past week.

As a result, the government had imposed the rationing of electricity, and, highlighting how regional strains such as China's power woes can ripple into global markets, switched off all air-conditioning in many of its Taipei offices, a move that drew some public backlash.

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Hydro-Québec Carillon Refurbishment delivers a $750M hydropower modernization, replacing six turbines and upgrading civil works, water passageways, and grid equipment to extend run-of-river, renewable energy output for peak demand near Montréal.

Key Points

A $750M project replacing six units and upgrading civil, water and electrical systems to supply power for 50 years.

✅ Replaces six generating units with Andritz turbines.

✅ Upgrades civil works, water passageways, and electrical gear.

✅ Extends run-of-river output for 50 years; boosts peak supply.

Hydro-Québec will invest $750 million to refurbish its Carillon generating station with a major powerhouse upgrade that will mainly replace six generating units. The investment also covers the cost of civil engineering work, including making adjustments to water passageways, upgrading electrical equipment and replacing the station roof. Work will start in 2021, aligning with Hydro-Québec's capacity expansion plans for 2021, and continue until 2027.

Carillon generating station is a run-of-river power plant consisting of 14 generating units with a total installed capacity of 753 MW. Built in the early 1960s, it is a key part of Hydro-Québec's hydroelectric generating fleet, which includes the La Romaine complex as well. The station is close to the greater Montréal area and feeds power into the grid to support industrial demand growth during peak consumption periods.

The selected supplier, turbine manufacturer Andritz, has been asked to maximize the project's economic spinoffs in Québec, as Canada continues investing in new turbines across the country to modernize assets. Once the work is completed, the new generating units will be able to provide clean, renewable energy, supporting Hydro-Québec's strategy to reduce fossil fuel reliance for the next 50 years.

"Carillon generating station is a symbol of our hydroelectric development and plays a strategic role in our production fleet. However, most of the generating units' main components date back to the station's original construction from 1959 to 1962. Hydropower generating stations have long service lives - with this refurbishment, Carillon will be producing clean renewable energy for decades to come." said David Murray, Chief Innovation Officer and President, Hydro-Québec Production.

"In light of today's economic situation, this is an important announcement that clearly reaffirms Hydro-Québec's role in relaunching Québec's economy and strengthening interprovincial electricity partnerships that open new markets. Over 600,000 hours of work will be required for everything from the engineering work to component assembly, creating many new high-quality skilled jobs for Québec industries."

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