Power sector pushes India CO2 emissions

By Reuters


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India's greenhouse gas emissions grew 58 percent between 1994 and 2007, official figures released showed, helped up by a largely coal-reliant power sector that nearly doubled its share in emissions.

Total emissions rose to 1.9 billion tonnes in 2007 versus 1.2 billion in 1994, with industry and transport sectors also upping their share in Asia's third largest economy and confirming India's ranking among the world's top five carbon polluters.

By way of comparison, between 1994 and 2007, India added more than the entire emissions produced annually by Australia. India is still low on per-capita emissions, about a tenth that of the United States.

The power sector accounted for 719.30 million tonnes of emissions against 355.03 million tonnes in 1994, while the transport sector's share jumped to 142.04 million tonnes from 80.28 million tonnes during the same period.

Industrial emissions rose a little more than 30 per cent during the same period.

With agriculture's share in the Indian economy dropping over the past years, emissions from the sector dipped marginally during 1994-2007.

The report highlights India's growing role as a key player in the UN-led climate negotiations on a replacement for the Kyoto Protocol and the need to include big developing nations in global efforts to fight climate change.

Figures in the government report, released by Environment Minister Jairam Ramesh at a conference in New Delhi, show India closing in on Russia, now the world's third largest greenhouse gas emitter, at nearly 2.2 billion tonnes in 2007.

China is the world's top emitter of greenhouse gases blamed for heating up the planet. The United States is second.

Russia's emissions have been growing at a slower pace than those of India, whose energy-hungry economy has been expanding at about 8 percent a year as it tries to lift millions out of poverty.

This has propelled investment in coal-fired power stations, steel mills, cement plants and mining, as well as renewable energy.

"Interestingly, the emissions of the United States and China are almost four times that of India in 2007," Ramesh told the conference.

"It is also noteworthy that the energy intensity of India's GDP declined by more than 30 percent during the period 1994-2007 due to the efforts and policies that we are proactively putting into place. This is a trend we intend to continue," he said.

Energy intensity refers to the amount of energy used per unit of gross domestic product.

India has also set a carbon intensity reduction target of 20 to 25 percent by 2020 from 2005 levels.

Data from 1994 was the last official report to the United Nations on India's emissions because, as a developing country, India is not obliged to make annual emissions declarations to the world body, unlike rich nations.

The latest UN emissions data for industrialized nations date to 2007.

Although India has announced a new climate plan which identifies renewable energy, such as solar power, as a key element, coal remains the backbone of energy supply in a country where almost half the 1.1 billion population has no access to electricity.

The country has 10 percent of the world's coal reserves, and it plans to add 78.7 gigawatts of power generation during the five years ending March 2012, most of it from coal, which now accounts for about 60 percent of the nation's energy mix.

Developing nations now emit more than half of mankind's greenhouse gas pollution and that figure is expected to accelerate in the short term even as poorer nations embrace renewable energy and greater energy efficiency.

A government-backed report last year projected India's greenhouse gas emissions could jump to between 4 billion tonnes and 7.3 billion tonnes in 2031, but per-capita emissions would still be half the global average.

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Canadian Electricity Grids Increasingly Exposed to Harsh Weather

North American Grid Reliability faces extreme weather, climate change, demand spikes, and renewable variability; utilities, AESO, and NERC stress resilience, dispatchable capacity, interconnections, and grid alerts to prevent blackouts during heatwaves and cold snaps.

 

Key Points

North American grid reliability is the ability to meet demand during extreme weather while maintaining stability.

✅ Extreme heat and cold drive record demand and resource strain.

✅ Balance dispatchable and intermittent generation for resilience.

✅ Expand interconnections, capacity, and demand response to avert outages.

 

The recent alerts in Alberta's electricity grid during extreme cold have highlighted a broader North American issue, where power systems are more susceptible to being overwhelmed by extreme weather impacts on reliability.

Electricity Canada's chief executive emphasized that no part of the grid is safe from the escalating intensity and frequency of weather extremes linked to climate change across the sector.

“In recent years, during these extreme weather events, we’ve observed record highs in electricity demand,” he stated.

“It’s a nationwide phenomenon. For instance, last summer in Ontario and last winter in Quebec, we experienced unprecedented demand levels. This pattern of extremes is becoming more pronounced across the country.”

The U.S. has also experienced strain on its electricity grids due to extreme weather, with more blackouts than peers documented in studies. Texas faced power outages in 2021 due to winter storms, and California has had to issue several emergency grid alerts during heat waves.

In Canada, Albertans received a government emergency alert two weeks ago, urging an immediate reduction in electricity use to prevent potential rotating blackouts as temperatures neared -40°C. No blackouts occurred, with a notable decrease in electricity use following the alert, according to the Alberta Electric System Operator (AESO).

AESO's data indicates an increase in grid alerts in Alberta for both heatwaves and cold spells, reflecting dangerous vulnerabilities noted nationwide. The period between 2017 and 2020 saw only four alerts, in contrast to 17 since 2021.

Alberta's electricity grid reliability has sparked political debate, including proposals for a western Canadian grid to improve reliability, particularly with the transition from coal-fired plants to increased reliance on intermittent wind and solar power. Despite this debate, the AESO noted that the crisis eased when wind and solar generation resumed, despite challenges with two idled gas plants.

Bradley pointed out that Alberta's grid issues are not isolated. Every Canadian region is experiencing growing electricity demand, partly due to the surge in electric vehicles and clean energy technologies. No province has a complete solution yet.

“Ontario has had to request reduced consumption during heatwaves,” he noted. “Similar concerns about energy mix are present in British Columbia or Manitoba, especially now with drought affecting their hydro-dependent systems.”

The North American Electric Reliability Corporation (NERC) released a report in November warning of elevated risks across North America this winter for insufficient energy supplies, particularly under extreme conditions like prolonged cold snaps.

While the U.S. is generally more susceptible to winter grid disruptions, and summer blackout warnings remain a concern, the report also highlights risks in parts of Canada. Saskatchewan faces a “high” risk due to increased demand, power plant retirements, and maintenance, whereas Quebec and the Maritimes are at “elevated risk.”

Mark Olson, NERC’s manager of reliability assessments, mentioned that Alberta wasn't initially considered at risk, illustrating the challenges in predicting electricity demand amid intensifying extreme weather.

Rob Thornton, president and CEO of the International District Energy Association, acknowledged public concerns about grid alerts but reassured that the risk of a catastrophic grid failure remains very low.

“The North American grid is exceptionally reliable. It’s a remarkably efficient system,” he said.

However, Thornton emphasized the importance of policies for a resilient and reliable electricity system through 2050 and beyond. This involves balancing dispatchable and intermittent electricity sources, investing in extra capacity, enhancing macrogrids and inter-jurisdictional connections, and more.

“These grid alerts raise awareness, if not anxiety, about our energy future,” Thornton concluded.

 

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Construction starts on disputed $1B electricity corridor

New England Clean Energy Connect advances despite court delays, installing steel poles on a Maine corridor for Canadian hydropower, while legal challenges seek environmental review; permits, jobs, and grid upgrades drive the renewable transmission project.

 

Key Points

An HV line in Maine delivering 1,200 MW of Canadian hydropower to New England to cut emissions and stabilize costs.

✅ Appeals court pauses 53-mile new section; upgrades continue

✅ 1,200 MW hydropower aims to cut emissions, stabilize rates

✅ Permits issued; environmental review litigation ongoing

 

Construction on part of a $1 billion electricity transmission corridor through sparsely populated woods in western Maine is on hold because of legal action, echoing Clean Line's Iowa withdrawal amid court uncertainty, but that doesn't mean all building has been halted.

Workers installed the first of 829 steel poles Tuesday on a widened portion of the existing corridor that is part of the project near The Forks, as the groundwork is laid for the 145-mile ( 230-kilometre ) New England Clean Energy Connect, a project central to Maine's debate over the 145-mile line moving forward.

The work is getting started even though the 1st U.S. Circuit Court of Appeals delayed construction of a new 53-mile ( 85-kilometre ) section.

Three conservation groups are seeking an injunction to delay the project while they sue to force the U.S. Army Corps of Engineers to conduct a more rigorous environmental review.

In western Maine, workers already have staged heavy equipment and timber “mats” that will be used to prevent the equipment from damaging the ground. About 275 Maine workers already have been hired, and more would be hired if not for the litigation, officials said.

“This project has always promised to provide an economic boost to Maine’s economy, and we are already seeing those benefits take shape," Thorn Dickinson, CEO of the New England Clean Energy Connect, said Tuesday.

The electricity transmission line would provide a conduit for up to 1,200 megawatts of Canadian hydropower, reducing greenhouse emissions and stabilizing energy costs in New England as states pursue Connecticut's market overhaul to improve market design, supporters say.

The project, which would be fully funded by Massachusetts ratepayers to meet the state's clean energy goals after New Hampshire rejected a Quebec-Massachusetts proposal elsewhere, calls for construction of a high-voltage power line from Mount Beattie Township on the Canadian border to the regional power grid in Lewiston, Maine.

Critics have been trying to stop the project, reflecting clashes over New Hampshire hydropower in the region, saying it would destroy wilderness in western Maine. They also say that the environmental benefits of the project have been overstated.

In addition to the lawsuit, opponents have submitted petitions seeking to have a statewide vote, even as a Maine court ruling on Hydro-Quebec exports has reshaped the legal landscape.

Sandi Howard, a leading opponent of the project, said the decision by the company to proceed showed “disdain for everyday Mainers” by ignoring permit appeals and ongoing litigation.

“For years, CMP has pushed the false narrative that their unpopular and destructive project is a ‘done deal’ to bully Mainers into submission on this for-profit project. But to be clear, we won’t stop until Maine voters (their customers), have the chance to vote,” said Howard, who led the referendum petition drive for the No CMP Corridor PAC.

The project has received permits from the Army Corps, Maine Department of Environmental Protection, Maine Land Use Planning Commission and Maine Public Utilities Commission.

The final approval came in the form of a presidential permit issued last month from the U.S. Department of Energy, providing green light for the interconnect at the Canadian border, even as customer backlash to utility acquisitions elsewhere underscores public scrutiny.

 

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New Mexico Governor to Sign 100% Clean Electricity Bill ‘As Quickly As Possible’

New Mexico Energy Transition Act advances zero-carbon electricity, mandating public utilities deliver carbon-free electricity by 2045, with renewable targets of 50 percent by 2030 and 80 percent by 2040 to accelerate grid decarbonization.

 

Key Points

A state law requiring utilities to deliver carbon-free electricity by 2045, with 2030 and 2040 renewable targets.

✅ 100 percent carbon-free power from utilities by 2045

✅ Interim renewable targets: 50 percent by 2030, 80 percent by 2040

✅ Aligns with clean energy commitments in HI, CA, and DC

 

The New Mexico House of Representatives passed the Energy Transition Act Tuesday afternoon, sending the carbon-free electricity bill, a move aligned with proposals for a Clean Electricity Standard at the federal level, to Gov. Michelle Lujan Grisham.

Her opinions on it are known: she campaigned on raising the share of renewable energy, a priority echoed in many state renewable ambitions nationwide, and endorsed the ETA in a recent column.

"The governor will sign the bill as quickly as possible — we're hoping it is enrolled and engrossed and sent to her desk by Friday," spokesperson Tripp Stelnicki said in an email Tuesday afternoon.

Once signed, the legislation will commit the state to achieving zero-carbon electricity from public utilities by 2045. The bill also imposes interim renewable energy targets of 50 percent by 2030 and 80 percent by 2040, similar to Minnesota's 2040 carbon-free bill in its timeline.

The Senate passed the bill last week, 32-9. The House passed it 43-22.

The legislation would enter New Mexico into the company of Hawaii, California, where climate risks to grid reliability are shaping policy, and Washington, D.C., which have committed to eliminating carbon emissions from their grids. A dozen other states have proposed similar goals. Meanwhile, the Green New Deal resolution has prompted Congress to discuss the bigger task of decarbonizing the nation overall.

Though grid decarbonization has surged in the news cycle in recent months, even as some states consider moves in the opposite direction, such as a Wyoming bill restricting clean energy that would limit utility choices, New Mexico's bill arose from a years-long effort to rally stakeholders within the state's close-knit political community.

 

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Is nuclear power really in decline?

Nuclear Energy Growth accelerates as nations pursue decarbonization, complement renewables, displace coal, and ensure grid reliability with firm, low-carbon baseload, benefiting from standardized builds, lower cost of capital, and learning-curve cost reductions.

 

Key Points

Expansion of nuclear capacity to cut CO2, complement renewables, replace coal, and stabilize grids at low-carbon cost.

✅ Complements renewables; displaces coal for faster decarbonization

✅ Cuts system costs via standardization and lower cost of capital

✅ Provides firm, low-carbon baseload and grid reliability

 

By Kirill Komarov, Chairman, World Nuclear Association.

As Europe and the wider world begins to wake up to the need to cut emissions, Dr Kirill Komarov argues that tackling climate change will see the use of nuclear energy grow in the coming years, not as a competitor to renewables but as a competitor to coal.

The nuclear industry keeps making headlines and spurring debates on energy policy, including the green industrial revolution agenda in several countries. With each new build project, the detractors of nuclear power crowd the bandwagon to portray renewables as an easy and cheap alternative to ‘increasingly costly’ nuclear: if solar and wind are virtually free why bother splitting atoms?

Yet, paradoxically as it may seem, if we are serious about policy response to climate change, nuclear energy is seeing an atomic energy resurgence in the coming decade or two.

Growth has already started to pick up with about 3.1 GW new capacity added in the first half of 2018 in Russia and China while, at the very least, 4GW more to be completed by the end of the year – more than doubling the capacity additions in 2017.

In 2019 new connections to the grid would exceed 10GW by a significant margin.

If nuclear is in decline, why then do China, India, Russia and other countries keep building nuclear power plants?

To begin with, the issue of cost, argued by those opposed to nuclear, is in fact largely a bogus one, which does not make a fully rounded like for like comparison.

It is true that the latest generation reactors, especially those under construction in the US and Western Europe, have encountered significant construction delays and cost overruns.

But the main, and often the only, reason for that is the ‘first-of-a-kind’ nature of those projects.

If you build something for the first time, be it nuclear, wind or solar, it is expensive. Experience shows that with series build, standardised construction economies of scale and the learning curve from multiple projects, costs come down by around one-third; and this is exactly what is already happening in some parts of the world.

Furthermore, those first-of-a-kind projects were forced to be financed 100% privately and investors had to bear all political risks. It sent the cost of capital soaring, increasing at one stroke the final electricity price by about one third.

While, according to the International Energy Agency, at 3% cost of capital rate, nuclear is the cheapest source of energy: on average 1% increase adds about US$6-7 per MWh to the final price.

When it comes to solar and wind, the truth, inconvenient for those cherishing the fantasy of a world relying 100% on renewables, is that the ‘plummeting prices’ (which, by the way, haven’t changed much over the last three years, reaching a plateau) do not factor in so-called system and balancing costs associated with the need to smooth the intermittency of renewables.

Put simply, the fact the sun doesn’t shine at night and wind doesn’t blow all the time means wind and solar generation needs to be backed up.

According to a study by the Potsdam Institute for Climate Impact Research, integration of intermittent renewables into the grid is estimated in some cases to be as expensive as power generation itself.

Delivering the highest possible renewable content means customers’ bills will have to cover: renewable generation costs, energy storage solutions, major grid updates and interconnections investment, as well as gas or coal peaking power plants or ‘peakers’, which work only from time to time when needed to back up wind and solar.

The expected cost for kWh for peakers, according to investment bank Lazard is about twice that of conventional power plants due to much lower capacity factors.

Despite exceptionally low fossil fuel prices, peaking natural gas generation had an eye-watering cost of $156-210 per MWh in 2017 while electricity storage, replacing ‘peakers’, would imply an extra cost of $186-413 per MWh.

Burning fossil fuels is cheaper but comes with a great deal of environmental concern and extensive use of coal would make net-zero emissions targets all but unattainable.

So, contrary to some claims, nuclear does not compete with renewables. Moreover, a recent study by the MIT Energy Initiative showed, most convincingly, that renewables and load following advanced nuclear are complementary.

Nuclear competes with coal. Phasing out coal is crucial to fighting climate change. Putting off decisions to build new nuclear capacities while increasing the share of intermittent renewables makes coal indispensable and extends its life.

Scientists at the Brattle group, a consultancy, argue that “since CO2 emissions persist for many years in the atmosphere, near-term emission reductions are more helpful for climate protection than later ones”.

The longer we hesitate with new nuclear build the more difficult it becomes to save the Earth.

Nuclear power accounta for about one-tenth of global electricity production, but as much as one-third of generation from low-carbon sources. 1GWe of installed nuclear capacity prevents emissions of 4-7 million metric tons of CO2 emissions per year, depending on the region.

The International Energy Agency (IEA) estimates that in order to limit the average global temperature increase to 2°C and still meet global power demand, we need to connect to the grid at least 20GW of new nuclear energy each year.

The World Nuclear Association (WNA) sets the target even higher with the total of 1,000 GWe by 2050, or about 10 GWe per year before 2020; 25 GWe per year from 2021 to 2025; and on average 33 GWe from 2026 to 2050.

Regulatory and political challenges in the West have made life for nuclear businesses in the US and in Europe's nuclear sector very difficult, driving many of them to the edge of insolvency; but in the rest of the world nuclear energy is thriving.

Nuclear vendors and utilities post healthy profits and invest heavily in next-gen nuclear innovation and expansion. The BRICS countries are leading the way, taking over the initiative in the global climate agenda. From their perspective, it’s the opposite of decline.

Dr Kirill Komarov is first deputy CEO of Russian state nuclear energy operator Rosatom and chairman of the World Nuclear Association.

 

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New Electricity Auctions Will Drive Down Costs for Ontario's Consumers

IESO Capacity Auctions will competitively procure resources for Ontario electricity needs, boosting reliability and resource adequacy through market-based bidding, enabling demand response, energy storage, and flexible supply to meet changing load and regional grid conditions.

 

Key Points

A competitive, technology-neutral auction buys capacity at lowest cost to keep Ontario's grid reliable and flexible.

✅ Market-based procurement reduces system costs.

✅ Enables demand response, storage, and hybrid resources.

✅ Increases flexibility and regional reliability in Ontario.

 

The Independent Electricity System Operator (IESO) is introducing changes to Ontario's electricity system that will help save Ontarians about $3.4 billion over a 10-year period. The changes include holding annual capacity auctions to acquire electricity resources at lowest cost that can be called upon when and where they are needed to meet Ontario electricity needs. 

Today's announcement marks the release of a high level design for future auctions, with changes for electricity consumers expected as the first is set to be held in late 2022.

"These auctions will specify how much electricity we need, and introduce a competitive process to determine who can meet that need. It's a competition among all eligible resources, and it's the Ontario consumer, including industrial electricity ratepayers, who benefits through lower costs and a more flexible system better able to respond to changing demand and supply conditions," says IESO President and CEO Peter Gregg.

In the past decade, electricity supply was typically acquired through very prescriptive means with defined targets for specific types of resources such as wind and solar, and secured through 20-year contracts.  While these long-term commitments helped Ontario transform its generation fleet over the last decade, electricity cost allocation also played a role, but longer term contracts provide limited flexibility in dealing with unexpected changes in the power system. 

"Imagine signing a 20-year contract for your cable TV service. In five years' time, electricity rates could be lower, new competitors may have entered the market, or entirely new and innovative platforms and services like Netflix may have emerged. You miss out on opportunities for improvement by being locked-in," says Gregg.

Provincial electricity demand has traditionally fluctuated over time due to factors like economic growth, conservation and the introduction of generating resources on local distribution systems, with occasional issues such as phantom demand affecting customers' costs as well. Technological changes are adding another layer of uncertainty to future demand as electric vehicles, energy storage and low-cost solar panels become more common.

"Our planners do their best to forecast electricity demand, but the truth is there's no such thing as certainty in electricity planning. That's why flexibility is so important. We don't want Ontarians to have to pay more on the typical Ontario electricity bill for electricity resources than are needed to ensure a reliable power system that can continue to meet Ontario's needs," says IESO Vice President and COO Leonard Kula.

 

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Ukraine's parliament backs amendments to electricity market law

Ukraine Electricity Market Price Caps empower the regulator, the National Commission, to set marginal prices on day-ahead, intraday, and balancing markets, stabilize competition, support thermal plants, and sustain the heating season via green tariff obligations.

 

Key Points

Regulatory limits set by the National Commission to curb price spikes, ensure competition, and secure heat supply.

✅ Sets marginal prices for day-ahead, intraday, balancing markets

✅ Mitigates collusion risks; promotes effective competition

✅ Ensures TPP operation and heat supply during heating season

 

The Verkhovna Rada, Ukraine's parliament, has adopted at first reading a draft law that proposes giving the National Commission for State Regulation of Energy and Public Utilities the right to set marginal prices in the electricity market, amid EU market revamp plans that aim to reshape pricing, until 2023.

A total of 259 MPs voted for the document at a parliament meeting on Tuesday, November 12, amid electricity import pressures that have tested the grid, according to an Ukrinform correspondent.

Bill No. 2233 introducing amendments to the law on the electricity market provides for the legislative regulation of the mechanism for fulfilling special obligations for the purchase of electricity at a "green" tariff, preventing the uncontrolled growth of electricity prices due to the lack of effective competition, including recent price-fixing allegations that have raised concerns, ensuring heat supply to consumers during the heating period by regulating the issue of the functioning of thermal power plants in the new electricity market.

It is proposed to introduce respective amendments to the law of Ukraine on the electricity market, alongside steps toward synchronization with ENTSO-E to enhance system stability.

In particular, the draft law gives the regulator the right for the period until July 1, 2023 to set marginal prices on the day-ahead market, the intraday market and the balancing market for each trade zone, reflecting similar EU fixed-price contract initiatives being discussed, and to decide on the obligation for producers to submit proposals (applications) for the sale of electricity on the day-ahead market.

Lawmakers think that the adoption of the bill and empowering the regulator to set marginal prices in the relevant segments of the electricity market will prevent, even as rolling back prices in Europe remains difficult for policymakers, "an uncontrolled increase in electricity prices due to the lack of effective competition or collusion between market players, as well as regulate the issue of the functioning of thermal power plants during the autumn and winter period, which is a necessary prerequisite for providing heat to consumers during the heating period."

The new model of the electricity market was launched on July 1 as the UK weighs decoupling gas and power prices to shield consumers, in accordance with the provisions of the law on the electricity market, adopted in 2017.

 

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