A dying industry turns to the Volt

By Toronto Star


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What's up with GM?

On one hand, it's revving up the Volt, a car that vaults it up the green technology curve and creates the impression the century-old corporation has mended its dinosaur ways.

On the other, its chief executive goes to Washington to plead for a bailout and is lambasted for not having a clue what to do with the cash and – the perfect metaphor for having his head stuck deep in another era – zipping in on his private jet. Ditto for Ford and Chrysler.

To be fair, no one in those crowded hearing rooms seemed to know what a viable plan would look like, except that it might require one of the Big Three to join Studebaker and Hudson in history's car crusher. Nothing contemplated would restore the industry to its dominant place in North America's economy. That's likely gone for good, since the domestic manufacturers already produce far more cars than consumers need and face a flood of lower-cost competitors from China.

Which brings us back to the four-seat Volt, which takes combined electric and gasoline propulsion a big leap beyond hybrids. The project is deemed so important it has, so far, survived the meltdown that's forced GM to unplug other development programs.

"At this stage, it's isolated from any challenges we face," says spokesperson Rob Peterson. The development timetable hasn't changed, nor has the November 2010 deadline for hitting showrooms.

The Volt is GM's "moon shot," vice-chairman Bob Lutz said in a recent published interview. Failure wouldn't kill the company, but success would "be sensational and... have the same sort of symbolism" as Neil Armstrong's giant leap for mankind nearly 40 years ago.

The new car is, in fact, all about image. The first production run is to total a minuscule 10,000 vehicles, not even a smudge on the bottom line.

If the technology succeeds it might appear in additional models. But for now, the Volt is all about the star of the 2006 movie Who Killed the Electric Car? trying to demonstrate it's seen the light.

In terms of public perception, the Volt is a smash. It dominates talk of environmentally friendlier cars, and boasts several websites, with interminable blogs. An unofficial customer waiting list includes 45,000 names. The car is a rallying point for those who, as Volt.com puts it, want to "help to empower and advance the impending electric car revolution."

Even so, it's no sure bet. It still faces technical hurdles and consumer resistance. The Volt will be relatively expensive: Its forecast price is approaching $40,000, $10,000 above the original target.

"North Americans have not been willing to pay for fuel efficiency – that's a very robust finding in many studies," says Johannes Van Biesebroeck, an economist at the University of Toronto. And with major purchases: "If you change radically from an earlier design, expect take-up to be very slow."

It's proceeding only because of aid from Washington – a $7,500 per car consumer rebate and a share of a $25 billion advanced technology fund. Both – separate from the current quest for a bailout – were approved last month. In return, the car will be built in Michigan. (Ontario has no role.)

Most important, even if the concept catches on, the Volt faces stiff competition. While it grabs attention, other carmakers are developing their own electric vehicles. Several were unveiled this week at the Los Angeles Auto Show. Nissan and Chrysler say theirs will go on sale around the same time the Volt is seeking customers.

All of this makes the Volt a complex part of any GM survival plan. It's useful, for the bailout negotiations, as a way to argue the corporation has a vision. It says nothing about reorganizing production of the remaining GM models or dealing with overcapacity, and it's irrelevant as a means to escape the economic crisis. Indeed, bankruptcy might propel it along; letting GM ditch aging plants and expensive union contracts.

Beyond the corporate machinations, though, the Volt suggests a bigger story. The auto industry is acting as if success now flows from reducing consumption of fossil fuels.

Even zero-emission vehicles would impact the environment – think expressways and sprawl. Making cars will still require enormous amounts of electricity. So will recharging. Still, as long as we remain besotted by our wheels, accelerating new technology is far better than racing to produce the biggest, most gas-guzzling SUV.

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Hydro One, Avista to ask U.S. regulator to reconsider order against acquisition

Hydro One Avista Takeover faces Washington UTC scrutiny as regulators deny approval; companies plan a reconsideration petition, citing acquisition terms, governance concerns, merger risks, EPS dilution, and balance sheet impacts across regulated utility operations.

 

Key Points

A $6.7B bid by Hydro One to buy Avista, denied by Washington UTC on governance risk, under reconsideration petition.

✅ UTC denied over potential provincial interference.

✅ Petition for reconsideration due by Dec. 17.

✅ Deal seen diluting EPS, weakening balance sheet.

 

Hydro One Ltd. and Avista Corp. say they plan to formally request that the Washington Utilities and Transportation Commission reconsider its order last week denying approval of the $6.7-billion takeover, which previously received U.S. antitrust clearance from federal regulators, of the U.S.-based energy utility.

The two companies say they will file a petition no later than Dec. 17 but haven't indicated on what grounds they are making the request, even as investor concerns about Hydro One persist.

Under Washington State law, the UTC has 20 days to consider the petition, otherwise it is deemed to be denied.

If it reconsiders its decision, the UTC can modify the prior order or take any actions it deems appropriate, similar to provincial rulings such as the OEB decision on Hydro One's first combined T&D rates, including extending deliberations.

Washington State regulators said they would not allow Ontario's largest utility to buy Avista for fear the provincial government, which owns 47 per cent of Hydro One's shares and recently prompted a CEO and board exit at the utility, might meddle in Avista's operations.

Hydro One's shares have risen since the order because the deal, announced in July 2017, would have eroded earnings per share and weakened Hydro One's balance sheet, according to analysts, even as the company reported a one-time-boosted Q2 profit earlier this year.

 

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Lawmakers push bill to connect Texas grid to rest of the nation

Connect the Grid Act links ERCOT to neighboring grids via high-voltage interconnections, enhancing reliability, resilience, and renewables integration. It enables power imports and exports with SPP, MISO, and the Western Interconnection under FERC oversight.

 

Key Points

A plan to link ERCOT with neighboring grids, improving reliability, enabling energy trade, and integrating renewables.

✅ High-voltage ties with SPP, MISO, and the Western Interconnection

✅ Enables imports during crises and exports of surplus power

✅ Brings ERCOT under FERC oversight; DoE to study Mexico links

 

In the aftermath of the devastating 2021 Texas blackouts, which exposed the vulnerabilities of the state's energy infrastructure, a significant legislative effort is underway to transform Texas from an energy island into a connected component of the broader U.S. power grid. Spearheaded by U.S. Representative Greg Casar, D-Austin, the proposed Connect the Grid Act is part of a push for smarter electricity infrastructure that seeks to remedy the isolation of the Electric Reliability Council of Texas (ERCOT) from neighboring power grids, a condition that significantly contributed to the crisis during Winter Storm Uri.

The blackouts, which left millions without power and resulted in significant loss of life and economic damage, underscored the inherent risks of Texas's unique energy infrastructure. Unlike the rest of the continental U.S., Texas's grid operates independently, limiting its ability to import electricity during emergencies. This isolation was a critical factor in the state's inability to respond effectively to the increased demand for power during the storm.

Recognizing the urgent need for a more resilient and integrated energy system, Rep. Casar's legislation aims to establish high-voltage connections between ERCOT and adjacent grid-operating organizations, including the Southern Power Pool, MISO, and the Western Interconnection. This would not only improve the reliability of Texas's power supply by enabling energy imports during crises but also allow the state to export surplus energy, thereby enhancing the economic efficiency and sustainability of its energy market.

The Connect the Grid Act proposes a range for the new connections' transfer capabilities, aiming to significantly boost the amount of power that can be shared between Texas and its neighbors. Such interconnectivity is anticipated to reduce energy costs for consumers by mitigating scarcity and enabling access to Texas's vast renewable energy resources, even as grid modernization affordability remains a point of debate among stakeholders. However, the bill faces opposition due to concerns over federal oversight, as it would bring ERCOT under the jurisdiction of the Federal Energy Regulatory Commission (FERC).

Some analysts note that policies such as later school start dates can ease late-summer peak demand as well.

At a press conference held at the IBEW Local 520 headquarters, Rep. Casar, along with environmental groups, labor unions, and frontline workers, highlighted the benefits of the proposed legislation. The bill also includes provisions for a Department of Energy study on the potential benefits of interconnecting with Mexico, and parallels proposals for macrogrids in Canada that seek greater reliability across borders.

The Connect the Grid Act reflects a broader national trend towards increasing the interconnectivity of regional power grids, a move deemed essential for the transition to renewable energy and combating climate change risks to the U.S. grid through expanded interconnection. By enabling the flow of clean energy from renewable-rich areas like Texas to energy-hungry urban centers, the legislation supports a more sustainable and resilient national energy infrastructure.

Critics of Texas's grid independence, including energy experts and federal regulators, have long advocated for such interconnections. They argue that increased access to neighboring grids could have mitigated the effects of the 2021 blackouts and emphasize the importance of a grid that can withstand extreme weather events. The Federal Energy Regulatory Commission and the North American Electric Reliability Corp. have both explored mandates and studies to promote electricity transfer between regional grids, while states like California grid upgrades are investing to modernize networks as well, highlighting the national importance of grid interconnectivity.

Despite the potential challenges of increased federal regulation, proponents of the Connect the Grid Act argue that the benefits of interconnection far outweigh the drawbacks. By reducing energy costs, enhancing grid reliability, and promoting renewable energy, the legislation aims to secure a more sustainable and equitable energy future for Texas and the nation.

If passed, the Connect the Grid Act would mark a historic shift in Texas's energy policy, ending the state's long-standing isolation and positioning it as a key player in the national and potentially international energy landscape, and echoes calls for a western Canadian electricity grid to strengthen regional ties. The bill sets a completion deadline of January 1, 2035, for the construction of the new connections, with other projects, like the one by Pattern Energy, potentially connecting ERCOT to parts of the Southeastern grid even earlier, by 2029. This legislative effort represents a critical step towards ensuring that Texas can meet its energy needs reliably and sustainably, while also contributing to the broader goal of transitioning to a cleaner, more resilient power system.

 

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Manitoba Hydro seeks unpaid days off to trim costs during pandemic

Manitoba Hydro unpaid leave plan offers unpaid days off to curb workforce costs amid COVID-19, avoiding temporary layoffs and pay cuts, targeting $5.7M savings through executive, manager, and engineer participation, with union options under discussion.

 

Key Points

A cost-saving measure offering unpaid days off to avert layoffs and pay cuts, targeting $5.7M savings amid COVID-19.

✅ 3 unpaid days for executives, managers, engineers

✅ Targets $5.7M total; $1.4M from non-union staff

✅ Avoids about 240 layoffs over a four-month period

 

The Manitoba government's Crown energy utility is offering workers unpaid days off as an alternative to temporary layoffs or pay cuts, even as residential electricity use rises due to more working from home.

In an email to employees, Manitoba Hydro president Jay Grewal says executives, managers, and engineers will take three unpaid days off before the fiscal year ends next March.

She says similar options are being discussed with other employee groups, which are represented by unions, as the Saskatchewan COVID-19 crisis reshaped workforces across the Prairies.

The provincial government ordered Manitoba Hydro to reduce workforce costs during the COVID-19 pandemic, as some power operators considered on-site staffing plans, and at one point the utility said it was looking at 600 to 700 temporary layoffs.

The organization said it’s looking for targeted savings of $5.7 million, down from $11 million previously estimated, while peers like BC Hydro’s Site C began reporting COVID-19 updates.

A spokesperson for Manitoba Hydro said non-unionized staff taking three days of unpaid leave will save $1.4 million of the $5.7 million savings.

“Three days of unpaid leave for every employee would eliminate layoffs entirely,” the spokesperson said in an email. “For comparison, approximately 240 layoffs would have to occur over a four-month period, while measures like Alberta's worker transition fund aim to support displaced workers, to achieve savings of $4.3 million.”

Grewal says the unpaid days off were a preferred option among the executives, managers, and engineers in an industry that recently saw a Hydro One worker injury case.

She says unions representing the other workers have been asked to respond by next Wednesday.

 

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India's Solar Growth Slows with Surge in Coal Generation

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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Climate Solution: Use Carbon Dioxide to Generate Electricity

Methane Hydrate CO2 Sequestration uses carbon capture and nitrogen injection to swap gases in seafloor hydrates along the Gulf of Mexico, releasing methane for electricity while storing CO2, according to new simulation research.

 

Key Points

A method injecting CO2 and nitrogen into hydrates to store CO2 while releasing methane for power.

✅ Nitrogen aids CO2-methane swap in hydrate cages, speeding sequestration

✅ Gulf Coast proximity to emitters lowers transport and power costs

✅ Revenue from methane electricity could offset carbon capture

 

The world is quickly realizing it may need to actively pull carbon dioxide out of the atmosphere to stave off the ill effects of climate change. Scientists and engineers have proposed various carbon capture techniques, but most would be extremely expensive—without generating any revenue. No one wants to foot the bill.

One method explored in the past decade might now be a step closer to becoming practical, as a result of a new computer simulation study. The process would involve pumping airborne CO2 down into methane hydrates—large deposits of icy water and methane right under the seafloor, beneath water 500 to 1,000 feet deep—where the gas would be permanently stored, or sequestered. The incoming CO2 would push out the methane, which would be piped to the surface and burned to generate electricity, whether sold locally or via exporters like Hydro-Que9bec to help defray costs, to power the sequestration operation or to bring in revenue to pay for it.

Many methane hydrate deposits exist along the Gulf of Mexico shore and other coastlines. Large power plants and industrial facilities that emit CO2 also line the Gulf Coast, where EPA power plant rules could shape deployment, so one option would be to capture the gas directly from nearby smokestacks, keeping it out of the atmosphere to begin with. And the plants and industries themselves could provide a ready market for the electricity generated.

A methane hydrate is a deposit of frozen, latticelike water molecules. The loose network has many empty, molecular-size pores, or “cages,” that can trap methane molecules rising through cracks in the rock below. The computer simulation shows that pushing out the methane with CO2 is greatly enhanced if a high concentration of nitrogen is also injected, and that the gas swap is a two-step process. (Nitrogen is readily available anywhere, because it makes up 78 percent of the earth’s atmosphere.) In one step the nitrogen enters the cages; this destabilizes the trapped methane, which escapes the cages. In a separate step, the nitrogen helps CO2 crystallize in the emptied cages. The disturbed system “tries to reach a new equilibrium; the balance goes to more CO2 and less methane,” says Kris Darnell, who led the study, published June 27 in the journal Water Resources Research. Darnell recently joined the petroleum engineering software company Novi Labs as a data scientist, after receiving his Ph.D. in geoscience from the University of Texas, where the study was done.

A group of labs, universities and companies had tested the technique in a limited feasibility trial in 2012 on Alaska’s North Slope, where methane hydrates form in sandstone under deep permafrost. They sent CO2 and nitrogen down a pipe into the hydrate. Some CO2 ended up being stored, and some methane was released up the same pipe. That is as far as the experiment was intended to go. “It’s good that Kris [Darnell] could make headway” from that experience, says Ray Boswell at the U.S. Department of Energy’s National Energy Technology Laboratory, who was one of the Alaska experiment leaders but was not involved in the new study. The new simulation also showed that the swap of CO2 for methane is likely to be much more extensive—and to happen quicker—if CO2 enters at one end of a hydrate deposit and methane is collected at a distant end.

The technique is somewhat similar in concept to one investigated in the early 2010s by Steven Bryant and others at the University of Texas. In addition to numerous methane hydrate deposits, the Gulf Coast has large pools of hot, salty brine in sedimentary rock under the coastline. In this system, pumps would send CO2 down into one end of a deposit, which would force brine into a pipe that is placed at the other end and leads back to the surface. There the hot brine would flow through a heat exchanger, where heat could be extracted and used for industrial processes or to generate electricity, supporting projects such as electrified LNG in some markets. The upwelling brine also contains some methane that could be siphoned off and burned. The CO2 dissolves into the underground brine, becomes dense and sinks further belowground, where it theoretically remains.

Either system faces big practical challenges, and building shared CO2 storage hubs to aggregate captured gas is still evolving. One is creating a concentrated flow of CO2; the gas makes up only .04 percent of air, and roughly 10 percent of the smokestack emission from a typical power plant or industrial facility. If an efficient methane hydrate or brine system requires an input that is 90 percent CO2, for example, concentrating the gas will require an enormous amount of energy—making the process very expensive. “But if you only need a 50 percent concentration, that could be more attractive,” says Bryant, who is now a professor of chemical and petroleum engineering at the University of Calgary. “You have to reduce the [CO2] capture cost.”

Another major challenge for the methane hydrate approach is how to collect the freed methane, which could simply seep out of the deposit through numerous cracks and in all directions. “What kind of well [and pipe] structure would you use to grab it?” Bryant asks.

Given these realities, there is little economic incentive today to use methane hydrates for sequestering CO2. But as concentrations rise in the atmosphere and the planet warms further, and as calls for an electric planet intensify, systems that could capture the gas and also provide energy or revenue to run the process might become more viable than techniques that simply pull CO2 from the air and lock it away, offering nothing in return.

 

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Victims of California's mega-fire will sue electricity company

PG&E Wildfire Lawsuit alleges utility negligence, inadequate infrastructure maintenance, and faulty transmission lines, as victims seek compensation. Regulators investigate the blaze, echoing class actions after Victoria's Black Saturday mega-fires and utility oversight failures.

 

Key Points

PG&E Wildfire Lawsuit alleges utility negligence and power line faults, seeking victim compensation amid investigations.

✅ Alleged failure to maintain transmission infrastructure

✅ Spark reports and regulator filings before blaze erupted

✅ Class action parallels with Australia's Black Saturday

 

Victims of California's most destructive wildfire have filed a lawsuit accusing Pacific Gas & Electric Co. of causing the massive blaze, a move that follows the utility's 2018 Camp Fire guilty plea in a separate case.

The suit filed on Tuesday in state court in California accuses the utility of failing to maintain its infrastructure and properly inspect and manage its power transmission lines, amid prior reports that power lines may have sparked fires in California.

The utility's president said earlier the company doesn't know what caused the fire, but is cooperating with the investigation by state agencies, and other utilities such as Southern California Edison have faced wildfire lawsuits in California.

PG&E told state regulators last week that it experienced a problem with a transmission line in the area of the fire just before the blaze erupted.

A landowner near where the blaze began said PG&E notified her the day before the wildfire that crews needed to come onto her property because some wires were sparking, and the company later promoted its wildfire assistance program for victims seeking aid.

A massive class action after Australia's last mega-fire, Victoria's Black Saturday in 2009, saw $688.5 million paid in compensation to thousands of claimants affected by the Kilmore-Kinglake and Murrindindi-Marysville fires, partly by electricity company SP Ausnet, and partly by government agencies, while in California PG&E's bankruptcy plan won support from wildfire victims addressing compensation claims.

 

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