Coal industry ‘pensive’ about Obama

By Associated Press


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Bill Raney considers coal golden. After all, the black rock fuels half of the nation's electrical generation.

But the West Virginia Coal Association's president and others in the industry say they've received mixed messages about president-elect Barack Obama's support for coal-fired power.

Obama and vice president-elect Joe Biden both have said they support finding cleaner ways to burn coal. But during the campaign, Obama told a newspaper that electricity rates could soar under his energy plan, while Biden told a voter in Ohio that "we're not supporting clean coal" — though he has said the U.S. should develop clean coal technology and export it to China.

"I think there's a great deal of pensiveness," Raney said.

Others, including Obama's camp, say they see little reason to worry.

Obama comes from Illinois, a coal-producing state, and supported its bid for the FutureGen experimental coal-fired power plant that would store emissions of carbon dioxide — a heat-trapping gas blamed for global warming — underground. After the plant was awarded to Mattoon, Ill., the Bush administration and the U.S. Energy Department walked away, citing costs that had ballooned to $1.8 billion.

Some key Democrats are from coal states. Illinois Sen. Dick Durbin is the Senate's No. 2 Democrat. Ed Rendell, former chairman of the Democratic National Committee, is governor of Pennsylvania, a big coal producer and home to steel mills that rely on the ore.

"All of these people who are some of the strongest supporters of coal in the U.S. Congress and in the governor's office... have supported and worked hard for President-elect Obama," said Cecil Roberts, president of United Mine Workers, which endorsed Obama last spring. "And I don't think he's going to let those folks down."

Luke Popovich, a spokesman for the National Mining Association, a trade group that includes many of the nation's biggest mining-equipment makers, said he believes Obama will be pragmatic about the need to keep coal in the nation's energy mix.

"He presumably would be sensitive to the impacts of energy policies on the economy given the perilous state of the economy," Popovich said. "And he's certainly shown an exceptional ability to listen to and to hear what voters want, and what we think voters said they wanted was practical solutions."

Obama has said he recognizes coal's importance in powering the U.S., but achieving his ambitious emissions-cutting objectives hinges on finding more environmentally friendly ways of using coal to generate electricity. He has said his goal is to create five first-of-a-kind, coal-fired demonstration plants that would capture carbon emissions and store them underground "so they're not adding to global warming."

The president plays a pivotal role in shaping the nation's energy policy, naming top officials at the U.S. Environmental Protection Agency, Office of Surface Mining Reclamation and Enforcement and U.S. Army Corps of Engineers. And on Capitol Hill, Democrats have padded their majorities in both chambers.

"So when the music stops, who will be chairing the various committees with jurisdictions over coal? That will also be critical," Popovich said.

Some of that jockeying on Capitol Hill already is under way.

Democrats steered the House toward more aggressively tackling global warming and other environmental problems, tapping California liberal Henry Waxman to head the House's Energy and Commerce panel.

An avid environmentalist and booster of health care programs, Waxman replaces Michigan Rep. John Dingell, an old-school supporter of Detroit's carmakers and other big industries such as electric utilities. Waxman is expected to move legislation with tougher emissions standards than Dingell would have.

Well before that, Waxman and other powerful Washington voices, including Senate Majority Leader Harry Reid, lined up against coal-fired power, which churns out two billions tons of greenhouse gases annually. Waxman this year signed onto legislation that would ban any new coal-fired power plants built without technology to capture carbon dioxide.

Yet uncertainty lingers, often tied to Obama's statement to the San Francisco Chronicle's editorial board in January that his proposed cap-and-trade system to control greenhouse gases — which would set an overall emissions limit, then require polluters to buy allowances at public auction — would be "as aggressive if not more aggressive than anybody else's out there."

He also told the newspaper that electricity rates would increase, and coal-fired plants that did not reduce pollution could go bankrupt because of the costs of buying pollution allowances.

Obama's energy plan includes mandatory reductions of greenhouse gas emissions to 80 percent below 1990 levels by 2050. He also proposed a 10-year $150 billion fund for biofuels, wind, solar, plug-in hybrids, clean-coal technology and other "climate-friendly" measures, and would require utilities to produce 25 percent of power from renewable energy by 2025.

At St. Louis-based Peabody Energy, among the world's biggest coal producers, spokesman Vic Svec said "there is obvious cause for alarm when political leaders acknowledge that under onerous cap-and-trade bills that limit coal use, ‘electricity costs would skyrocket.’"

But Svec notes that Obama's comments to the San Francisco newspaper are nearly a year old, and that since then Obama dozens of times has voiced growing support for clean-coal technologies — including FutureGen, the project that includes Peabody as a potential partner.

"This may seem counterintuitive, but we are eager for the new administration in terms of their support for coal and their support for advancement of carbon capture and storage technology," said Svec, whose company fuels roughly one-tenth of all U.S. electricity generation and more than 2 percent worldwide.

Popovich, from the mining trade group, said he suspects that the faltering U.S. economy will make Obama reluctant to mess with "indispensable" King Coal.

"I would say there's some cautious — underscore cautious — optimism," he said. "You're not going to help the American economy by hurting coal production and coal utilization."

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EIA expects solar and wind to be larger sources of U.S. electricity generation this summer

US Summer Electricity Outlook 2022 projects rising renewable energy generation as utility-scale solar and wind capacity additions surge, while coal declines and natural gas shifts amid higher fuel prices and regional supply constraints.

 

Key Points

An EIA forecast of summer 2022 power: more solar and wind, less coal, and shifting gas use amid higher fuel prices.

✅ Solar +10 million MWh; wind +8 million MWh vs last summer

✅ Coal generation -20 million MWh amid supply constraints, retirements

✅ Gas prices near $9/MMBtu; slight national gen decline

 

In our Summer Electricity Outlook, a supplement to our May 2022 Short-Term Energy Outlook, we expect the largest increases in U.S. electric power sector generation this summer will come from renewable energy sources such as wind and solar generation. These increases are the result of new capacity additions. We forecast utility-scale solar generation between June and August 2022 will grow by 10 million megawatthours (MWh) compared with the same period last summer, and wind generation will grow by 8 million MWh. Forecast generation from coal and natural gas declines by 26 million MWh this summer, although natural gas generation could increase in some electricity markets where coal supplies are constrained.

For recent context, overall U.S. power generation in January rose 9.3% year over year, the EIA reports.

Wind and solar power electric-generating capacity has been growing steadily in recent years. By the start of June, we estimate the U.S. electric power sector will have 65 gigawatts (GW) of utility-scale solar-generating capacity, a 31% increase in solar capacity since June 2021. Almost one-third of this new solar capacity will be built in the Texas electricity market. The electric power sector will also have an estimated 138 GW of wind capacity online this June, which is a 12% increase from last June.

Along with growth in renewables capacity, we expect that an additional 6 GW of new natural gas combined-cycle generating capacity will come online by June 2022, an increase of 2% from last summer. Despite this increase in capacity, we expect natural gas-fired electricity generation at the national level will be slightly (1.3%) lower than last summer.

We forecast the price of natural gas delivered to electric generators will average nearly $9 per million British thermal units between June and August 2022, which would be more than double the average price last summer. The higher expected natural gas prices and growth in renewable generation will likely lead to less natural gas-fired generation in some regions of the country.

In contrast to renewables and natural gas, the electricity industry has been steadily retiring coal-fired power plants over the past decade. Between June 2021 and June 2022, the electric power sector will have retired 6 GW (2%) of U.S. coal-fired generating capacity.

In previous years, higher natural gas prices would have resulted in more coal-fired electricity generation across the fleet. However, coal-fired power plants have been limited in their ability to replenish their historically low inventories in recent months as a result of mine closures, rail capacity constraints, and labor market tightness. These coal supply constraints, along with continued retirement of generating capacity, contribute to our forecast that U.S. coal-fired generation will decline by 20 million MWh (7%) this summer. In some regions of the country, these coal supply constraints may lead to increased natural gas-fired electricity generation despite higher natural gas prices.
 

 

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Africa's Electricity Unlikely To Go Green This Decade

Africa 2030 Energy Mix Forecast finds electricity generation doubling, with fossil fuels dominant, non-hydro renewables under 10%, hydro vulnerable to droughts, and machine-learning analysis of planned power plants shaping climate and investment decisions.

 

Key Points

An analysis predicting Africa's 2030 power mix, with fossil fuels dominant, limited renewables growth, and hydro risks.

✅ ML model assesses 2,500 planned plants' commissioning odds

✅ Fossil fuels ~66% of generation; non-hydro RE <10% by 2030

✅ Policy shifts and finance reallocation to scale solar and wind

 

New research today from the University of Oxford predicts that total electricity generation across the African continent will double by 2030, with fossil fuels continuing to dominate the energy mix posing potential risk to global climate change commitments.

The study, published in Nature Energy, uses a state-of-the art machine-learning technique to analyse the pipeline of more than 2,500 currently-planned power plants and their chances of being successfully commissioned. It shows the share of non-hydro renewables in African electricity generation is likely to remain below 10% in 2030, although this varies by region.

'Africa's electricity demand is set to increase significantly as the continent strives to industrialise and improve the wellbeing of its people, which offers an opportunity to power this economic development and expand universal electricity access through renewables' says Galina Alova, study lead author and researcher at the Oxford Smith School of Enterprise and the Environment.

'There is a prominent narrative in the energy planning community that the continent will be able to take advantage of its vast renewable energy resources and rapidly decreasing clean technology prices to leapfrog to renewables by 2030 but our analysis shows that overall it is not currently positioned to do so.'

The study predicts that in 2030, fossil fuels will account for two-thirds of all generated electricity across Africa. While an additional 18% of generation is set to come from hydro-energy projects across Africa. These have their own challenges, such as being vulnerable to an increasing number of droughts caused by climate change.

The research also highlights regional differences in the pace of the transition to renewables across Sub-Saharan Africa, with southern Africa leading the way. South Africa alone is forecast to add almost 40% of Africa's total predicted new solar capacity by 2030.

'Namibia is committed to generate 70% of its electricity needs from renewable sources, including all the major alternative sources such as hydropower, wind and solar generation, by 2030, as specified in the National Energy Policy and in Intended Nationally Determined Contributions under Paris Climate Change Accord,' says Calle Schlettwein, Namibia Minister of Water (former Minister of Finance and Minister of Industrialisation). 'We welcome this study and believe that it will support the refinement of strategies for increasing generation capacity from renewable sources in Africa and facilitate both successful and more effective public and private sector investments in the renewable energy sector.'

Minister Schlettwein adds: 'The more data-driven and advanced analytics-based research is available for understanding the risks associated with power generation projects, the better. Some of the risks that could be useful to explore in the future are the uncertainties in hydrological conditions and wind regimes linked to climate change, and economic downturns such as that caused by the COVID-19 pandemic.'

The study further suggests that a decisive move towards renewable energy in Africa would require a significant shock to the current system. This includes large-scale cancellation of fossil fuel plants currently being planned. In addition, the study identifies ways in which planned renewable energy projects can be designed to improve their success chances for example, smaller size, fitting ownership structure, and availability of development finance for projects.

'The development community and African decision makers need to act quickly if the continent wants to avoid being locked into a carbon-intense energy future' says Philipp Trotter, study author and researcher at the Smith School. 'Immediate re-directions of development finance from fossil fuels to renewables are an important lever to increase experience with solar and wind energy projects across the continent in the short term, creating critical learning curve effects.'

 

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The biggest problem facing the U.S. electric grid isn't demand. It's climate change

US power grid modernization addresses aging infrastructure, climate resilience, extreme weather, EV demand, and clean energy integration, using AI, transmission upgrades, and resilient substations to improve reliability, reduce outages, and enable rapid recovery.

 

Key Points

US power grid modernization strengthens infrastructure for resilience, reliability, and clean energy under rising demand.

✅ Hardening substations, lines, and transformers against extreme weather

✅ Integrating EV load, DERs, and renewables into transmission and distribution

✅ Using AI, sensors, and automation to cut outages and speed restoration

 

The power grid in the U.S. is aging and already struggling to meet current demand, with dangerous vulnerabilities documented across the system today. It faces a future with more people — people who drive more electric cars and heat homes with more electric furnaces.

Alice Hill says that's not even the biggest problem the country's electricity infrastructure faces.

"Everything that we've built, including the electric grid, assumed a stable climate," she says. "It looked to the extremes of the past — how high the seas got, how high the winds got, the heat."

Hill is an energy and environment expert at the Council on Foreign Relations. She served on the National Security Council staff during the Obama administration, where she led the effort to develop climate resilience. She says past weather extremes can no longer safely guide future electricity planning.

"It's a little like we're building the plane as we're flying because the climate is changing right now, and it's picking up speed as it changes," Hill says.

The newly passed infrastructure package dedicates billions of dollars to updating the energy grid with smarter electricity infrastructure programs that aim to modernize operations. Hill says utility companies and public planners around the country are already having to adapt. She points to the storm surge of Hurricane Sandy in 2012.

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"They thought the maximum would be 12 feet," she says. "That storm surge came in close to 14 feet. It overcame the barriers at the tip of Manhattan, and then the electric grid — a substation blew out. The city that never sleeps [was] plunged into darkness."

Hill noted that Con Edison, the utility company providing New York City with energy, responded with upgrades to its grid: It buried power lines, introduced artificial intelligence, upgraded software to detect failures. But upgrading the way humans assess risk, she says, is harder.

"What happens is that some people tend to think, well, that last storm that we just had, that'll be the worst, right?" Hill says. "No, there is a worse storm ahead. And then, probably, that will be exceeded."

In 2021, the U.S. saw electricity outages for millions of people as a result of historic winter storms in Texas, a heatwave in the Pacific Northwest and Hurricane Ida along the Gulf Coast. Climate change will only make extreme weather more likely and more intense, driving longer, more frequent outages for utilities and customers.

In the West, California's grid reliability remains under scrutiny as the state navigates an ambitious clean energy shift.

And that has forced utility companies and other entities to grapple with the question: How can we prepare for blackouts and broader system stress we've never experienced before?

A modern power station in Maryland is built for the future
In the town of Edgemere, Md., the Fitzell substation of Baltimore Gas and Electric delivers electricity to homes and businesses. The facility is only a year or so old, and Laura Wright, the director of transmission and substation engineering, says it's been built with the future in mind.

She says the four transformers on site are plenty for now. And to counter the anticipated demand of population growth and a future reliance on electric cars, she says the substation has been designed for an easy upgrade.

"They're not projecting to need that additional capacity for a while, but we designed this station to be able to take that transformer out and put in a larger one," Wright says.

Slopes were designed to insulate the substation from sea level rise. And should the substation experience something like a catastrophic flooding event or deadly tornado, there's a plan for that too.

"If we were to have a failure of a transformer," Wright says, "we can bring one of those mobile transformers into the substation, park it in the substation, connect it up in place of that transformer. And we can do that in two to three days."

The Fitzell substation is a new, modern complex. Older sites can be knocked down for weeks.

That raises the question: Can the amount of money dedicated to the power grid in the new infrastructure legislation actually make meaningful changes to the energy system across the country, where studies find more blackouts than other developed nations persist?

"The infrastructure bill, unfortunately, only scratches the surface," says Daniel Cohan, an associate professor in civil and environmental engineering at Rice University.

Though the White House says $65 billion of the infrastructure legislation is dedicated to power infrastructure, a World Resources Institute analysis noted that only $27 billion would go to the electric grid — a figure that Cohan also used.

"If you drill down into how much is there for the power grid, it's only about $27 billion or so, and mainly for research and demonstration projects and some ways to get started," he says.

Cohan, who is also author of the forthcoming book Confronting Climate Gridlock, says federal taxpayer dollars can be significant but that most of the needed investment will eventually come from the private sector — from utility companies and other businesses spending "many hundreds of billions of dollars per decade," even as grid modernization affordability remains a concern. He also says the infrastructure package "misses some opportunities" to initiate that private-sector action through mandates.

"It's better than nothing, but, you know, with such momentous challenges that we face, this isn't really up to the magnitude of that challenge," Cohan says.

Cohan argues that thinking big, and not incrementally, can pay off. He believes a complete transition from fossil fuels to clean energy by 2035 is realistic and attainable — a goal the Biden administration holds — and could lead to more than just environmental benefit.

"It also can lead to more affordable electricity, more reliable electricity, a power supply that bounces back more quickly when these extreme events come through," he says. "So we're not just doing it to be green or to protect our air and climate, but we can actually have a much better, more reliable energy supply in the future."

 

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Net-Zero Emissions Might Not Be Possible Without Nuclear Power

Nuclear Power for Net-Zero Grids anchors reliable baseload, integrating renewables with grid stability as solar, wind, and battery storage scale. Advanced reactors complement hydropower, curb natural gas reliance, and accelerate deep decarbonization of electricity systems.

 

Key Points

Uses nuclear baseload and advanced reactors to stabilize power grids and integrate higher shares of variable renewables.

✅ Provides firm, zero-carbon baseload for renewable-heavy grids

✅ Reduces natural gas dependence and peaker emissions

✅ Advanced reactors enhance safety, flexibility, and cost

 

Declining solar, wind, and battery technology costs are helping to grow the share of renewables in the world’s power mix to the point that governments are pledging net-zero emission electricity generation in two to three decades to fight global warming.

Yet, electricity grids will continue to require stable baseload to incorporate growing shares of renewable energy sources and ensure lights are on even when the sun doesn’t shine, or the wind doesn’t blow. Until battery technology evolves enough—and costs fall far enough—to allow massive storage and deployment of net-zero electricity to the grid, the systems will continue to need power from sources other than solar and wind.

And these will be natural gas and nuclear power, regardless of concerns about emissions from the fossil fuel natural gas and potential disasters at nuclear power facilities such as the ones in Chernobyl or Fukushima.

As natural gas is increasingly considered as just another fossil fuel, nuclear power generation provides carbon-free electricity to the countries that have it, even as debates over nuclear power’s outlook continue worldwide, and could be the key to ensuring a stable power grid capable of taking in growing shares of solar and wind power generation.

The United States, where nuclear energy currently provides more than half of the carbon-free electricity, is supporting the development of advanced nuclear reactors as part of the clean energy strategy.

But Europe, which has set a goal to reach carbon neutrality by 2050, could find itself with growing emissions from the power sector in a decade, as many nuclear reactors are slated for decommissioning and questions remain over whether its aging reactors can bridge the gap. The gap left by lost nuclear power is most easily filled by natural gas-powered electricity generation—and this, if it happens, could undermine the net-zero goals of the European Union (EU) and the bloc’s ambition to be a world leader in the fight against climate change.

 

U.S. Power Grid Will Need Nuclear For Net-Zero Emissions

A 2020 report from the University of California, Berkeley, said that rapidly declining solar, wind, and storage prices make it entirely feasible for the U.S. to meet 90 percent of its power needs from zero-emission energy sources by 2035 with zero increases in customer costs from today’s levels.

Still, natural gas-fired generation will be needed for 10 percent of America’s power needs. According to the report, in 2035 it would be possible that “during normal periods of generation and demand, wind, solar, and batteries provide 70% of annual generation, while hydropower and nuclear provide 20%.” Even with an exponential rise in renewable power generation, the U.S. grid will need nuclear power and hydropower to be stable with such a large share of solar and wind.

The U.S. Backs Advanced Nuclear Reactor Technology

The U.S. Department of Energy is funding programs of private companies under DOE’s new Advanced Reactor Demonstration Program (ARDP) to showcase next-gen nuclear designs for U.S. deployment.

“Taking leadership in advanced technology is so important to the country’s future because nuclear energy plays such a key role in our clean energy strategy,” U.S. Secretary of Energy Dan Brouillette said at the end of December when DOE announced it was financially backing five teams to develop and demonstrate advanced nuclear reactors in the United States.

“All of these projects will put the U.S. on an accelerated timeline to domestically and globally deploy advanced nuclear reactors that will enhance safety and be affordable to construct and operate,” Secretary Brouillette said.

According to Washington DC-based Nuclear Energy Institute (NEI), a policy organization of the nuclear technologies industry, nuclear energy provides nearly 55 percent of America’s carbon-free electricity. That is more than 2.5 times the amount generated by hydropower, nearly 3 times the amount generated by wind, and more than 12 times the amount generated by solar. Nuclear energy can help the United States to get to the deep carbonization needed to hit climate goals.

 

Europe Could See Rising Emissions Without Nuclear Power

While the United States is doubling down on efforts to develop advanced and cheaper nuclear reactors, including microreactors and such with new types of technology, Europe could be headed to growing emissions from the electricity sector as nuclear power facilities are scheduled to be decommissioned over the next decade and Europe is losing nuclear power just when it really needs energy, according to a Reuters analysis from last month.

In many cases, it will be natural gas that will come to the rescue to power grids to ensure grid stability and enough capacity during peak demand because solar and wind generation is variable and dependent on the weather.

For example, Germany, the biggest economy in Europe, is boosting its renewables targets, but it is also phasing out nuclear by next year, amid a nuclear option debate over climate strategy, while its deadline to phase out coal-fired generation is 2038—more than a decade later compared to phase-out plans in the UK and Italy, for example, where the deadline is the mid-2020s.

The UK, which left the EU last year, included support for nuclear power generation as one of the ten pillars in ‘The Ten Point Plan for a Green Industrial Revolution’ unveiled in November.

The UK’s National Grid has issued several warnings about tight supply since the fall of 2020, due to low renewable output amid high demand.

“National Grid’s announcement underscores the urgency of investing in new nuclear capacity, to secure reliable, always-on, emissions-free power, alongside other zero-carbon sources. Otherwise, we will continue to burn gas and coal as a fallback and fall short of our net zero ambitions,” Tom Greatrex, Chief Executive of the Nuclear Industry Association, said in response to one of those warnings.

But it’s in the UK that one major nuclear power plant project has notoriously seen a delay of nearly a decade—Hinkley Point C, originally planned in 2007 to help UK households to “cook their 2017 Christmas turkeys”, is now set for start-up in the middle of the 2020s.

Nuclear power development and plant construction is expensive, but it could save the plans for low-carbon emission power generation in many developed economies, including in the United States.

 

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Ottawa making electricity more expensive for Albertans

Alberta Electricity Price Surge reflects soaring wholesale rates, natural gas spikes, carbon tax pressures, and grid decarbonization challenges amid cold-weather demand, constrained supply, and Europe-style energy crisis impacts across the province.

 

Key Points

An exceptional jump in Alberta's power costs driven by gas price spikes, high demand, policy costs, and tight supply.

✅ Wholesale prices averaged $123/MWh in December

✅ Gas costs surged; supply constraints and outages

✅ Carbon tax and decarbonization policies raised costs

 

Albertans just endured the highest electricity prices in 21 years. Wholesale prices averaged $123 per megawatt-hour in December, more than triple the level from the previous year and highest for December since 2000.

The situation in Alberta mirrors the energy crisis striking Europe where electricity prices are also surging, largely due to a shocking five-fold increase in natural gas prices in 2021 compared to the prior year.

The situation should give pause to Albertans when they consider aggressive plans to “decarbonize” the electric grid, including proposals for a fully renewable grid by 2030 from some policymakers.

The explanation for skyrocketing energy prices is simple: increased demand (because of Calgary's frigid February demand and a slowly-reviving post-pandemic economy) coupled with constrained supply.

In the nitty gritty details, there are always particular transitory causes, such as disputes with Russian gas companies (in the case of Europe) or plant outages (in the case of Alberta).

But beyond these fleeting factors, there are more permanent systemic constraints on natural gas (and even more so, coal-fired) power plants.

I refer of course to the climate change policies of the Trudeau government at the federal level and some of the more aggressive provincial governments, which have notable implications for electricity grids across Canada.

The most obvious example is the carbon tax, the repeal of which Premier Jason Kenney made a staple of his government.

Putting aside the constitutional issues (on which the Supreme Court ruled in March of last year that the federal government could impose a carbon tax on Alberta), the obvious economic impact will be to make carbon-sourced electricity more expensive.

This isn’t a bug or undesired side-effect, it’s the explicit purpose of a carbon tax.

Right now, the federal carbon tax is $40 per tonne, is scheduled to increase to $50 in April, and will ultimately max out at a whopping $170 per tonne in 2030.

Again, the conscious rationale of the tax, aligned with goals for cleaning up Canada's electricity, is to make coal, oil and natural gas more expensive to induce consumers and businesses to use alternative energy sources.

As Albertans experience sticker shock this winter, they should ask themselves — do we want the government intentionally making electricity and heating oil more expensive?

Of course, the proponent of a carbon tax (and other measures designed to shift Canadians away from carbon-based fuels) would respond that it’s a necessary measure in the fight against climate change, and that Canada will need more electricity to hit net-zero according to the IEA.

Yet the reality is that Canada is a bit player on the world stage when it comes to carbon dioxide, responsible for only 1.5% of global emissions (as of 2018).

As reported at this “climate tracker” website, if we look at the actual policies put in place by governments around the world, they’re collectively on track for the Earth to warm 2.7 degrees Celsius by 2100, far above the official target codified in the Paris Agreement.

Canadians can’t do much to alter the global temperature, but federal and provincial governments can make energy more expensive if policymakers so choose, and large-scale electrification could be costly—the Canadian Gas Association warns of $1.4 trillion— if pursued rapidly.

As renewable technologies become more reliable and affordable, business and consumers will naturally adopt them; it didn’t take a “manure tax” to force people to use cars rather than horses.

As official policy continues to make electricity more expensive, Albertans should ask if this approach is really worth it, or whether options like bridging the Alberta-B.C. electricity gap could better balance costs.

Robert P. Murphy is a senior fellow at the Fraser Institute.

 

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5,000 homes would be switched to geothermal energy free of charge

Manitoba NDP Geothermal Conversion Program offers full-cost heat pump installation for 5,000 homes, lowering electricity bills, funding contractor training and rebates, and cutting greenhouse gas emissions via geothermal energy administered by Efficiency Manitoba.

 

Key Points

A plan funding 5,000 home heat pump conversions to cut electricity bills, reduce emissions, and expand installer capacity.

✅ Covers equipment and installation for 5,000 homes

✅ Cuts electricity bills up to 50% vs electric heat

✅ Administered by Efficiency Manitoba; trains contractors

 

An NDP government would cover the entire cost for 5,000 families to switch their homes to geothermal energy, New Democrats have promised.

If elected on Oct. 3, the NDP will pay for the equipment and installation of new geothermal systems at 5,000 homes, St. James candidate Adrien Sala announced outside a St. Boniface home that previously made the switch. 

The homes that switch to geothermal energy could save as much as 50 per cent on their electricity bills, Sala said.

"It will save you money, it will grow our economy and it will reduce greenhouse gas emissions. And I think we can safely call that a win, win, win," Sala said.

Geothermal energy is derived from heat that is generated within the Earth.

The NDP said each conversion to geothermal heating and cooling would cost an estimated $26,000, and comes as new turbine investments advance in Manitoba, and it would take four years to complete all 5,000 conversions.

The program would be administered through Efficiency Manitoba, the Crown corporation responsible for conserving energy, as Manitoba Hydro's new president navigates changes at the utility. The NDP estimates it will cost $32.5 million annually over the four years, at a time of red ink at Manitoba Hydro as new power generation needs loom. Some of that money would support the training of more contractors who could install geothermal systems.


Subsidies get low pickup: NDP
Sala wouldn't say Wednesday which homeowners or types of homes would be eligible.

He said the NDP's plan would be a first in Canada, even as Ontario's energy plan seeks to address growing demand elsewhere.

"What we've seen elsewhere is where other jurisdictions have used a strict subsidy model, where they try to reduce the cost of geothermal, and while Ontario reviews a halt to natural gas generation to cut emissions, approaches differ across provinces. We really haven't seen a lot of uptake in those other jurisdictions," Sala said.

"This is an attempt at dealing with one of those key barriers for homeowners."

Efficiency Manitoba runs a subsidy program for geothermal energy through ground source heat pumps, supporting using more electricity for heat across the province, valued at up to $2.50 per square foot. It is estimated a 1,600 sq. ft. home switching from an electric furnace to geothermal will receive a rebate of around $4,000 and save around $900 annually on their electricity bills, the Crown corporation said.anitoba homeProgressive Conservative spokesperson Shannon Martin questioned how NDP Leader Wab Kinew can afford his party's numerous election promises.

"He will have no choice but to raise taxes, and history shows the NDP will raise them all," said Martin, the McPhillips MLA who isn't seeking re-election.

Wednesday's announcement was the first for the NDP in which Kinew wasn't present. The party has criticized the Progressive Conservatives for leader Heather Stefanson showing up for only a few announcements a week.

Sala said Kinew was busy preparing for the debate later in the day.

"This stuff is near and dear to Wab's heart, and frankly, I think he's probably hurting that he's not here with us right now."

 

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