Page power plant under fire for emissions

By Arizona Daily Sun


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The Grand Canyon Trust and other environmental groups are pressing for tighter pollution controls on the coal-burning power plant near Page.

They say air pollution from the plant is marring views at Grand Canyon National Park even after the power station underwent improvements in the 1990s. But the owners of the plant contend it is one of the cleanest in the West and that further reductions in pollutants are scheduled.

The National Parks Conservation Association, Sierra Club, Grand Canyon Trust, San Juan Citizens Alliance, To Nizhoni Ani and Dine CARE filed a petition with the Interior Department on Tuesday seeking to have Interior and the Environmental Protection Agency require state-of-the-art pollution devices on the Navajo Generating Station.

The 2,250-megawatt plant is one of the larger coal-fired plants in the country and employs 545.

A similar petition filed a decade ago by conservation groups resulted in the EPA requiring new controls at the Mohave Generating Station in Laughlin, Nev.

The owners of that plant said the improvements were cost-prohibitive and the facility has been shut down.

In essence, the groups are pressing the National Park Service to state that air in the Grand Canyon is not as clean as the Clean Air Act requires in a national park, and that the power plant near Page is one reason why.

The Park Service is already on board, following years of air quality modeling.

"There's ample data that shows that Navajo Generating Station contributes to visibility impairment at the park," said Chris Shaver, chief of the Park Service division that monitors air quality in the nation's parks.

Researchers at the Grand Canyon say smog emitted in Southern California, Las Vegas, and Phoenix also likely contributes to poor visibility in the Grand Canyon.

The ultimate goal is to have the plant convert partly to being run from renewable energy, or to close, said Roger Clark, of the Grand Canyon Trust.

"It's had a good run. It's time to go to pasture," Clark said of Navajo Generating Station, scheduled to operate to 2026.

The power plant discharges 34,000 tons of nitrogen oxides, 1,900 tons of particulate matter and 3,690 tons of sulfur dioxide and 20 million tons of carbon dioxide into the air annually, the groups say in their petition.

They are pressing for expensive, top-notch pollution controls.

But those would not reduce greenhouse gases, like carbon dioxide.

The U.S. Bureau of Reclamation, Salt River Project, Los Angeles Department of Water and Power, Arizona Public Service, Nevada Power, and Tucson Electric Power own the Navajo Generating Station, which generates enough electricity to supply more than 500,000 homes in Arizona, Nevada and California and pump Colorado River water to Phoenix via the Central Arizona Project.

Operating costs for the plant, located on the Navajo Nation, run $200 million annually, not including coal purchased from the Kayenta Mine and Peabody Coal to feed it.

The plant is also supplied with a little less than 27,000 acre-feet of water per year from Lake Powell — or more than twice as much water as the city of Flagstaff consumes annually.

The owners of Navajo Generating Station spent more than $400 million in the 1990s to greatly cut some of the farthest-traveling air pollution from the plant, under pressure from the Grand Canyon Trust and the EPA.

SRP calls the plant, operating since 1974, among the cleanest coal-fired power stations in the West.

"The emissions at Navajo Generating Station are at rates that are comparable to what have been set for new plants," said Kevin Wanttaja, manager of environmental services at Salt River Project, which operates the Navajo Generating Station.

The utility plans to add more equipment to remove nitrogen oxides, Wanttaja said, but the groups filing the petition say that doesn't go far enough.

"Maybe it will need to shut down if it can't be cleaned up, but we think a transition from coal to renewables in the next 10 years is going to have to happen one way or another," said Andy Bessler, of the Sierra Club office in Flagstaff.

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Report: Duke Energy to release climate report under investor pressure

Duke Energy zero-coal 2050 plan outlines a decarbonized energy mix, aligning with Paris goals, cutting greenhouse gas emissions, driven by investor pressure, shifting to natural gas, extending nuclear power, and phasing out coal.

 

Key Points

An investor-driven scenario to end coal by 2050, shift to natural gas, extend nuclear plants, and manage climate risk.

✅ Eliminates coal from the generation mix by 2050

✅ Prioritizes natural gas transitions without CCS breakthroughs

✅ Extends nuclear plant licenses to limit carbon emissions

 

One of America’s largest utility companies, Duke Energy, is set to release a report later this month that sketches a drastically changed electricity mix in a carbon-constrained future.

The big picture: Duke is the latest energy company to commit to releasing a report about climate change in response to investor pressure, echoing shifts such as Europe's oil majors going electric across the sector, conveyed by non-binding but symbolically important shareholder resolutions. Duke provides electricity to more than seven million customers in the Carolinas, the Midwest and Florida.

Gritty details: The report is expected to find that coal, currently 33% of Duke’s mix, gone entirely from its portfolio by 2050 in a future scenario where the world has taken steps to cut greenhouse gas emissions, and where global coal-fired electricity use is falling markedly, to a level consistent with keeping global temperatures from rising two degrees Celsius. That’s the big ambition of the 2015 Paris climate deal, but the current commitments aren’t close to reaching that.

What they're saying: “What’s difficult about this is we are trying to overlay what we understand currently about technology,” Lynn Good, Duke CEO, told Axios in an interview on the sidelines of a major energy conference here.

She went on to say that this scenario of zero coal by 2050 doesn’t assume any breakthroughs in technology that captures carbon emissions from coal-fired power plants. “We don’t see that technology today, and we need to make economic decisions to get those units moving and replacing them with natural gas.”

Good also stressed the benefits of its several nuclear power plants, highlighting the role of sustaining U.S. nuclear power in decarbonization, which emit no carbon emissions. She said Duke isn’t considering investing in new nuclear plants, but plans to seek federal relicensing of current plants.

“If I turn them off, the resource that would replace them today is natural gas, so carbon will go up,” Good said. “Our objective is to continue to keep those plants as long as possible.”

What’s next: A spokesman said the other details of their 2050 scenario estimates will be available when the report is officially released by month’s end.

Axios reports that Duke Energy will release a report later this month that detail the utility's efforts to mitigate climate change risks and plan carbon-free electricity investments across its operations. The report includes a scenario that eliminates coal entirely from the company's power mix by 2050. Coal currently makes up about a third of Duke's generation.

Duke CEO Lynn Good told the news outlet the scenario ending coal-fired generation assumes no technological advances in emissions capture, seemingly leaving open the possibility.

Last year, a report by the Union of Concerned Scientists concluded one in four of the remaining operating coal-fired plants in the U.S. are slated for closure or conversion to natural gas, amid falling power-sector carbon emissions across the country. Duke's report is expected to be released by the end of the month.

Duke's report on its carbon plans comes at the behest of shareholders, a trend utility companies have seen growing among investors who are increasingly concerned about companies' sustainability and their financial exposure to climate policy.

Last year, a majority of shareholders of Pennsylvania utility PPL Corp. called on company management to publish a report on how climate change policies and technological innovations will affect the company's bottom line. Almost 60% of shareholders voted in favor of the non-binding proposal.

The vote, reportedly a first for the power sector, followed a similar decision by shareholders of Occidental Petroleum, which was supported by about 66% of shareholders.

Duke's Good told Axios that right now the utility does not see the coal technology on the horizon that would keep it operating plants. “We don't see that technology today, and we need to make economic decisions to get those units moving and replacing them with natural gas," Good said. However, it does not mean the utility is making near-term efforts to erase coal from its power mix. However, some utilities are taking those steps as they prepare for en energy landscape with more carbon regulations.

In addition to the 25% of coal plants heading for closure or conversion, the UCS report also said that another 17% of the nation’s operating coal plants are uneconomic compared with natural gas-fired generation, and could face retirement soon. But there is plenty of ongoing research into "clean coal" possibilities, and the federal government has expressed an interest in smaller, modular coal units.

 

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Alberta's electricity rebate program extended until December

Alberta Electricity Rebate Extension provides $50 monthly credits, utility bill relief, and an natural gas rebate, supporting homes, farms, and small businesses with energy costs through December 2022, capped at 250 MWh per year.

 

Key Points

A provincial program extending $50 credits and energy relief, with a natural gas rebate for eligible consumers in 2022.

✅ Up to $300 in bill credits; auto-applied to eligible accounts

✅ Applies to whole bill; limit 250 MWh/year consumption

✅ Natural gas rebate triggers above $6.50/GJ Oct-Mar 2023

 

Alberta's electricity rebate program has been extended by three months amid an electricity price spike in Alberta, and will now be in effect until the end of December, the government said.

The program was originally to provide more than 1.9 million homes, farms and small businesses with $50 monthly credits on their electricity bills, complementing a consumer price cap on power bills, for July, August and September. It will now also cover the final three months of 2022.

Those eligible for the rebate could receive up to $300 in credits until the end of December, a relief for Alberta ratepayers facing deferral costs.

The program, designed to provide relief to Albertans hit hard by high utility bills and soaring energy prices, will cost the Alberta government $600 million.

Albertans who have consumed electricity within the past calendar year, up to a maximum of 250 megawatt hours per year, are eligible for the rebates, which will be automatically applied to consumer bills, as seen in Ontario electricity bill support initiatives.

The rebates will apply to the entire bill, similar to a lump-sum credit in Newfoundland and Labrador, not just the energy portion, the government said. The rebates will be automatic and no application will be needed.

Starting October, the government will enact a natural gas rebate program until March 2023 that will kick in when prices exceed $6.50 per gigajoule, and Alberta's consumer price cap on electricity will remain in place.

 

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Quebec's electricity ambitions reopen old wounds in Newfoundland and Labrador

Quebec Churchill Falls power deal renewal spotlights Hydro-Que9bec's Labrador hydroelectricity, Churchill River contract extension, Gull Island prospects, and Innu Nation rights, as demand from EV battery manufacturing and the green economy outpaces provincial supply.

 

Key Points

Extending Quebec's low-price Churchill Falls contract to secure Labrador hydro and address Innu Nation rights.

✅ 1969 contract delivers ~30 TWh at very low fixed price.

✅ Newfoundland seeks higher rates, equity, and consultation.

✅ Innu Nation demands benefits, consent, and land remediation.

 

As Quebec prepares to ramp up electricity production to meet its ambitious economic goals, the government is trying to extend a power deal that has caused decades of resentment in Newfoundland and Labrador.

Around 15 per cent of Quebec's electricity comes from the Churchill Falls dam in Labrador, through a deal set to expire in 2041 that is widely seen as unfair. Quebec Premier François Legault not only wants to extend the agreement, he wants another dam on the Churchill River and, for now, has closed the door on nuclear power as an option to help make his province what he has called a "world leader for the green economy."

But renewing that contract "won't be easy," Normand Mousseau, scientific director of the Trottier Energy Institute at Polytechnique Montréal, said in a recent interview. Extending the Churchill Falls deal is not essential to meet Quebec's energy plans, but without it, Mousseau said, "we would have some problems."

The Legault government is enticing global companies, such as manufacturers of electric vehicle batteries, to set up shop in the province and access its hydroelectricity. But demand for Quebec's power has exceeded its supply, and Ontario has chosen not to renew a power-purchase deal with Quebec, limiting the government's vision.

Last month, Quebec's hydro utility released its strategic plan calling for a production increase of 60 terawatt hours by 2035, which represents the installed capacity of three of Hydro-Québec's largest facilities. Churchill Falls produces roughly 30 terawatt hours, and Quebec would need to replace that power if it can't strike a deal to extend the contract, Mousseau said.

If Quebec wants to keep buying power from Churchill Falls, the government is going to have to pay more, said Mousseau, who is also a physics professor at Université de Montréal. "We're paying one-fifth of a cent a kilowatt hour — that's not much," he said.

Under the 1969 contract, Quebec assumed most of the financial risk of building the Churchill Falls dam in exchange for the right to buy power at a fixed price. The deal has generated more than $28 billion for Hydro-Québec; it has returned $2 billion to Newfoundland and Labrador.

That lopsided deal has stoked anti-Quebec sentiment in Newfoundland and Labrador and contributed to nationalist politics, including threats of separation from Canada around a decade and a half ago, when Danny Williams was premier, said Jerry Bannister, a history professor at Dalhousie University.

"We tend to forget what it was like during the Williams era — he hauled down the Canadian flag," Bannister said. "There was a type of angry, combative nationalism which defined energy development. And particularly Muskrat Falls, it was payback, it was revenge."

Power from the Muskrat Falls generating station, also on the Churchill River, would be sold to Nova Scotia instead of Quebec. But that project has suffered technical problems and cost overruns since, and as of June 29, the price of Muskrat Falls had reached $13.5 billion; the province had estimated the total cost would be $7.4 billion when it sanctioned the project in 2012.

Anti-Quebec feelings may have subsided, but Bannister said the Churchill Falls deal continues to influence Newfoundland politics.

In September, Premier Andrew Furey said Legault would have to show him the money(opens in a new tab) to extend th Legault's office said Tuesday that discussions are ongoing, while the Newfoundland and Labrador government said in an emailed statement Thursday that it wants to maximize the value of its "assets and future opportunities" along the Churchill River.

Whatever negotiations are happening, Grand Chief Simon Pokue of the Innu Nation of Labrador(opens in a new tab) said he has been left out of them.

Churchill Falls flooded 6,500 square kilometres of traditional Innu land, Pokue said, adding that in response, the Innu Nation filed a $4 billion lawsuit against Hydro-Québec in 2020, which is ongoing.

"A lot of damage has been done to our lands, our land is flooded and we'll never see it again," Pokue said in a recent interview. "Nobody will ever repair that."

As well, a portion of Muskrat Falls profits was supposed to go to the Innu Nation, but the cost overruns and a refinancing deal between the federal government and Newfoundland and Labrador have limited whatever money they will see.

If Legault wants another dam on the Churchill River, at Gull Island, the Innu Nation needs to be paid the kind of money it was expecting from Muskrat Falls, he said.

"You did it once, but you're not going to do it again," Pokue said. "It's not going to start until we are consulted and involved."

Meanwhile, Quebec may face competition for Churchill Falls power, Mousseau said, with at least one Labrador mining company expressing interest in buying a significant portion of its output — though he added that the dam's capacity could be increased. The low price paid by Quebec has meant there has been little incentive to upgrade the plant's turbines.

As demand for electricity rises across the country, Mousseau said he thinks it would be better for provinces to work together, sharing expertise and costs, for example through NB Power deals to import more Quebec electricity as they look across provincial borders to find the best locations for projects, rather than acting as rivals.

"We need to talk and work with other provinces, and some propose an independent planning body to guide this, but for this you need to build confidence, and there's no confidence from the Newfoundland side with respect to Quebec," he said. "So that's a challenge: how do you work on this relationship that has been broken for 50 years?"e contract, but the two premiers have said little since.

 

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Georgia Power customers to see $21 reduction on June bills

Georgia Power June bill credit delivers PSC-approved savings, lower fuel rates, and COVID-19 relief for residential customers, driven by natural gas prices and 2018 earnings, with typical 1,000 kWh users seeing June bill reductions.

 

Key Points

A PSC-approved one-time credit and lower fuel rates reducing June bills for Georgia Power residential customers.

✅ $11.29 credit for 1,000 kWh usage on June bills

✅ Fuel rate cut saves $10.26 per month from June to September 2020

✅ PSC-approved $51.5M credit based on Georgia Power's 2018 results

 

Georgia Power announced that the typical residential customer using 1,000-kilowatt hours will receive an $11.29 credit on their June bill, reflecting a lump-sum credit model also used elsewhere.

This reflects implementation of a one-time $51.5 million credit for customers, similar to Gulf Power's bill decrease efforts, approved by the Georgia Public Service Commission, as a result of

Georgia Power's 2018 financial results.

Pairing the June credit with new, lower fuel rates recently announced, the typical residential customer would see a reduction of $21.55 in June, even as some regions face increases like Pennsylvania's winter price hikes elsewhere.

The amount each customer receives will vary based on their 2018 usage. Georgia Power will apply the credit to June bills for customers who had active accounts as of Dec. 31, 2018, and are still active or receiving a final bill as of June 2020, and the company has issued pandemic scam warnings to help customers stay informed.

Fuel rate lowered 17.2 percent

In addition to the approved one-time credit in June, the Georgia PSC recently approved Georgia Power’s plan to reduce its fuel rates by 17.2 percent and total billings by approximately $740 million over a two-year period. The implementation of a special interim reduction will provide customers additional relief during the COVID-19 pandemic through even lower fuel rates over the upcoming 2020 summer months. The lower fuel rate and special interim reduction will lower the total bill of a typical residential customer using an average of 1,000-kilowatt hours by a total of $10.26 per month from June through September 2020.

The reduction in the company’s fuel rate is driven primarily by lower natural gas prices, even as FPL proposed multiyear rate hikes in Florida, as a result of increased natural gas supplies, which the company is able to take advantage of to benefit customers due to its diverse generation sources.

February bill credit due to tax law savings

Georgia Power completed earlier this year the third and final bill credit associated with the Tax Cuts and Jobs Act of 2017, resulting in credits totaling $106 million. The typical residential customer using an average of 1,000 kilowatt-hours per month received a credit of approximately $22 on their February Georgia Power bill, a helpful offset as U.S. electric bills rose 5% in 2022 according to national data.

 

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China to build 525-MW hydropower station on Yangtze tributary

Baima Hydropower Station advances China renewable energy on the Wujiang River, a Yangtze tributary in Chongqing; a 525 MW cascade project approved by NDRC, delivering 1.76 billion kWh and improving river shipping.

 

Key Points

An NDRC-approved 525 MW project on Chongqing's Wujiang River, producing 1.76 billion kWh and improving navigation.

✅ 10.2 billion yuan investment; final cascade plant on Wujiang in Chongqing

✅ Expected output: 1.76 billion kWh; capacity 525 MW; NDRC approval

✅ Improves river shipping; relocation of 5,000 residents in Wulong

 

China plans to build a 525-MW hydropower station on the Wujiang River, a tributary of the Yangtze River, in Southwest China's Chongqing municipality, aligning with projects like the Lawa hydropower station elsewhere in the Yangtze basin.

The Baima project, the last of a cascade of hydropower stations on the section of the Wujiang River in Chongqing, has gotten the green light from the National Development and Reform Commission, China's state planning agency, even as some independent power projects elsewhere face uncertainty, such as the Siwash Creek project in British Columbia, the Chongqing Municipal Commission of Development and Reform said Monday.

The project, in Baima township of Wulong district, is expected to involve an investment of 10.2 billion yuan ($1.6 billion), as China explores compressed air generation to bolster grid flexibility, it said.

#google#

With a power-generating capacity of 525 MW, it is expected to generate 1.76 billion kwh of electricity a year, supporting efforts to reduce coal power production nationwide, and help improve the shipping service along the Wujiang River.

More than 5,000 local residents will be relocated to make room for the project, which forms part of a broader energy mix alongside advances in nuclear energy in China.

 

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Electricity Regulation With Equity & Justice For All

Energy equity in utility regulation prioritizes fair rates, clean energy access, and DERs, addressing fixed charges and energy burdens on low-income households through stakeholder engagement and public utility commission reforms.

 

Key Points

Fairly allocates clean energy benefits and rate burdens, ensuring access and protections for low-income households.

✅ Reduces fixed charges that burden low-income households

✅ Funds community participation in utility proceedings

✅ Prioritizes DERs, energy efficiency, and solar in impacted areas

 

By Kiran Julin

Pouring over the line items on your monthly electricity bill may not sound like an enticing way to spend an afternoon, but the way electricity bills are structured has a significant impact on equitable energy access and distribution. For example, fixed fees can have a disproportionate impact on low-income households. And combined with other factors, low-income households and households of color are far more likely to report losing home heating service, with evidence from pandemic power shut-offs highlighting these disparities, according to recent federal data.

Advancing Equity in Utility Regulation, a new report published by the U.S. Department of Energy’s (DOE’s) Lawrence Berkeley National Laboratory (Berkeley Lab), makes a unifying case that utilities, regulators, and stakeholders need to prioritize energy equity in the deployment of clean energy technologies and resources, aligning with a people-and-planet electricity future envisioned by advocacy groups. Equity in this context is the fair distribution of the benefits and burdens of energy production and consumption. The report outlines systemic changes needed to advance equity in electric utility regulation by providing perspectives from four organizations — Portland General Electric, a utility company; the National Consumer Law Center, a consumer advocacy organization; and the Partnership for Southern Equity and the Center for Biological Diversity, social justice and environmental organizations.
 
“While government and ratepayer-funded energy efficiency programs have made strides towards equity by enabling low-income households to access energy-efficiency measures, that has not yet extended in a major way to other clean-energy technologies,” said Lisa Schwartz, a manager and strategic advisor at Berkeley Lab and technical editor of the report. “States and utilities can take the lead to make sure the clean-energy transition does not leave behind low-income households and communities of color. Decarbonization and energy equity goals are not mutually exclusive, and in fact, they need to go hand-in-hand.”

Energy bills and electricity rates are governed by state laws and utility regulators, whose mission is to ensure that utility services are reliable, safe, and fairly priced. Public utility commissions also are increasingly recognizing equity as an important goal, tool, and metric, and some customers face major changes to electric bills as reforms advance. While states can use existing authorities to advance equity in their decision-making, several, including Illinois, Maine, Oregon, and Washington, have enacted legislation over the last couple of years to more explicitly require utility regulators to consider equity.

“The infrastructure investments that utility companies make today, and regulator decisions about what goes into electricity bills, including new rate design steps that shape customer costs, will have significant impacts for decades to come,” Schwartz said.

Solutions recommended in the report include considering energy justice goals when determining the “public interest” in regulatory decisions, allocating funding for energy justice organizations to participate in utility proceedings, supporting utility programs that increase deployment of energy efficiency and solar for low-income households, and accounting for energy inequities and access in designing electricity rates, while examining future utility revenue models as technologies evolve.

The report is part of the Future of Electric Utility Regulation series that started in 2015, led by Berkeley Lab and funded by DOE, to encourage informed discussion and debate on utility trends and tackling the toughest issues related to state electric utility regulation. An advisory group of utilities, public utility commissioners, consumer advocates, environmental and social justice organizations, and other experts provides guidance.

 

Taking stock of past and current energy inequities

One focus of the report is electricity bills. In addition to charges based on usage, electricity bills usually also have a fixed basic customer charge, which is the minimum amount a household has to pay every month to access electricity. The fixed charge varies widely, from $5 to more than $20. In recent years, utility companies have sought sizable increases in this charge to cover more costs, amid rising electricity prices in some markets.

This fixed charge means that no matter what a household does to use energy more efficiently or to conserve energy, there is always a minimum cost. Moreover, low-income households often live in older, poorly insulated housing. Current levels of public and utility funding for energy-efficiency programs fall far short of the need. The combined result is that the energy burden – or percent of income needed to keep the lights on and their homes at a healthy temperature – is far greater for lower-income households.

“While all households require basic lighting, heating, cooling, and refrigeration, low-income households must devote a greater proportion of income to maintain basic service,” explained John Howat and Jenifer Bosco from the National Consumer Law Center and co-authors of Berkeley Lab’s report. Their analysis of data from the most recent U.S. Energy Information Administration’s Residential Energy Consumption Survey shows households with income less than $20,000 reported losing home heating service at a pace more than five times higher than households with income over $80,000. Households of color were far more likely than those with a white householder to report loss of heating service. In addition, low-income households and households of color are more likely to have to choose between paying their energy bill or paying for other necessities, such as healthcare or food.

Based on the most recent data (2015) from the U.S. Energy Information Administration (EIA), households with income less than $20,000 reported losing home heating service at a rate more than five times higher than households with income over $80,000. Households of color were far more likely than those with a white householder to report loss of heating service. Click on chart for larger view. (Credit: John Howat/National Consumer Law Center, using EIA data)

Moreover, while many of the infrastructure investment decisions that utilities make, such as whether and where to build a new power plant, often have long-term environmental and health consequences, impacted communities often are not at the table. “Despite bearing an inequitable proportion of the negative impacts of environmental injustices related to fossil fuel-based energy production and climate change, marginalized communities remain virtually unrepresented in the energy planning and decision-making processes that drive energy production, distribution, and regulation,” wrote Chandra Farley, CEO of ReSolve and a co-author of the report.


Engaging impacted communities
Each of the perspectives in the report identify a need for meaningful engagement of underrepresented and disadvantaged communities in energy planning and utility decision-making. “Connecting the dots between energy, racial injustice, economic disinvestment, health disparities, and other associated equity challenges becomes a clarion call for communities that are being completely left out of the clean energy economy,” wrote Farley, who previously served as the Just Energy Director at Partnership for Southern Equity. “We must prioritize the voices and lived experiences of residents if we are to have more equity in utility regulation and equitably transform the energy sector.”

In another essay in the report, Nidhi Thaker and Jake Wise from Portland General Electric identify the importance of collaborating directly with the communities they serve. In 2021, the Oregon Legislature passed Oregon HB 2475, which allows the Oregon Public Utility Commission to allocate ratepayer funding for organizations representing people most affected by a high energy burden, enabling them to participate in utility regulatory processes.

The report explains why energy equity requires correcting inequities resulting from past and present failures as well as rethinking how we achieve future energy and decarbonization goals. “Equity in energy requires adopting an expansive definition of the ‘public interest’ that encompasses energy, climate, and environmental justice. Energy equity also means prioritizing the deployment of distributed energy resources and clean energy technologies in areas that have been hit first and worst by the existing fossil fuel economy,” wrote Jean Su, energy justice director and senior attorney at the Center for Biological Diversity.

This report was supported by DOE’s Grid Modernization Laboratory Consortium, with funding from the Office of Energy Efficiency and Renewable Energy and the Office of Electricity.

 

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