Does Providing Electricity To The Poor Reduce Poverty? Maybe Not


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Rural Electrification Poverty Impact examines energy access, grid connections, and reliability, testing economic development claims via randomized trials; findings show minimal gains without appliances, reliable supply, and complementary services like education and job creation initiatives.

 

Key Points

Study of household grid connections showing modest poverty impact without reliable power and appliances.

✅ Randomized grid connections showed no short-term income gains.

✅ Low reliability and few appliances limited electricity use.

✅ Complementary investments in jobs, education, health may be needed.

 

The head of Swedfund, the development finance group, recently summarized a widely-held belief: “Access to reliable electricity drives development and is essential for job creation, women’s empowerment and combating poverty.” This view has been the driving force behind a number of efforts to provide electricity to the 1.1 billion people around the world living in energy poverty, such as India's village electrification initiatives in recent years.

But does electricity really help lift households out of poverty? My co-authors and I set out to answer this question. We designed an experiment in which we first identified a sample of “under grid” households in Western Kenya—structures that were located close to but not connected to a grid. These households were then randomly divided into treatment and control groups. In the treatment group, we worked closely with the rural electrification agency to connect the households to the grid for free or at various discounts. In the control group, we made no changes. After eighteen months, we surveyed people from both groups and collected data on an assortment of outcomes, including whether they were employed outside of subsistence agriculture (the most common type of work in the region) and how many assets they owned. We even gave children basic tests, as a frequent assertion is that electricity helps children perform better in school since they are able to study at night.

When we analyzed the data, we found no differences between the treatment and control groups. The rural electrification agency had spent more than $1,000 to connect each household. Yet eighteen months later, the households we connected seemed to be no better off. Even the children’s test scores were more or less the same. The results of our experiment were discouraging, and at odds with the popular view that supplying households with access to electricity will drive economic development. Lifting people out of poverty may require a more comprehensive approach to ensure that electricity is not only affordable (with some evidence that EV growth can benefit all customers in mature markets), but is also reliable, useable, and available to the whole community, paired with other important investments.

For instance, in many low-income countries, the grid has frequent blackouts and maintenance problems, making electricity unreliable, as seen in Nigeria's electricity crisis in recent years. Even if the grid were reliable, poor households may not be able to afford the appliances that would allow for more than just lighting and cell phone charging. In our data, households barely bought any appliances and they used just 3 kilowatt-hours per month. Compare that to the U.S. average of 900 kilowatt-hours per month, a figure that could rise as EV adoption increases electricity demand over time.

There are also other factors to consider. After all, correlation does not equal causation. There is no doubt that the 1.1 billion people without power are the world’s poorest citizens. But this is not the only challenge they face. The poor may also lack running water, basic sanitation, consistent food supplies, quality education, sufficient health care, political influence, and a host of other factors that may be harder to measure but are no less important to well-being. Prioritizing investments in some of these other factors may lead to higher immediate returns. Previous work by one of my co-authors, for example, shows substantial economic gains from government spending on treatment for intestinal worms in children.

It’s possible that our results don’t generalize. They certainly don’t apply to enhancing electricity services for non-residential customers, like factories, hospitals, and schools, and electric utilities adapting to new load patterns. Perhaps the households we studied in Western Kenya are particularly poor (although measures of well-being suggest they are comparable to rural households across Sub-Saharan Africa) or politically disenfranchised. Perhaps if we had waited longer, or if we had electrified an entire region, the household impacts we measured would have been much greater. But others who have studied this question have found similar results. One study, also conducted in Western Kenya, found that subsidizing solar lamps helped families save on kerosene, but did not lead children to study more. Another study found that installing solar-powered microgrids in Indian villages resulted in no socioeconomic benefits.

 

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Is Ontario embracing clean power?

Ontario Clean Energy Expansion signals IESO-backed renewables, energy storage, and low-CO2 power to meet EV-driven demand, offset Pickering nuclear retirement, and balance interim gas-fired generation while advancing grid reliability, decarbonization, and net-zero targets.

 

Key Points

Ontario Clean Energy Expansion plans to grow renewables and storage, manage short-term gas, and meet rising demand.

✅ IESO long-term procurements for renewables and storage

✅ Interim reliance on gas to replace Pickering capacity

✅ Targets align with net-zero grid reliability goals

 

After cancelling hundreds of renewable power projects four years ago, the Doug Ford government appears set to expand clean energy to meet a looming electricity shortfall across the province.

Recent announcements from Ontario Energy Minister Todd Smith and the province’s electric grid management agency suggest the province plans to expand low-CO2 electricity with new wind and solar plans in the long-term, even as it ramps up gas-fired power over the next five years.

The moves are in response to an impending electricity shortfall as climate-conscious drivers switch to electric vehicles, farmers replace field crops with greenhouses and companies like ArcelorMittal Dofasco in Hamilton switch from CO2-heavy manufacturing to electricity-based production. Forecasters predict Canada will need to double its power supply by 2050.

While Ontario has a relatively low-CO2 power system, the province’s electricity supply will be reduced in 2025 when Ontario Power Generation closes the 50-year-old Pickering nuclear station, now near the end of its operating life. This will remove 3,100 megawatts of low-CO2 generation, about eight per cent of the province’s 40,000-megawatt total.

The impending closure has created a difficult situation for the Independent Electricity System Operator (IESO), the provincial agency managing Ontario’s grid. Last year, it forecasted it would need to sharply increase CO2-polluting natural gas-fired power to avoid widespread blackouts.

This would mean drivers switching to electric vehicles or companies like Dofasco cutting CO2 through electrification would end up causing higher power system emissions.

It would also fly in the face of the federal government’s ambition to create a net-zero national electricity system by 2035, a critical part of Canada’s pledge to reduce CO2 emissions to zero by 2050.

Yet the Ford government has appeared reluctant to expand clean energy. In the 2018 election, clean electricity was a key issue as it appealed to anti-turbine voters in rural Ontario and cancelled more than 700 renewable energy contracts shortly after taking office, taking 400 megawatts out of the system.

But there are signs the government is having a change of heart. IESO recently released a list of 55 companies approved to submit bids for 3,500 megawatts of long-term electricity contracts starting between 2025 and 2027, and the energy minister has outlined a plan to address growing energy needs as well.

The companies include a variety of potential producers, ranging from Canadian and global renewable companies to local utilities and small startups. Most are renewable power or energy storage companies specializing in low- or zero-emission power. IESO plans additional long-term bid offerings in the future.

This doesn’t mean gas generation will be turned off. IESO will contract yearly production from existing gas plants until 2028 (the annual contract in 2023 will be for about 2,000 megawatts). As well, IESO has issued contracts to four gas-fired producers, a small wind company and a storage company to begin production of about 700 megawatts to boost gas plant output starting between 2024 and 2026.

While this represents an expansion of existing gas-fired generation, Smith has asked IESO to report on a gas moratorium, saying he doesn’t believe new gas plants will be needed over the long term.

The NDP and Greens criticized the government for relying on gas in the near term. But clean energy advocates greeted the long-term plans positively.

The IESO process “will contribute to a clean, reliable and affordable grid,” said the Canadian Renewable Energy Association.

Rachel Doran, director of policy and strategy at Clean Energy Canada, said in an email the potential gas generation moratorium “is an encouraging step forward,” although she criticized the “unfortunate decision to replace near-term nuclear power capacity with climate-change-causing natural gas.”

There will have to be a massive clean energy expansion to green Ontario’s grid well beyond what has been announced in recent days for Ontario to meet its future energy needs (think a doubling of Ontario’s current 40,000-megawatt capacity by 2050).

But these first steps hold promise that Ontario is at least starting on the path to that goal, rather than scrambling to keep the lights on with CO2-polluting natural gas.

 

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US NRC streamlines licensing for advanced reactors

NRC Advanced Reactor Licensing streamlines a risk-informed, performance-based, technology-inclusive pathway for advanced non-light water reactors, aligning with NEIMA to enable predictable regulatory reviews, inherent safety, clean energy deployment, and industrial heat, hydrogen, and desalination applications.

 

Key Points

A risk-informed, performance-based NRC pathway streamlining licensing for advanced non-light water reactors.

✅ Aligned with NEIMA: risk-informed, performance-based, tech-inclusive

✅ Predictable licensing for advanced non-light water reactor designs

✅ Enables clean heat, hydrogen, desalination beyond electricity

 

The US Nuclear Regulatory Commission (NRC) voted 4-0 to approve the implementation of a more streamlined and predictable licensing pathway for advanced non-light water reactors, aligning with nuclear innovation priorities identified by industry advocates, the Nuclear Energy Institute (NEI) announced, and amid regional reliability measures such as New England emergency fuel stock plans that have drawn cost scrutiny.

This approach is consistent with the Nuclear Energy Innovation and Modernisation Act (NEIMA), a nuclear innovation act passed in 2019 by the US Congress calling for the development of a risk-informed, performance-based and technology inclusive licensing process for advanced reactor developers.

NEI Chief Nuclear Officer Doug True said: “A modernised regulatory framework is a key enabler of next-generation nuclear technologies that, amid ACORE’s challenge to DOE subsidy proposals in energy market proceedings, can help us meet our energy needs while protecting the climate. The Commission’s unanimous approval of a risk-informed and performance-based licensing framework paves the way for regulatory reviews to be aligned with the inherent safety characteristics, smaller reactor cores and simplified designs of advanced reactors.”

Over the last several years the industry’s Licensing Modernisation Project, sponsored by US Department of Energy, led by Southern Nuclear, and supported by NEI’s Advanced Reactor Regulatory Task Force, and influenced by a presidential order to bolster uranium and nuclear energy, developed the guidance for this new framework. Amid shifts in the fuel supply chain, including the U.S. ban on Russian uranium, this approach will inform the development of a new rule for licensing advanced reactors, which NEIMA requires.

“A well-defined licensing path will benefit the next generation of nuclear plants, especially as regions consider New England market overhaul efforts, which could meet a wide range of applications beyond generating electricity such as producing heat for industry, desalinating water, and making hydrogen – all without carbon emissions,” True noted.

 

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APS asks customers to conserve energy after recent blackouts in California

Arizona Energy Conservation Alert urges APS and TEP customers to curb usage during a heatwave, preventing rolling blackouts, easing peak demand, and supporting grid reliability by raising thermostats, delaying appliances, and pausing pool pumps.

 

Key Points

A utility request during extreme heat to cut demand and protect grid reliability, helping prevent outages.

✅ Raise thermostats to 80 F or higher during peak hours

✅ Delay washers, dryers, dishwashers until after 8 p.m.

✅ Pause pool pumps; switch off nonessential lights and devices

 

After excessive heat forced rolling blackouts for thousands of people across California Friday and Saturday, Arizona Public Service Electric is asking customers to conserve energy this afternoon and evening.

“Given the extended heat wave in the western United States and climate-related grid risks that utilities are monitoring, APS is asking customers to conserve energy due to extreme energy demand that is driving usage higher throughout the region with today’s high temperatures,” APS said in a statement.

Tucson Electric Power has made a similar request of customers in its coverage area.


APS is asking customers to conserve energy in the following ways Tuesday until 8 p.m.:

  • Raise thermostat settings to no lower than 80 degrees.
  • Turn off extra lights and avoid use of discretionary major appliances such as clothes washers, dryers and dishwashers.
  • Avoid operation of pool pumps.

The request from APS also came just hours after Arizona Corporation Commission Chairman Bob Burns sent a letter to electric utilities under the commission's umbrella, like APS, to see if they are in good shape or anticipate any problems given looming shortages in California. He requested the companies respond by noon Friday.


"The whole plan is to take a look at the system early in the Summer," Burns said. "Early May we look at the system, make sure we're ready and able to serve the public throughout the entire heat cycle."

Burns told ABC15 the Summer Preparedness workshop with utilities took place in May and the regulated utilities reported they were well equipped to meet the anticipated peaks of the Summer, even as supply-chain pressures mount across the industry. Tuesday's letter to the electric companies seeks to see if they are still able to "adequately, safely and reliably" serve customers through the heatwave, or if what happened in California could take place here.

"With the activities that are occurring over in California, including tight grid conditions that have repeatedly tested operators, we just want to double check," Burns said.

An APS representative told ABC15 they have adequate supply and reserve and don't anticipate any problems.

However, the rolling blackouts in California also caught the attention of Commissioner Lea Marquez Peterson. She is calling on the chairman to hold an emergency meeting amid wildfire concerns across California and the region.

"The risk to Arizonans and the fact that energy could be interrupted, that we had some kind of rolling blackout like California would have, would be really a public health issue," Peterson said. "It could be life and death in some cases for vulnerable populations."

 

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California Considers Revamping Electricity Rates in Bid to Clean the Grid

California Electricity Rate Overhaul proposes a fixed fee and lower per-kWh rates to boost electrification, renewables, and grid reliability, while CPUC weighs impacts on conservation, low-income customers, and time-of-use pricing across the state.

 

Key Points

A proposal to add fixed fees and cut per-kWh prices to drive electrification, support renewables, and balance grid costs.

✅ Fixed monthly fee plus lower volumetric per-kWh charges

✅ Aims to accelerate EVs, heat pumps, and building electrification

✅ CPUC review weighs equity, conservation, and grid reliability

 

California is contemplating a significant overhaul to its electricity rate structure that could bring major changes to electric bills statewide, a move that has ignited debate among environmentalists and politicians alike. The proposed modifications, spearheaded by the California Energy Commission (CEC), would introduce a fixed fee on electric bills and lower the rate per kilowatt-hour (kWh) used.

 

Motivations for the Change

Proponents of the plan argue that it would incentivize Californians to transition to electric appliances and vehicles, a critical aspect of the state's ambitious climate goals. They reason that a lower per-unit cost would make electricity a more attractive option for applications like home heating and transportation, which are currently dominated by natural gas and gasoline. Additionally, they believe the plan would spur investment in renewable energy sources and distributed generation, ultimately leading to a cleaner electricity grid.

California has some of the most ambitious climate goals in the country, aiming to achieve carbon neutrality by 2045. The transportation sector is the state's largest source of greenhouse gas emissions, and electrification is considered a key strategy for reducing emissions. A 2021 report by the Natural Resources Defense Council (NRDC) found that electrifying all California vehicles and buildings could reduce greenhouse gas emissions by 80% compared to 2020 levels.

 

Concerns and Potential Impacts

Opponents of the proposal, including some consumer rights groups, express apprehensions that it would discourage conservation efforts. They argue that with a lower per-kWh cost, Californians would have less motivation to reduce their electricity consumption. Additionally, they raise concerns that the income-based fixed charges could disproportionately burden low-income households, who may struggle to afford the base charge regardless of their overall electricity consumption.

A recent study by the CEC suggests that the impact on most Californians would be negligible, even as regulators face calls for action over soaring bills from ratepayers across the state. The report predicts that the average household's electricity bill would change by less than $5 per month under the proposed system. However, some critics argue that this study may not fully account for the potential behavioral changes that could result from the new rate structure.

 

Similar Initiatives and National Implications

California is not the only state exploring changes to its electricity rates to promote clean energy. Hawaii and New York have also implemented similar programs to encourage consumers to use electricity during off-peak hours. These time-varying rates, also known as time-of-use rates, can help reduce strain on the electricity grid during peak demand periods.

The California proposal has garnered national attention as other states grapple with similar challenges in balancing clean energy goals with affordability concerns amid soaring electricity prices in California and beyond. The outcome of this debate could have significant implications for the broader effort to decarbonize the U.S. power sector.

 

The Road Ahead

The California Public Utilities Commission (CPUC) is reviewing the proposal and anticipates making a decision later this year, with a potential income-based flat-fee structure under consideration. The CPUC will likely consider the plan's potential benefits and drawbacks, including its impact on greenhouse gas emissions, electricity costs for consumers, and the overall reliability of the grid, even as some lawmakers seek to overturn income-based charges in the legislature.

The decision on California's electricity rates is merely one piece of the puzzle in the fight against climate change. However, it is a significant one, with the potential to shape the state's energy landscape for years to come, including the future of residential rooftop solar markets and investments.

 

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Balancing Act: Germany's Power Sector Navigates Energy Transition

Germany January Power Mix shows gas-fired generation rising, coal steady, and nuclear phaseout impacts, amid cold weather, energy prices, industrial demand, and emissions targets shaping renewables, grid stability, and security of supply.

 

Key Points

The January electricity mix, highlighting gas, coal, renewables, and nuclear exit effects on emissions, prices, and demand.

✅ Gas output up 13% to 8.74 TWh, share at 18.6%.

✅ Coal share 23%, down year on year, steady vs late 2023.

✅ Nuclear gap filled by gas and coal; emissions below Jan 2023.

 

Germany's electricity generation in January presented a fascinating snapshot of its energy transition journey. As the country strives to move away from fossil fuels, with renewables overtaking coal and nuclear in its power mix, it grapples with the realities of replacing nuclear power and meeting fluctuating energy demands.

Gas Takes the Lead:

Gas-fired power plants saw their highest output in two years, generating 8.74 terawatt hours (TWh). This 13% increase compared to January 2023 compensated for the closure of nuclear reactors, which were extended during the energy crisis to shore up supply, and colder weather driving up heating needs. This reliance on gas, however, pushed its share in the electricity mix to 18.6%, highlighting Germany's continued dependence on fossil fuels.

Coal Fades, but Not Forgotten:

While gas surged, coal-fired generation remained below previous levels, dropping 29% from January 2023. However, it stayed relatively flat compared to late 2023, suggesting utilities haven't entirely eliminated it. Coal still held a 23% share, and periodic coal reliance remains evident, exceeding gas' contribution, reflecting its role as a reliable backup for intermittent renewable sources like wind.

Nuclear Void and its Fallout:

The shutdown of nuclear plants in April 2023 created a significant gap, previously accounting for an average of 12% of annual electricity output. This loss is being compensated through gas and coal, with gas currently the preferred choice, even as a nuclear option debate persists among policymakers. This strategy kept January's power sector emissions lower than the previous year, but rising demand could shift the balance.

Industry's Uncertain Impact:

Germany's industrial sector, a major energy consumer, is facing challenges like high energy prices and weak consumer demand. While the government aims to foster industrial recovery, uncertainties linger due to a shaky coalition and limited budget, and debate about a possible nuclear resurgence continues in parallel, which could reshape policy. Any future industrial revival would likely increase energy demand and potentially necessitate more gas or coal.

Cost-Driven Choices and Emission Concerns:

The choice between gas and coal depends on their relative costs, in a system pursuing a coal and nuclear phase-out under long-term policy. Currently, gas seems more favorable emission-wise, but if its price rises, coal might become more attractive, impacting overall emissions.

Looking Ahead:

Germany's energy transition faces a complex balancing act, with persistent grid expansion woes and exposure to cheap gas complicating progress. While the reliance on gas and coal highlights the difficulties in replacing nuclear, the focus on emissions reduction is encouraging. Navigating the challenges of affordability, industrial needs, and climate goals will be crucial for a successful transition to a clean and secure energy future.

 

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Hydro One announces pandemic relief fund for Hydro One customers

Hydro One Pandemic Relief Fund offers COVID-19 financial assistance, payment flexibility, and Winter Relief to Ontario electricity customers facing hardship, with disconnection protection and customer support to help manage bills during the health crisis.

 

Key Points

COVID-19 aid offering bill credits, payment flexibility, and disconnection protection for electricity customers.

✅ Financial assistance and bill credits for hardship cases

✅ Flexible payment plans and extended Winter Relief

✅ No-disconnect policy and dedicated customer support hours

 

We are pleased to announce a Pandemic Relief Fund to assist customers affected by the novel coronavirus (COVID-19). As part of our commitment to customers, we will offer financial assistance as well as increased payment flexibility to customers experiencing hardship. The fund is designed to support customers impacted by these events and those that may experience further impacts.

In addition to this, we've also extended our Winter Relief program, aligning with our ban on disconnections policy so no customer experiencing any hardship has to worry about potential disconnection.

We recognize that this is a difficult time for everyone and we want our customers to know that we’re here to support them. We hope this fund and the added measures, such as extended off-peak rates that help provide our customers peace of mind so they can concentrate on what matters most — keeping their loved ones safe.

If you are concerned about paying your bill, are experiencing hardship or have been impacted by the pandemic, including electricity relief announced by the province, we want to help you. Call us to discuss the fund and see what options are available for you.


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KEEPING ONTARIANS AND OUR ELECTRICITY SYSTEM SAFE
We recognize the critical role we play in powering communities across the province and our support for the Province of Ontario during COVID-19. This is a responsibility to employees, customers, businesses and the people of Ontario that we take very seriously.

Since the novel coronavirus (COVID-19) outbreak began, Hydro One’s Pandemic Team along with our leadership, have been actively monitoring the issues to ensure we can continue to deliver the service Ontarians depend on while keeping our employees, customers and the public safe, even as there has been no cut in peak hydro rates yet for self-isolating customers across Ontario. While the risk in Ontario remains low, we believe we can best protect our people and our operations by taking proactive measures.

As information continues to evolve, our leadership team along with the Pandemic Planning Team and our Emergency Operations Centre are committed to maintaining business continuity while minimizing risk to employees and communities.

Over the days and weeks to come, we will work with the sector and government, which is preparing to extend disconnect moratoriums across the province, to enhance safety protocols and champion the needs of electricity customers in Ontario.
 

 

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