Narrowbanding issue prompts many utilities to rebuild systems

Nithi Mountain Wind Project delivers 200 MW of renewable wind power in British Columbia under a BC Hydro electricity purchase deal, producing 600 GWh yearly, led by Stellat'en First Nation and Innergex.

Key Points

A 200 MW wind farm in British Columbia producing 600 GWh yearly, co-owned by Stellat'en First Nation and Innergex.

✅ 30-year BC Hydro take-or-pay PPA, CPI-indexed

✅ 200 MW capacity, ~600 GWh per year for ~60,000 homes

✅ 51% Stellat'en First Nation; operations targeted for 2030

In December 2024, a significant development unfolded in British Columbia's renewable energy sector, where the clean-energy regulatory process continues to evolve, as Stellat'en First Nation and Innergex Renewable Energy Inc. announced the signing of a 30-year electricity purchase agreement with BC Hydro. This agreement pertains to the Nithi Mountain Wind Project, a 200 MW initiative poised to enhance the province's clean energy capacity.

Project Overview

The Nithi Mountain Wind Project is a collaborative venture between Stellat'en First Nation, which holds a 51% stake, and Innergex Renewable Energy Inc., which holds a 49% stake. Located in the Bulkley-Nechako region of British Columbia, the project is expected to generate approximately 600 GWh of renewable electricity annually, comparable to other large-scale projects like the 280 MW wind farm in Alberta now online, sufficient to power around 60,000 homes. The wind farm is scheduled to commence commercial operations in 2030.

Economic and Community Impact

This partnership is anticipated to create approximately 150 job opportunities during the development, construction, and operational phases, thereby supporting local economic growth and workforce development, and aligns with recent federal green electricity procurement efforts that signal broader market support. The long-term electricity purchase agreement with BC Hydro is structured as a 30-year take-or-pay contract, indexed to a predefined percentage of the Consumer Price Index (CPI), ensuring financial stability and protection against inflation.

Environmental and Cultural Considerations

The Nithi Mountain Wind Project is being developed in close collaboration with First Nations in the area, guided by collaborative land-use planning. The project integrates cultural preservation, environmental stewardship, and economic empowerment for Indigenous communities in the Bulkley-Nechako region, while other solutions such as tidal energy for remote communities are also advancing across Canada. The project is committed to minimizing environmental impact by avoiding sensitive cultural and ecological resources and integrating sustainability at every stage, with remediation practices to restore the land, preserve cultural values, and enhance biodiversity and wildlife habitats if decommissioned.

Broader Implications

This agreement underscores a growing trend of collaboration between Indigenous communities, exemplified by the Ermineskin First Nation project emerging nationwide, and renewable energy developers in Canada. Such partnerships are instrumental in advancing sustainable energy projects that respect Indigenous rights and contribute to the nation's clean energy objectives, as renewable power developers find that diversified energy sources strengthen project outcomes. The Nithi Mountain Wind Project exemplifies how integrating traditional knowledge with modern renewable energy technologies can lead to mutually beneficial outcomes for both Indigenous communities and the broader society.

In summary, the Nithi Mountain Wind Project represents a significant step forward in British Columbia's renewable energy landscape, highlighting the importance of collaboration between Indigenous communities and renewable energy developers. The project promises substantial economic, environmental, and cultural benefits, setting a precedent for future partnerships in the clean energy sector, as large-scale storage acquisitions like Centrica's battery project illustrate complementary pathways to unlock wind potential.

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Ontario Hydro Flat Rate sets a single electricity rate at 12.8 cents per kWh, replacing time-of-use pricing for Ontario ratepayers, affecting hydro bills this summer, alongside COVID-19 Energy Assistance Program support.

Key Points

A fixed 12.8 cents per kWh electricity price replacing time-of-use rates across Ontario from June to November.

✅ Single rate applies 24/7, replacing time-of-use pricing

✅ May slightly raise bills versus pre-pandemic usage patterns

✅ COVID-19 aid offers one-time credits for households, small firms

A new provincial COVID-19 measure, including a fixed COVID-19 hydro rate designed to give Ontario ratepayers "stability" on their hydro bills this summer, could result in slightly higher hydro costs over the next four months.

Ontario Premier Doug Ford's government announced over the weekend that consumers would be charged a single around-the-clock electricity rate between June and November, before a Nov. 1 rate increase takes effect, replacing the much-derided time-of-use model ratepayers have complained about for years.

Instead of being charged between 10 to 20 cents per kilowatt hour, depending on the time of day electricity is used, including ultra-low TOU rates during off-peak hours, hydro users will be charged a blanket rate of 12.8 cents per kWh.

"The new rate will simply show up on your bill," Premier Doug Ford said at a Monday afternoon news conference.

While the government said the new fixed rate would give customers "greater flexibility" to use their home appliances without having to wait for the cheapest rate -- and has tabled legislation to lower rates as part of its broader plan -- the new policy also effectively erases a pandemic-related hydro discount for millions of consumers.

For example, a pre-pandemic bill of $59.90 with time-of-use rates, will now cost $60.28 with the government's new recovery rate, as fixed pricing ends across the province, before delivery charges, rebates and taxes.

That same bill would have been much cheaper -- $47.57 -- if the government continued applying the lowest tier of time-of-use 24/7 under an off-peak price freeze as it had been doing since March 24.

The government also introduced support for electric bills with two new assistance programs to help customers struggling to pay their bills.

The COVID-19 Energy Assistance Program will provide a one-time payment consumers to help pay off electricity debt incurred during the pandemic -- which will cost the government $9 million.

The government will spend another $8 million to provide similar assistance to small businesses hit hard by the pandemic.

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FPL Rate Increase Proposal 2026-2029 outlines $9B base-rate hikes as Florida grows, citing residential demand, grid infrastructure investments, energy mix diversification, and Florida PSC review impacting customer bills, reliability, and fuel price volatility mitigation.

Key Points

A $9B base-rate plan FPL filed with the Florida PSC to fund growth, grid upgrades, and energy diversification through 2029.

✅ Adds 275k since 2021; +335k customers projected by 2029.

✅ Monthly bills rise to about $157 by 2029, up ~22% total.

✅ Investments in poles, wires, transformers, substations, renewables.

Florida Power & Light (FPL), the state's largest utility provider, has submitted a proposal to the Florida Public Service Commission (PSC) seeking a substantial increase in customer base rates over the next four years, amid ongoing scrutiny, including a recent hurricane surcharge controversy that heightened public attention.

Rationale Behind the Rate Increase

FPL's request is primarily influenced by Florida's robust population growth. Since 2021, the utility has added about 275,000 customers and projects an additional 335,000 by the end of 2029. This surge necessitates significant investments in transmission and distribution infrastructure, including poles, wires, transformers, and substations, to maintain reliable service. Moreover, FPL aims to diversify its energy mix to shield customers from fuel price volatility, even as the state declined federal solar incentives that could influence renewable adoption, ensuring a stable and sustainable power supply.

Impact on Customer Bills

If approved, the proposed rate increases would affect residential customers as follows:

• 2026: An estimated increase of $11.52 per month, raising the typical bill to $145.66.

• 2027: An additional $6.05 per month, bringing the bill to $151.71.

• 2028: A further increase of $3.64 per month, totaling $155.35.

• 2029: An extra $2.06 per month, resulting in a final bill of $157.41.

These adjustments represent a cumulative increase of approximately 22% over the four-year period, while in other regions some customers face sharper spikes, such as Pennsylvania's winter price increases this season.

Comparison with Previous Rate Hikes

This proposal follows a series of rate increases approved in recent years, as California electricity bills have soared and prompted calls for action in that state. For instance, Tampa Electric Co. (TECO) received approval for rate hikes totaling $287.9 million in 2025, with additional increases planned for 2026 and 2027. Consumer groups have expressed intentions to challenge these rate hikes, indicating a trend of growing scrutiny over utility rate adjustments.

Regulatory Review Process

The PSC is scheduled to review FPL's rate increase proposal in the coming months. A staff recommendation is expected by March 14, 2025, with a final decision anticipated at a commission conference on March 20, 2025. This process allows for public input and thorough evaluation of the proposed rate changes, while elsewhere some utilities anticipate stabilization, such as PG&E's 2025 outlook in California.

Customer and Consumer Advocacy Responses

The proposed rate hikes have elicited concerns from consumer advocacy groups. Organizations like Food & Water Watch have criticized the scale of the increase, labeling it as the largest rate hike request in U.S. history, amid mixed signals such as Gulf Power's one-time 40% bill decrease earlier this year. They argue that such substantial increases could place undue financial strain on households, especially those with fixed incomes.

Additionally, the Florida Public Service Commission has faced challenges in approving rate hikes for other utilities, such as TECO, and a recent Florida court decision on electricity monopolies that may influence the policy landscape, with consumer groups planning to appeal these decisions. This backdrop of heightened scrutiny suggests that FPL's proposal will undergo rigorous examination.

As Florida continues to experience rapid growth, balancing the need for infrastructure development and reliable energy services with the financial impact on consumers remains a critical challenge. The PSC's forthcoming decisions will play a pivotal role in shaping the state's energy landscape, influencing both the economy and the daily lives of Floridians.

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Alberta Ends Renewable Energy Moratorium, accelerating wind and solar deployment while prioritizing grid stability, reliability, and infrastructure upgrades to attract investment, cut emissions, meet climate targets, and integrate renewables into the provincial power system.

Key Points

It is Alberta's decision to lift a pause on new wind and solar projects while enhancing grid reliability.

✅ Resumes wind and solar development across Alberta.

✅ Focuses on grid stability and infrastructure upgrades.

✅ Aims to attract investment and meet climate targets.

The Alberta government has announced the end of a temporary suspension on the development of new renewable energy projects, as the power grid operator prepares to accept green energy bids across the market. This pause, which had been in place since May 2023, was initially implemented to evaluate the effects of rapid growth in renewable energy installations on the province's power grid and overall energy system. However, the decision to lift the moratorium reflects a shift in the government’s approach to balancing energy needs and environmental goals.

The suspension was introduced amid concerns that the swift expansion of wind and solar energy projects, including documented challenges with solar energy expansion in the province, could place undue stress on Alberta's electrical grid and infrastructure. Officials expressed worries about the ability of the grid to handle the increased load and the potential need for upgrades to accommodate new renewable energy sources. The government aimed to assess the implications of this growth and determine appropriate measures to ensure that the energy system could support both existing and future demands.

The moratorium drew significant criticism from various sectors, including renewable energy companies, environmental advocates, and local communities. Critics argued that the pause was detrimental to Alberta's efforts to transition to cleaner energy sources and meet climate targets, citing cases like TransAlta scrapping a wind farm amid policy uncertainty. They pointed out that halting projects could delay investments and job creation associated with the renewable energy sector, potentially impeding progress towards a more sustainable energy future.

In response to these concerns, the Alberta government conducted further reviews and consultations. The decision to cancel the pause reflects the government’s recognition of the importance of advancing renewable energy initiatives while also addressing the need for grid stability and infrastructure development. By ending the moratorium, the government aims to support the continued growth of renewable energy projects and maintain momentum in the shift towards greener energy solutions.

The lifting of the moratorium is expected to have a positive impact on the renewable energy industry in Alberta. Several planned projects that were put on hold can now proceed, leading to renewed investment and economic benefits, including a renewable energy surge that could power 4,500 jobs across the province. The government’s decision signals a commitment to integrating renewable energy sources into the provincial grid in a way that ensures both reliability and sustainability.

Going forward, the Alberta government plans to implement measures to better manage the integration of renewable energy into the existing power infrastructure. This includes addressing any potential challenges related to grid capacity and ensuring that the growth of renewable energy projects aligns with the province's overall energy strategy, as recent federal procurement such as a $500M green electricity contract with an Edmonton company underscores demand that integration efforts must accommodate. The goal is to create a balanced approach that supports the development of clean energy while maintaining the stability and efficiency of the energy system.

The end of the moratorium aligns with Alberta’s broader objectives to reduce greenhouse gas emissions and promote environmental sustainability within a province recognized as a powerhouse for both green energy and fossil fuels in Canada. The government’s approach reflects a willingness to adapt policies and strategies in response to evolving industry needs and environmental priorities. By removing the pause, Alberta demonstrates its commitment to fostering a diverse and resilient energy sector that can meet both current and future demands.

The decision to cancel the moratorium is also seen as a move to reinforce Alberta’s position as a leader in renewable energy development. With the lifting of restrictions, the province can continue to attract investment in clean energy projects, as neighboring jurisdictions such as B.C. streamline clean energy approvals to accelerate deployment, enhance its reputation as a progressive energy market, and contribute to global efforts to address climate change.

In summary, the Alberta government’s decision to lift the pause on renewable energy projects represents a significant shift in its approach to energy policy. The move reflects an acknowledgment of the importance of advancing renewable energy while addressing the practical challenges associated with grid management and infrastructure development. By ending the moratorium, Alberta aims to support the growth of clean energy initiatives and maintain its commitment to sustainability and environmental responsibility.

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Newfoundland and Labrador electricity rate hike examines a proposed 18.6% increase under the PUB's Rate Stabilization Plan, driven by oil prices at Holyrood, with Consumer Advocate concerns over rate shock and use of RSP balances.

Key Points

A proposed 18.6% July 2017 increase under the RSP, driven by oil prices, now under PUB review for potential mitigation.

✅ PUB flags potential rate shock from proposed adjustment

✅ RSP balances cited to offset increases without depleting fund

✅ Oil-fired Holyrood volatility drives fuel cost uncertainty

How much of a rate hike is reasonable for users of electricity in Newfoundland and Labrador?

That's a question before the Public Utilities Board (PUB) as it examines an application by Newfoundland and Labrador Hydro, which could see consumers pay up to 18.6 per cent more as of July 1, reflecting regional pressures seen in Nova Scotia, where regulators approved a 14% rate hike earlier this year.

"The estimated rate increase for July 2017 is such a significant increase that it may be argued that it would cause rate shock," said the PUB, asking the company to revise its application.

NL Hydro said the price adjustment is part of what happens every year through the Rate Stabilization Plan (RSP), which is used to offset the ups and downs of oil prices.

"The cost of fuel is volatile and as long as we rely on oil-fired generation at Holyrood, customers will continue to be impacted by this electricity price uncertainty," said the company in a statement to CBC News.

It noted that customers received a break from RSP adjustments in 2015 and 2016, even as costs from the Muskrat Falls project begin to be reflected.

The PUB noted that under the rate stabilization plan, prices have gone up or down by about 10 per cent in the past.

The regulatory board said the impact of the latest request would be a 27.6 per cent hike to Newfoundland Power, with "an estimated average end customer impact of 18.6 per cent."

Hydro's estimates are based on an average price for oil of $81.40 per barrel from July 2017 to June 2018, according to the PUB.

'Unacceptable' burden: Consumer Advocate

"To burden ratepayers with an 18 per cent rate increase is unacceptable," said Consumer Advocate Dennis Browne, echoing pushback in Nova Scotia, where the premier urged regulators to reject a 14% hike at the time.

Browne is arguing that there is money in the RSP to reduce the proposed increase, including the possibility of a lump-sum bill credit for customers.

"These ratepayer balances — which, according to NL Power, totals $77.4 million — are not the property of Hydro," he wrote in a letter to the PUB.

"No utility has the right to squirrel away ratepayers' money to be used by that utility for some future purpose. The Board has jurisdiction over those balances," Browne said.

Browne also wants the RSP overhauled so that it can be applied to price fluctuations every quarter, as opposed to annually.

Hydro has expressed concern that depleting the rate stabilization fund would lead to other, more significant, rate increases in the future.

It said several alternatives to mitigate high rates have been provided to the PUB, which has final say, similar to how Manitoba Hydro scaled back a planned increase in the next year.

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Nigeria Electricity Crisis undermines energy access as aging grid, limited generation, and transmission losses cause power outages, raising costs for businesses and public services; renewables, microgrids, and investment offer resilient, inclusive solutions.

Key Points

A nationwide power gap from weak infrastructure, low generation, and grid losses that disrupt services and growth.

✅ Aging grid and underinvestment drive frequent power outages

✅ Businesses face higher costs, lost productivity, weak competitiveness

✅ Renewables, microgrids, and regulatory reform can expand access

In Nigeria, millions of residents face persistent challenges with access to reliable electricity, a crisis that has profound implications for businesses, public services, and overall socio-economic development. This article explores the root causes of Nigeria's electricity deficit, drawing on 2021 electricity lessons to inform analysis, its impact on various sectors, and potential solutions to alleviate this pressing issue.

Challenges with Electricity Access

The issue of inadequate electricity access in Nigeria is multifaceted. The country's electricity generation capacity falls short of demand due to aging infrastructure, inadequate maintenance, and insufficient investment in power generation and distribution, a dynamic echoed when green energy supply constraints emerge elsewhere as well. As a result, many Nigerians, particularly in rural and underserved urban areas, experience frequent power outages or have limited access to electricity altogether.

Impact on Businesses

The unreliable electricity supply poses significant challenges to businesses across Nigeria. Manufacturing industries, small enterprises, and commercial establishments rely heavily on electricity to operate machinery, maintain refrigeration for perishable goods, and power essential services. Persistent power outages disrupt production schedules, increase operational costs, and, as grids prepare for new loads from electric vehicle adoption worldwide, hinder business growth and competitiveness in both domestic and international markets.

Public Services Strain

Public services, including healthcare facilities, schools, and government offices, also grapple with the consequences of Nigeria's electricity crisis. Hospitals rely on electricity to power life-saving medical equipment, maintain proper sanitation, and ensure patient comfort. Educational institutions require electricity for lighting, technological resources, and administrative functions. Without reliable power, the delivery of essential public services is compromised, impacting the quality of education, healthcare outcomes, and overall public welfare.

Socio-economic Impact

The electricity deficit in Nigeria exacerbates socio-economic disparities and hampers poverty alleviation efforts, even as debates continue over whether access alone reduces poverty in every context. Lack of access to electricity limits economic opportunities, stifles entrepreneurship, and perpetuates income inequality. Rural communities, where access to electricity is particularly limited, face greater challenges in accessing educational resources, healthcare services, and economic opportunities compared to urban counterparts.

Government Initiatives and Challenges

The Nigerian government has implemented various initiatives to address the electricity crisis, including privatization of the power sector, investment in renewable energy projects, and regulatory reforms aimed at improving efficiency and accountability, while examples like India's village electrification illustrate rapid expansion potential too. However, progress has been slow, and challenges such as corruption, bureaucratic inefficiencies, and inadequate funding continue to impede efforts to expand electricity access nationwide.

Community Resilience and Adaptation

Despite these challenges, communities and businesses in Nigeria demonstrate resilience and adaptability in navigating the electricity crisis. Some businesses invest in alternative power sources such as generators, solar panels, or hybrid systems to mitigate the impact of power outages, while utilities weigh shifts signaled by EVs' impact on utilities for future planning. Community-led initiatives, including local cooperatives and microgrids, provide decentralized electricity solutions in underserved areas, promoting self-sufficiency and resilience.

Path Forward

Addressing Nigeria's electricity crisis requires a concerted effort from government, private sector stakeholders, and international partners, informed by UK grid transformation experience as well. Key priorities include increasing investment in power infrastructure, enhancing regulatory frameworks to attract private sector participation, and promoting renewable energy deployment. Improving energy efficiency, reducing transmission losses, and expanding electricity access to underserved communities are critical steps towards achieving sustainable development goals and improving quality of life for all Nigerians.

Conclusion

The electricity crisis in Nigeria poses significant challenges to businesses, public services, and socio-economic development. Addressing these challenges requires comprehensive strategies that prioritize infrastructure investment, regulatory reform, and community empowerment. By working together to expand electricity access and promote sustainable energy solutions, Nigeria can unlock its full economic potential, improve living standards, and create opportunities for prosperity and growth across the country.

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