Niagara power project celebrates 50 years

By Buffalo News


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"The mighty Niagara hydroelectric project sent its first power racing into Western New York" exactly 50 years ago as of February 2010, culminating the region's largest construction project and forever changing the face of the lower Niagara Gorge and igniting unending debate over the project itself, the allocation of electricity and the legacy that remains today in the Buffalo Niagara region.

The words quoted above are ones used by reporter Bob Balme on Feb. 10, 1961, to tell readers of The Buffalo Evening News, as this newspaper then was called, about what Gov. Nelson A. Rockefeller said was a "great and exciting moment in the history of the state."

The moment of euphoria was reported in a banner headline across the top of Page One of The News: "Niagara Ceremony Opens New Era" and "Giant Project Goes to Work as Governor Throws the Switch." It was supplemented by at least eight other articles and several pictures.

The governor closed a symbolic red-handled switch at 11:35 that morning to "formally put into service the largest water-driven power complex in the free world," The News reported.

Calling it a "great day," the report went on to say that "The power from the Niagara Gorge at Lewiston went into a high-voltage transmission line and onto the system of Niagara Mohawk Power Corp. Almost instantly, it was consumed in homes, farms and industries of the region."

Since that day half a century ago, the Niagara Power Project has been generating electricity not only for the region, but at times for almost all of New York State — and even for neighboring states.

Several things have changed:

* The project's two main facilities now are called the Robert Moses Niagara Power Plant and the Lewiston Pump-Generating Plant. Moses, one of the leading urban planners of the 20th century and often called the state's "master builder," was chairman of the State Power Authority, now the New York Power Authority, and head of the state parks system when the project was built. He died in 1981 at age 92.

* The original turbines have been replaced.

* Niagara Mohawk has become National Grid.

* The project has been granted a new federal license to keep it running for another 50 years.

* The debate over whether Niagara power should be allocated almost exclusively to upstate New York has waxed and waned through the years.

The story of power generation near Niagara Falls began long before the State Power Authority was created. Early industrialists dreamed of diverting some of the water from the upper Niagara River into canals around the falls, where the falling water could be used to turn waterwheels that would power their industries. The spent water then could be channeled into the Niagara Gorge.

The much lamented and only partly completed Love Canal was a remnant of that era. The Love Canal excavation later was used as an industrial dump that leaked toxic chemicals into the surrounding neighborhood, becoming one of the nation's worst environmental disasters.

The New York Power Authority begins its official chronology on June 10, 1920, when President Woodrow Wilson signed the Federal Water Power Act, authorizing the federal government to license and regulate hydropower projects.

But the real impetus for the Niagara Power Project came June 7, 1956, in a devastating rock slide when the gorge wall collapsed onto Niagara Mohawk's 60-year-old Schoellkopf Power Station, destroying the huge generating complex that had been called the world's greatest hydroelectric plant and wiping out the city's largest taxpayer.

Within months, President Dwight D. Eisenhower signed the Niagara Redevelopment Act, directing the Federal Power Commission to issue a license to the State Power Authority to build a hydroelectric project near Niagara Falls.

Construction began in 1957, and in about three years, on exactly the date that Moses had predicted, the Niagara Power Project was officially "turned on."

Thousands of workers and some of their families inundated Niagara County with their presence during the construction.

When the project produced its first power in 1961, it was the largest hydropower facility in the Western world, according to a report by the Power Authority.

"Today, Niagara is the biggest producer of electricity in New York State, generating 2.4 million kilowatts — enough power to light 24 million 100-watt bulbs at once!" according to the report.

In 2006, the Power Authority completed a $300 million upgrade of the Moses power plant in which all 13 turbines were replaced and improvements were made to generating equipment in the power dam.

Up to 375,000 gallons of water is diverted from the upper Niagara River every second. The diverted water flows through two gigantic conduits under the City of Niagara Falls and to Lewiston, where it flows through the Moses plant, spinning the turbines that power the generators that turn mechanical energy into electrical energy.

At night, when the demand for electricity is low, the 12 pump-turbines at the Lewiston Pump-Generating Plant operate as pumps transporting water from the forebay up to the huge reservoir that occupies part of what was the neighboring Tuscarora Indian Reservation. During the daytime, when the use of electricity peaks, the Lewiston pumps are reversed and become generators as the water pours out of the reservoir and through the Moses plant to produce still more electricity.

Thus, the same water is used twice to generate power before it is discharged into the lower Niagara River below the falls.

The $720 million project actually produced its first power on a somewhat trial basis Jan. 28, 1961. The formal dedication and symbolic "throwing of the switch" came about two weeks later on the campus of Niagara University, next to the water-filled forebay that connects the two plants that make up the project.

The tape-recorded voice of President John F. Kennedy told officials at the dedication ceremony, "This great power project signifies a new and more prosperous era for the Niagara Frontier and is an example to the world of North American efficiency and determination."

His predecessor, Eisenhower, said, "The mighty power of the Niagara has been harnessed for the public good, and the beauty of historic Niagara Falls has been preserved for all times."

Former President Herbert Hoover said, "It was fortunate that Gov. Thomas E. Dewey appointed [Moses] to direct the American part of this huge enterprise of partnership with Canadian Ontario Hydro. The gigantic benefits to our nation are today a reality."

Former President Harry S. Truman said, "I want to congratulate ... the people of the Niagara Frontier for this great project which will add to the general well-being of the community."

The federal license requires the Power Authority to supply municipal electric systems, rural cooperatives and even some adjoining states with low-cost electricity produced at Niagara. Power-hungry downstate areas have been trying for decades with mixed luck to siphon off some of Niagara's electricity for their own use.

In 2005, then-Gov. George E. Pataki signed sweeping economic-development legislation to continue making industries in Western New York eligible for low-cost "replacement power" from Niagara and to create a block of "preservation power" from the St. Lawrence-Franklin D. Roosevelt Project near Massena that will remain in Northern New York even if it is relinquished by the project's current industrial customers.

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DOE Announces $28M Award for Wind Energy

DOE Wind Energy Funding backs 13 R&D projects advancing offshore wind, distributed energy, and utility-scale turbines, including microgrids, battery storage, nacelle and blade testing, tall towers, and rural grid integration across the United States.

 

Key Points

DOE Wind Energy Funding is a $28M R&D effort in offshore, distributed, and utility-scale wind to lower cost and risk.

✅ $6M for rural microgrids, storage, and grid integration.

✅ $7M for offshore R&D, nacelle and long-blade testing.

✅ Up to $10M demos; $5M for tall tower technology.

 

The U.S. Department of Energy announced that in order to advance wind energy in the U.S., 13 projects have been selected to receive $28 million. Project topics focus on technology development while covering distributed, offshore wind growth and utility-scale wind found on land.

The selections were announced by the DOE’s Assistant Secretary for the Office of Energy Efficiency and Renewable Energy, Daniel R. Simmons, at the American Wind Energy Association Offshore Windpower Conference in Boston, as New York's offshore project momentum grows nationwide.

 

Wind Project Awards

According to the DOE, four Wind Innovations for Rural Economic Development projects will receive a total of $6 million to go toward supporting rural utilities via facilitating research drawing on U.K. wind lessons for deployment that will allow wind projects to integrate with other distributed energy resources.

These endeavors include:

Bergey WindPower (Norman, Oklahoma) working on developing a standardized distributed wind/battery/generator micro-grid system for rural utilities;

Electric Power Research Institute (Palo Alto, California) working on developing modeling and operations for wind energy and battery storage technologies, as large-scale projects in New York progress, that can both help boost wind energy and facilitate rural grid stability;

Iowa State University (Ames, Iowa) working on optimization models and control algorithms to help rural utilities balance wind and other energy resources; and

The National Rural Electric Cooperative Association (Arlington, Virginia) providing the development of standardized wind engineering options to help rural-area adoption of wind.

Another six projects are to receive a total of $7 million to facilitate research and development in offshore wind, as New York site investigations advance, with these projects including:

Clemson University (North Charleston, South Carolina) improving offshore-scale wind turbine nacelle testing via a “hardware-in-the-loop capability enabling concurrent mechanical, electrical and controller testing on the 7.5-megawatt dynamometer at its Wind Turbine Drivetrain Testing Facility to accelerate 1 GW on the grid progress”; and

The Massachusetts Clean Energy Center (Boston) upgrading its Wind Technology Testing Center to facilitate structural testing of 85- to 120-meter-long (roughly 278- to 393-foot-long) blades, as BOEM lease requests expand, among other projects.

Additionally, two offshore wind technology demonstration projects will receive up to $10 million for developing initiatives connected to reducing wind energy risk and cost. One last project will also be granted $5 million for the development of tall tower technology that can help overcome restrictions associated with transportation.

“These projects will be instrumental in driving down technology costs and increasing consumer options for wind across the United States as part of our comprehensive energy portfolio,” said Simmons.

 

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Why Canada should invest in "macrogrids" for greener, more reliable electricity

Canadian electricity transmission enables grid resilience, long-distance power trade, and decarbonization by integrating renewables, hydroelectric storage, and HVDC links, providing backup during extreme weather and lowering costs to reach net-zero, clean energy targets.

 

Key Points

An interprovincial high-voltage grid that shares clean power to deliver reliable, low-cost decarbonization.

✅ Enables resilience by sharing power across weather zones

✅ Integrates renewables with hydro storage via HVDC links

✅ Lowers decarbonization costs through interprovincial trade

 

As the recent disaster in Texas showed, climate change requires electricity utilities to prepare for extreme events. This “global weirding” is leaving Canadian electricity grids increasingly exposed to harsh weather that leads to more intense storms, higher wind speeds, heatwaves and droughts that can threaten the performance of electricity systems.

The electricity sector must adapt to this changing climate while also playing a central role in mitigating climate change. Greenhouse gas emissions can be reduced a number of ways, but the electricity sector is expected to play a central role in decarbonization, including powering a net-zero grid by 2050 across Canada. Zero-emissions electricity can be used to electrify transportation, heating and industry and help achieve emissions reduction in these sectors.

Enhancing long-distance transmission is viewed as a cost-effective way to enable a clean and reliable power grid, and to lower the cost of meeting our climate targets. Now is the time to strengthen transmission links in Canada, with concepts like a western Canadian electricity grid gaining traction.


Insurance for climate extremes
An early lesson from the Texas power outages is that extreme conditions can lead to failures across all forms of power supply. The state lost the capacity to generate electricity from natural gas, coal, nuclear and wind simultaneously. But it also lacked cross-border transmission to other electricity systems that could have bolstered supply.

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Long-distance transmission offers the opportunity to escape the correlative clutch of extreme weather, by accessing energy and spare capacity in areas not beset by the same weather patterns. For example, while Texas was in its deep freeze, relatively balmy conditions in California meant there was a surplus of electricity generation capability in that region — but no means to get it to Texas. Building new transmission lines and connections across broader regions, including projects like a hydropower line to New York that expand access, can act as an insurance policy, providing a back-up for regions hit by the crippling effects of climate change.

A transmission tower crumpled under the weight of ice.
The 1998 Quebec ice storm left 3.5 million Quebecers and a million Ontarians, as well as thousands in in New Brunswick, without power. CP Photo/Robert Galbraith
Transmission is also vulnerable to climate disruptions, such as crippling ice storms that leave wires temporarily inoperable. This may mean using stronger poles when building transmission, or burying major high-voltage transmission links, or deploying superconducting cables to reduce losses.

In any event, more transmission links between regions can improve resilience by co-ordinating supply across larger regions. Well-connected grids that are larger than the areas disrupted by weather systems can be more resilient to climate extremes.


Lowering the cost of clean power
Adding more transmission can also play a role in mitigating climate change. Numerous studies have found that building a larger transmission grid allows for greater shares of renewables onto the grid, ultimately lowering the overall cost of electricity.

In a recent study, two of us looked at the role transmission could play in lowering greenhouse gas emissions in Canada’s electricity sector. We found the cost of reducing greenhouse gas emissions is lower when new or enhanced transmission links can be built between provinces.

Average cost increase to electricity in Canada at different levels of decarbonization, with new transmission (black) and without new transmission (red). New transmission lowers the cost of reducing greenhouse gas emissions. (Authors), Author provided
Much of the value of transmission in these scenarios comes from linking high-quality wind and solar resources with flexible zero-emission generation that can produce electricity on demand. In Canada, our system is dominated by hydroelectricity, but most of this hydro capacity is located in five provinces: British Columbia, Manitoba, Ontario, Québec and Newfoundland and Labrador.

In the west, Alberta and Saskatchewan are great locations for building low-cost wind and solar farms. Enhanced interprovincial transmission would allow Alberta and Saskatchewan to build more variable wind and solar, with the assurance that they could receive backup power from B.C. and Manitoba when the wind isn’t blowing and the sun isn’t shining.

When wind and solar are plentiful, the flow of low cost energy can reverse to allow B.C. and Manitoba the opportunity to better manage their hydro reservoir levels. Provinces can only benefit from trading with each other if we have the infrastructure to make that trade possible.

A recent working paper examined the role that new transmission links could play in decarbonizing the B.C. and Alberta electricity systems. We again found that enabling greater electricity trade between B.C. and Alberta can reduce the cost of deep cuts to greenhouse gas emissions by billions of dollars a year. Although we focused on the value of the Site C project, in the context of B.C.'s clean energy shift, the analysis showed that new transmission would offer benefits of much greater value than a single hydroelectric project.

The value of enabling new transmission links between Alberta and B.C. as greenhouse gas emissions reductions are pursued. (Authors), Author provided
Getting transmission built
With the benefits that enhanced electricity transmission links can provide, one might think new projects would be a slam dunk. But there are barriers to getting projects built.

First, electricity grids in Canada are managed at the provincial level, most often by Crown corporations. Decisions by the Crowns are influenced not simply by economics, but also by political considerations. If a transmission project enables greater imports of electricity to Saskatchewan from Manitoba, it raises a flag about lost economic development opportunity within Saskatchewan. Successful transmission agreements need to ensure a two-way flow of benefits.

Second, transmission can be expensive. On this front, the Canadian government could open up the purse strings to fund new transmission links between provinces. It has already shown a willingness to do so.

Lastly, transmission lines are long linear projects, not unlike pipelines. Siting transmission lines can be contentious, even when they are delivering zero-emissions electricity. Using infrastructure corridors, such as existing railway right of ways or the proposed Canadian Northern Corridor, could help better facilitate co-operation between regions and reduce the risks of siting transmission lines.

If Canada can address these barriers to transmission, we should find ourselves in an advantageous position, where we are more resilient to climate extremes and have achieved a lower-cost, zero-emissions electricity grid.

 

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

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

 

Key Points

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

✅ Alleged failure to maintain transmission infrastructure

✅ Spark reports and regulator filings before blaze erupted

✅ Class action parallels with Australia's Black Saturday

 

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

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

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

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

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

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

 

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PG&E's bankruptcy plan wins support from wildfire victims

PG&E Bankruptcy Plan outlines wildfire victims compensation via a $13.5B trust funded by cash and stock, aiming CPUC and court approval before June 30 to access the state wildfire insurance fund and finalize settlement.

 

Key Points

A regulator-approved plan funding a $13.5B wildfire victims trust with cash and PG&E stock to exit bankruptcy.

✅ $13.5B trust split between cash and PG&E shares

✅ Targets CPUC and court approval to meet June 30 deadline

✅ Accesses state wildfire insurance fund for future risks

 

Pacific Gas & Electric's plan for getting out of bankruptcy has won overwhelming support from the victims of deadly Northern California wildfires ignited by the utility's fraying electrical grid, while some have pursued mega-fire lawsuits through the courts as well, despite concerns that they will be shortchanged by a $13.5 billion fund that's supposed to cover their losses.

The company announced the preliminary results of the vote on Monday without providing a specific tally. Those numbers are supposed to be filed with U.S. Bankruptcy Judge Dennis Montali by Friday.

The backing of the wildfire victims keeps PG&E on track to meet a June 30 deadline to emerge from bankruptcy in time to qualify for a coverage from a California wildfire insurance fund created to help protect the utility from getting into financial trouble again.

The current bankruptcy case, which began early last year, will require PG&E to pay out about $25.5 billion to cover the devastation caused by its neglect, including a Camp Fire guilty plea that underscored liabilities in court proceedings. It's the second time in less than 20 years that PG&E has filed for bankruptcy.

The backing for PG&E's plan isn't a surprise, even though some of the roughly 80,000 wildfire victims had been trying to rally resistance to what they consider to be a deeply flawed plan. The misgivings mostly center on the massive debt that the utility will take on to finance the plan and uncertainties about the fluctuating value of the $6.75 billion in company stock that comprises half of the $13.5 billion promised them.

As it became apparent that the COVID-19 pandemic would drive the economy into a deep recession, PG&E's shares plunged along with the rest of the stock market during March, even as it announced pandemic response measures for customers and employees during that period. That led one financial expert to estimate the PG&E stock earmarked for the wildfire victims' trust would be worth only $4.85 billion, a nearly 30% markdown.

But PG&E's stock price has rebounded in recent weeks and it's now worth more than it was when the deal setting up the victims' trust was struck last December. The shares surged more than 8% to $12.28 in Monday's late afternoon trading. The stock stood at $9.65 when PG&E reached its settlement the wildfire victims.

Critics of the utility's plan also are upset because the company still hasn't specified when the fire victims will be able to sell the shares. It now seems likely the victims will have to hold the stock through the upcoming wildfire season in Northern California, raising the specter that another calamity caused by the utility's badly outdated equipment, as power line fire reports have underscored, could cause the shares to plummet before they can cash out.

A petition signed by more than 3,100 wildfire victims recently urged Gov. Gavin Newsom to consider pushing back the deadline for qualifying for the state's wildfire from June 30 to late August to allow for more time to revise PG&E's plan, as many also turn to a wildfire assistance program for interim aid while they wait. Newsom's office hasn't responded to inquiry about the plan from The Associated Press.

But the lawyers representing the wildfire victims advised their clients to vote in favor of PG&E's plan, contending that it's the best deal they are going to get.

PG&E still must get its plan approved by the judge supervising its case, and a recent judge order on dividend use underscores the focus on wildfire mitigation. The confirmation hearings are scheduled to begin May 27. The judge, though, has indicated he will give great weight to the wishes of the wildfire victims.

California state regulators also must approve PG&E's plan, amid projections that rates will stabilize in 2025 for customers. A vote on that is scheduled Thursday before the Public Utilities Commission.

 

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U.S. offshore wind power about to soar

US Offshore Wind Lease Sales signal soaring renewable energy growth, drawing oil and gas developers, requiring BOEM auctions, seismic surveying, transmission planning, with $70B investment, 8 GW milestones, and substantial job creation in coastal communities.

 

Key Points

BOEM-run auctions granting areas for offshore wind, spurring projects, investment, and jobs in federal waters.

✅ $70B investment needed by 2030 to meet current demand

✅ 8 GW early buildout could create 40,000 US jobs

✅ Requires BOEM auctions, seismic surveying, transmission corridors

 

Recent offshore lease sales demonstrate that not only has offshore wind arrived in the U.S., but it is clearly set to soar, as forecasts point to a $1 trillion global market in the coming decades. The level of participation today, especially from seasoned offshore oil and gas developers, exemplifies that the offshore industry is an advocate for the 'all of the above' energy portfolio.

Offshore wind could generate 160,000 direct, indirect and induced jobs, with 40,000 new U.S. jobs with the first 8 gigawatts of production, while broader forecasts see a quarter-million U.S. wind jobs within four years.

In fact, a recent report from the Special Initiative on Offshore Wind (SIOW), said that offshore wind investment in U.S. waters will require $70 billion by 2030 just based on current demand, and the UK's rapid scale-up offers a relevant benchmark.

Maintaining this tremendous level of interest from offshore wind developers requires a reliable inventory of regularly scheduled offshore wind sales and the ability to develop those resources. Coastal communities and extreme environmental groups opposing seismic surveying and the issuance of incidental harassment authorizations under the Marine Mammal Protection Act may literally take the wind out of these sales. Just as it is for offshore oil and gas development, seismic surveying is vital for offshore wind development, specifically in the siting of wind turbines and transmission corridors.

Unfortunately, a long-term pipeline of wind lease sales does not currently exist. In fact, with the exception of a sale proposed offshore New York offshore wind or potentially California in 2020, there aren't any future lease sales scheduled, leaving nothing upon which developers can plan future investments and prompting questions about when 1 GW will be on the grid nationwide.

NOIA is dedicated to working with the Bureau of Ocean Energy Management and coastal communities, consumers, energy producers and other stakeholders, drawing on U.K. wind lessons where applicable, in working through these challenges to make offshore wind a reality for millions of Americans.

 

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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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