Westar rate hearing dates draw criticism

West and Central Africa Electricity Access hinges on utility reform, renewable energy, off-grid solar, mini-grids, battery storage, and regional grid integration, lowering costs, curbing energy poverty, and advancing SDG7 with sustainable, reliable power solutions.

Key Points

Expanding reliable power via renewables, grid trade, and off-grid systems to cut energy poverty and unlock inclusive growth.

✅ Utility reform lowers costs and improves service reliability

✅ Regional grid integration enables clean, least-cost power trade

✅ Off-grid solar and mini-grids electrify remote communities

As commodity prices soar and leaders around the world worry about energy shortages and prices of gasoline at the pump, millions of people in Africa still lack access to electricity.  One-half of the people on the continent cannot turn on a fan when temperatures go up, can’t keep food cool, or simply turn the lights on. This energy access crisis must be addressed urgently.

In West and Central Africa, only three countries are on track to give every one of their people access to electricity by 2030. At this slow pace, 263 million people in the region will be left without electricity in ten years.  West Africa has one of the lowest rates of electricity access in the world; only about 42% of the total population, and 8% of rural residents, have access to electricity.

These numbers, some far too big, others far too small, have grave consequences. Electricity is an important step toward enhancing people’s opportunities and choices. Access is key to boosting economic activity and contributes to improving human capital, which, in turn, is an investment in a country’s potential.  

Without electricity, children can’t do their schoolwork at night. Businesspeople can’t get information on markets or trade with each other. Worse, as the COVID-19 pandemic has shown so starkly, limited access to energy constrains hospital and emergency services, further endangering patients and spoiling precious medicine.  

What will it take to power West and Central Africa?  
As the African continent recovers from COVID-19 impacts, now is the critical time to accelerate progress towards universal energy access to drive the region’s economic transformation, promote socio-economic inclusion, and unlock human capital growth. Without reliable access to electricity, the holes in a country’s social fabric can grow bigger, those without access growing disenchanted with inequality.  

Tackling the Africa region’s energy access crisis requires four bold approaches. 

First, this involves making utilities financially viable. Many power providers in the region are cash-strapped, operate dilapidated and aging generation fleet and infrastructure. Therefore, they can’t deliver reliable and affordable electricity to their customers, let alone deliver electricity to those that currently must rely on inadequate alternatives to electricity. Overall, fewer than half of the utilities in Sub-Saharan Africa recover their operating costs, resulting in GDP losses as high as four percent in some countries.

Improving the performance of national utilities and greening their power generation mix is a prerequisite to lowering the costs of supply, thus expanding electricity access to those currently unelectrified, usually lower-income and often remote households. 

In that effort — and this a critical second point — West and Central African countries need to look beyond their borders and further integrate their national utilities and grids to other systems in the region. The region has an abundance of affordable clean energy sources — hydropower in Guinea, Mali, and Cote d’Ivoire; high solar irradiation in the Sahel — but the regional energy market is fragmented. 

Without efficient regional trade, many countries are highly dependent on one or two energy resources and heavily reliant on inefficient, polluting generation sources, requiring fuel imports linked to volatile international oil prices.

The vision of an integrated regional power market in countries of the Economic Community of West African States (ECOWAS) is coming a step closer to reality thanks to an ambitious program of cross-border interconnection projects. If countries take full advantage of this grid, the share of the region’s electricity consumption traded across borders would more than double from 8 percent today to about 17 percent by 2030. Overall, regional power trade could lower the lifecycle cost of West Africa’s power generation system by about 10 percent and provide greener energy by 2030. 

Third, electrification efforts need to be open to private sector investments and innovations, such as renewables like solar energy and battery storage, which have made a tremendous impact in enabling access for millions of poor and underserved households.  Specifically, off-grid solar systems and mini-grids have become a proven reliable way to provide affordable modern electricity services, powering homes in rural communities, healthcare facilities, and schools.

Burkina Faso, which enjoys one of the best solar radiation conditions in the region, is a successful example of leveraging the transformative impact of solar energy and battery storage. With support from the World Bank, the country is deploying solar energy to power its national grid, as well as mini-grids and individual household systems. Solar power with battery storage is competitive in Burkina Faso compared to other technologies and its government was successful in attracting private sector investments to support this technology.

Last, achieving universal electricity access will involve significant commitment from political leaders, especially developing policies and regulations that can attract high-quality investments.  

A significant step in that direction was achieved at the World Bank’s 2020 Annual Meetings with a commitment to set up the Powering Transformation Platform in each African country. Through the platform, each government will set their country-specific vision, goals and metrics, track progress, and explore and exchange innovative ideas and emerging best practices according to their own national energy needs and plans. 

This platform will bring together the elements needed to bring electricity to all in West and Central Africa and help attract new financing.

Over the last 3 years, the World Bank has doubled its investments to increase electricity access rates in Central and West Africa.  We have committed more than $7.8 billion to support 40 electricity access programs, of which more than half directly support new electricity connections. These operations are expected to provide access to 16 million people. The aim is to increase electricity access rates in West and Central Africa from 50 percent today to 64 percent by 2026.

However, World Bank’s financing alone is not enough. Our estimates show that nearly $20 billion are required for universal electrification across Sub-Saharan Africa, aligning with calls to quadruple power investment to meet demand, with about $10 billion annually needed for West and Central Africa. 

Closing the funding gap will require mobilizing traditional and new partners, especially the private sector, which is willing to invest if enabling conditions are in place, as well as philanthropic capital, that can fill in the space in areas not yet commercially attractive. The World Bank is ready to play a catalytical role in leveraging new investments. 

This is vital as less than a decade remains to reach the 2030 SDG7 goal of ensuring electricity for all through affordable, reliable, and modern energy services. As headlines worldwide focus on soaring energy prices in the developed world, we cannot lose sight of the vast populations in Africa that still cannot access basic energy services. This is the true global energy crisis.  

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IEC-PETL Electricity Agreement streamlines grid management, debt settlement, and bank guarantees, shifting power supply, transmission, and distribution to PETL via IEC-built sub-stations, bolstering energy cooperation, utility billing, and payment assurance in PA areas.

Key Points

A 15-year deal transferring PA grid operations to PETL, settling legacy debt, and securing payments with bank guarantees.

✅ NIS 915 million repaid in 48 installments.

✅ PETL assumes distribution, O&M, and sub-station ownership.

✅ 15-year, NIS 2.8b per year supply and services contract.

The Palestinian Authority will pay Israel Electric NIS 915 million and take over management of its grid through Palestinian electricity supplier PETL.

The Israel Electric Corporation (IEC) (TASE: ELEC.B22) and Palestinian electricity supplier PETL have signed a draft commercial agreement under which the Palestinian Authority's (PA) debt of almost NIS 1 billion will be repaid. The agreement also transfers actual management of the supply of electricity to Palestinian customers from IEC to the Palestinian electricity authority, enabling consideration of distributed solutions such as a virtual power plant program in future planning.

Up until now, the IEC was unable to actually collect debts for electricity from Palestinian customers, because the connection with them was through the PA. Responsibility for collection will now be exclusively in Palestinian hands, with the PA providing hundreds of millions of shekels in bank guarantees for future debts. The agreement, which is valid for 15 years, amounts to an estimated NIS 2.8 billion a year, as of now.

IEC will sell electricity and related services to PETL through four high-tension sub-stations built by IEC for PETL and through high and low-tension connection points, similar to large interconnector projects like the Lake Erie Connector, for the purpose of distribution and supply of the electricity by PETL or an entity on its behalf to consumers in PA territory. PETL will have sole operational and maintenance responsibility for distribution and supply and ownership of the four sub-stations.

NIS 915 million in 48 payments

According to the IEC announcement, the settlement was reached following negotiations following the signing of an agreement in principle in September 2016 by the minister of finance, the government coordinator of activities in the territories, and the Palestinian minister for civilian affairs. The parties reached commercial understandings yesterday that made possible today's signing of the first commercial document of its kind regulating commercial relations - the sales of electricity - between the parties. The agreement will go into effect after it is approved by the IEC board of directors, the Public Utilities Authority (electricity), reflecting regulatory oversight akin to Ontario industrial electricity pricing consultations, and the IDF Chief Electrical Staff Officer. Representatives of IEC, the Ministry of Finance, the Public Utilities Authority (electricity), the government coordinator of activities in the territories, the civilian authority, the PA government, and PETL took part in the negotiations.

The agreement also settles the PA's historical debt to IEC. The PA will begin payment of NIS 915 million in debt for consumption of electricity before September 2016 to IEC Jerusalem District Ltd. in 48 equal installments after the final signing, as stipulated in the agreement in principle signed by the Israeli government and the PA on September 13, 2016.

The PA's debt for electricity amounted to almost NIS 2 billion in 2016. The initial spadework for the current debt settlement was accomplished in that year, after the parties reached understandings on writing off NIS 500 million of the Palestinian debt. The PA paid NIS 600 million in October 2016, and the remainder will be paid now.

It was also reported that an arrangement of securities and guarantees to ensure payment to IEC under the agreement had been settled, including the past debt. IEC will obtain a bank guarantee and a PA guarantee, in addition to the existing collection mechanisms at the company's disposal.

Minister of Finance Moshe Kahlon said, "Signing the commercial agreement is a historic step completing the agreement signed by the governments in September 2016. Strengthening economic cooperation between Israel and the PA is above all an Israeli security interest. The agreement will ensure future payments to the IEC and reinforce its financial position. I congratulate the negotiating teams for the completion of their task."

Minister of National Infrastructure, Energy, and Water Resources Dr. Yuval Steinitz said, "In my meeting last year with Palestinian Prime Minister Rami Hamdallah in Jenin, we agreed that it was necessary to settle the debt and formalize relations between IEC and the PA. The settlement signed today is a breakthrough, both in the measures for payment of the Palestinian debt to IEC and Israel and in arranging future relations to prevent more debts from emerging in the future. With the signing of the agreement, we will be able to make progress with the Palestinians in developing a modern electrical grid, aligning with regional initiatives like the Cyprus electricity highway, according to the model of the sub-station we inaugurated in Jenin."

IEC chairperson Yiftah Ron Tal said, "This is a historic event. In this agreement, IEC is correcting for the first time a historical distortion of accumulated debt without guarantees, ability to collect it, or control over the amount of debt. This anchor agreement not only constitutes an unprecedented financial achievement; it also constitutes an important milestone in regulating electricity commercial relations between the Israeli and Palestinian electric companies, comparable to cross-border efforts such as the Ireland-France interconnector in Europe."

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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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Germany Solar-Plus-Storage Cost Parity signals grid parity as solar power with battery storage undercuts conventional electricity. Falling LCOE, policy incentives, and economies of scale accelerate the energy transition and decarbonization across Germany's power market.

Key Points

The point at which solar power with battery storage is cheaper than conventional grid electricity across Germany.

✅ Lower LCOE from tech advances and economies of scale

✅ EEG incentives and streamlined installs cut total costs

✅ Enhances energy security, reduces fossil fuel dependence

Germany, a global leader in renewable energy adoption, with clean energy supplying about half of its electricity in recent years, has reached a significant milestone: the cost of solar power combined with battery storage has now fallen below that of conventional electricity sources. This development marks a transformative shift in the energy landscape, showcasing the increasing affordability and competitiveness of renewable energy technologies and reinforcing Germany’s position as a pioneer in the transition to sustainable energy.

The decline in costs for solar power paired with battery storage represents a breakthrough in Germany’s energy sector, especially amid the recent solar power boost during the energy crisis, where the transition from traditional fossil fuels to cleaner alternatives has been a central focus. Historically, conventional power sources such as coal, natural gas, and nuclear energy have dominated electricity markets due to their established infrastructure and relatively stable pricing. However, the rapid advancements in solar technology and energy storage solutions are altering this dynamic, making renewable energy not only environmentally preferable but also economically advantageous.

Several factors contribute to the cost reduction of solar power with battery storage:

1. Technological Advancements: The technology behind solar panels and battery storage systems has evolved significantly over recent years. Solar panel efficiency has improved, allowing for greater energy generation from smaller installations. Similarly, cheaper batteries have advanced, with reductions in cost and increases in energy density and lifespan. These improvements mean that solar installations can produce more electricity and store it more effectively, enhancing their economic viability.

2. Economies of Scale: As demand for solar and battery storage systems has grown, manufacturers have scaled up production, leading to economies of scale. This scaling has driven down the cost of both solar panels and batteries, making them more affordable for consumers. As the market for these technologies expands, prices are expected to continue decreasing, further enhancing their competitiveness.

3. Government Incentives and Policies: Germany’s commitment to renewable energy has been supported by robust government policies and incentives. The country’s Renewable Energy Sources Act (EEG) and other supportive measures, alongside efforts to remove barriers to PV in Berlin that could accelerate adoption, have provided financial incentives for the adoption of solar power and battery storage. These policies have encouraged investment in renewable technologies and facilitated their integration into the energy market, contributing to the overall reduction in costs.

4. Falling Installation Costs: The cost of installing solar power systems and battery storage has decreased as the industry has matured. Advances in installation techniques, increased competition among service providers, and streamlined permitting processes have all contributed to lower installation costs. This reduction in upfront expenses has made solar with battery storage more accessible and financially attractive to both residential and commercial consumers.

The economic benefits of solar power with battery storage becoming cheaper than conventional power are substantial. For consumers, this shift translates into lower electricity bills and reduced reliance on fossil fuels. Solar installations with battery storage allow households and businesses to generate their own electricity, store it for use during times of low sunlight, and even sell excess power back to the grid, reflecting how solar is reshaping electricity prices in Northern Europe as markets adapt. This self-sufficiency reduces exposure to fluctuating energy prices and enhances energy security.

For the broader energy market, the decreasing cost of solar power with battery storage challenges the dominance of conventional power sources. As renewable energy becomes more cost-effective, it creates pressure on traditional energy providers to adapt and invest in cleaner technologies, including responses to instances of negative electricity prices during renewable surpluses. This shift can accelerate the transition to a low-carbon energy system and contribute to the reduction of greenhouse gas emissions.

Germany’s achievement also has implications for global energy markets. The country’s success in making solar with battery storage cheaper than conventional power serves as a model for other nations pursuing similar energy transitions. As the cost of renewable technologies continues to decline, other countries can leverage these advancements to enhance their own energy systems, reduce carbon emissions, and achieve energy independence amid over 30% of global electricity now from renewables trends worldwide.

The impact of this development extends beyond economics. It represents a significant step forward in addressing climate change and promoting sustainability. By reducing the cost of renewable energy technologies, Germany is accelerating the shift towards a cleaner and more resilient energy system. This progress aligns with the country’s ambitious climate goals and reinforces its role as a leader in global efforts to combat climate change.

Looking ahead, several challenges remain. The integration of renewable energy into existing energy infrastructure, grid stability, and the management of energy storage are all areas that require continued innovation and investment. However, the decreasing cost of solar power with battery storage provides a strong foundation for addressing these challenges and advancing the transition to a sustainable energy future.

In conclusion, the fact that solar power with battery storage in Germany has become cheaper than conventional power is a groundbreaking development with wide-ranging implications. It underscores the technological advancements, economic benefits, and environmental gains associated with renewable energy technologies. As Germany continues to lead the way in clean energy adoption, this achievement highlights the potential for renewable energy to drive global change and reshape the future of energy.

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Commercial Electric Tariffs explain utility rate structures, peak demand charges, kWh vs kW pricing, time-of-use periods, voltage, delivery, capacity ratchets, and riders, guiding facility managers in tariff analysis for accurate energy savings.

Key Points

Commercial electric tariffs define utility pricing for energy, demand, delivery, time-of-use periods, riders, and ratchet charges.

✅ Separate kWh charges from kW peak demand fees.

✅ Verify time-of-use windows and demand interval length.

✅ Review riders, capacity ratchets, and minimum demand clauses.

Especially during these tough economic times, as major changes to electric bills are debated in some states, facility executives who don’t understand how their power is priced have been disappointed when their energy projects failed to produce expected dollar savings. Here’s how not to be one of them.

Your electric rate is spelled out in a document called a “tariff” that can be downloaded from your utility’s web page. A tariff should clearly spell out the costs for each component that is part of your rate, reflecting cost allocation practices in your region. Don’t be surprised to learn that it contains a bunch of them. Unlike residential electric rates, commercial electric bills are not based solely on the quantity of kilowatt-hours (kWh) consumed in a billing period (in the United States, that’s a month). Instead, different rates may apply to how your power is supplied, how it is delivered via electricity delivery charges, when it was consumed, its voltage, how fast it was used (in kW), and other factors.

If a tariff’s lingo and word structure are too opaque, spend some time with a utility account rep to translate it. Many state utility commissions also have customer advocates that may assist as they explore new utility rate designs that affect customers. Alternatively, for a fee, facility managers can privately chat with an energy consultant.

Common mistakes

Many facility managers try to estimate savings based on an averaged electric rate, i.e., annual electric spend divided by annual kWh. However, in markets where electricity demand is flat, such a number may obscure the fastest rising cost component: monthly peak demand charges, measured in dollars per kW (or kilo-volt-amperes, kVA).

This charge is like a monthly speeding ticket, based solely on the highest speed you drove during that time. In some areas, peak demand charges now account for 30 to 60 percent of a facility’s annual electric spend. When projecting energy cost savings, failing to separately account for kW peak demand and kWh consumption may result in erroneous results, and a lot of questions from the C-suite.

How peak demand charges are calculated varies among utilities. Some base it on the highest average speed of use across one hour in a month, while others may use the highest average speed during a 15- or 30-minute period. Others may average several of the highest speeds within a defined time period (for example, 8 a.m. to 6 p.m. on weekdays). It is whatever your tariff says it is.

Because some power-consuming (or producing) devices, including those tied to smart home electricity networks, vary in their operation or abilities, they may save money on a few — but not all — of those rate components. If an equipment vendor calculates savings from its product by using an average electric rate, take pause. Tell the vendor to return after the proposal has been redone using tariff-based numbers.

When a vendor is the only person calculating potential savings from using a product, there’s also a built-in conflict of interest: The person profiting from an equipment sale should not also be the one calculating its expected financial return. Before signing any energy project contracts, it’s essential that someone independent of the deal reviews projected savings. That person (typically an energy or engineering consultant) should be quite familiar with your facility’s electric tariff, including any special provisions, riders, discounts, etc., that may pertain. When this doesn’t happen, savings often don’t occur as planned. 

For example, some utilities add another form of demand charge, based on the highest kW in a year. It has various names: capacity, contract demand, or the generic term “ratchet charge.” Some utilities also have a minimum ratchet charge which may be based on a percent of a facility’s annual kW peak. It ensures collection of sufficient utility revenue to cover the cost of installed transmission and distribution even when a customer significantly cuts its peak demand.

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Hinkley Point C dome lift marks a nuclear reactor milestone in Somerset, as EDF used Big Carl crane to place a 245-tonne steel roof, enabling 2027 startup amid costs, delays, and precision indoor welding.

Key Points

A 245-tonne dome lifted onto Hinkley Point C's first reactor, finishing the roof and enabling fit-out for a 2027 startup.

✅ 245-tonne steel dome lifted by Big Carl onto 44m-high reactor

✅ Indoor welding avoided weather defects seen at Flamanville

✅ Cost now £33bn; first power targeted by end of 2027

Engineers have lifted a steel roof onto a building which will house the first of two nuclear reactors at Hinkley Point in Somerset.

Hundreds of people helped with the delicate operation to get the 245-tonne steel dome into position.

It means the first reactor can be installed next year, ready to be switched on in June 2027.

Engineers at EDF said the "challenging job" was completed in just over an hour.

They first broke the ground on the new nuclear station in March 2017. Now, some 10,000 people work on what is Europe's largest building site.

Yet many analysts note that Europe is losing nuclear power even as demand for reliable energy grows.

They have faced delays from Covid restrictions and other recent setbacks, and the budget has doubled to £33bn, so getting the roof on the first of the two reactor buildings is a big deal.

EDF's nuclear island director Simon Parsons said it was a "fantastic night".

"Lifting the dome into place is a celebration of all the work done by a fantastic team. The smiles on people's faces this morning were something else.

"Now we can get on with the fitting of equipment, pipes and cables, including the first reactor which is on site and ready to be installed next year."

Nuclear minister Andrew Bowie hailed the "major milestone" in the building project, citing its role in the UK's green industrial revolution ambitions.

He said: "This is a key part of the UK Government's plans to revitalise nuclear."

But many still question whether Hinkley Point C will be worth all the money, especially after Hitachi's project freeze in Britain, with Roy Pumfrey of the Stop Hinkley campaign describing the project as "shockingly bad value".

Why lift the roof on?

The steel dome is bigger than the one on St Paul's Cathedral in London.

To lift it onto the 44-metre-high reactor building, they needed the world's largest land-based crane, dubbed Big Carl by engineers.

So why not just build the roof on top of the building?

The answer lies in a remote corner of Normandy in France, near a village called Flamanville.

EDF has been building a nuclear reactor there since 2007, ten years before they started in west Somerset.

The project is now a decade behind schedule and has still not been approved by French regulators.

Why? Because of cracks found in the precision welding on the roof of the reactor building.

In nuclear-powered France, they built the roof in situ, out in the open. 

Engineers have decided welding outside, exposed to wind and rain, compromised the high standards needed for a nuclear reactor.

So in Somerset they built a temporary workshop, which looks like a fair sized building itself. All the welding has been done inside, and then the completed roof was lifted into place.

Is it on time or on budget?

No, neither. When Hinkley C was first approved a decade ago, EDF said it would cost £14bn.

Four years later, in 2017, they finally started construction. By now the cost had risen to £19.5bn, and EDF said the plant would be finished by the end of 2025.

Today, the cost has risen to £33bn, and it is now hoped Hinkley C will produce electricity by the end of 2027.

"Nobody believes it will be done by 2027," said campaigner Roy Pumfrey.

"The costs keep rising, and the price of Hinkley's electricity will only get dearer," they added.

On the other hand, the increase in costs is not a problem for British energy bill payers, or the UK government.

EDF agreed to pay the full cost of construction, including any increases.

When I met Grant Shapps, then the UK Energy Secretary, at the site in April, he shrugged off the cost increases.

He said: "I think we should all be rather pleased it is not the British tax payer - it is France and EDF who are paying."

In return, the UK government agreed a set rate for Hinkley's power, called the Strike Price, back in 2013. The idea was this would guarantee the income from Hinkley Point for 35 years, allowing investors to get their money back.

Will it be worth the money?

Back in 2013, the Strike Price was set at £92.50 for each megawatt hour of power. At the time, the wholesale price of electricity was around £50/MWh, so Hinkley C looked expensive.

But since then, global shocks like the war in Ukraine have increased the cost of power substantially, and advocates argue next-gen nuclear could deliver smaller, cheaper, safer designs.

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