Tunisia increases gas to meet power demand

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Tunisia's electrical power demand is growing 6 annually, in step with the country's development plans.

The 11th development plan 2007-11 shows 5.4 power demand growth, and the Tunisian government is forecasting power demand growth of 7 for the 12th development plan 2012-16, as demand is expected to be in line with mega-projects and the subsequent economic push in the fields of housing, tourism, and business growth in a range of industries.

The vertically integrated utility Société Tunisienne de l'Electricité et du Gaz STEG, which was established in 1962, still generates approximately 75 of Tunisia's power and has a monopoly over the country's transmission and distribution of electricity and gas.

STEG supplied 70 of the natural gas requirements of Tunisia's power stations and relied on its bordering neighbor Algeria to fulfill the shortage. In its pursuit of a reduced import fuel bill, Tunisia is developing existing gas fields and exploring new fields with the cooperation of international companies such as BP plc.

In July 2010, Tunisia applied to the African Development Bank for a loan of US $187 million to expand its Hasdrubal offshore gas field, which is 106 kilometers offshore. This loan will help to raise gas production to 100 million cubic feet daily and 16,000 tons of oil equivalent from liquefied gas, in addition to oil and condensates that will be consumed by local market.

The Islamic development Bank granted STEG $45 million to extend a gas pipeline to the southern industrial area of Tunisia to feed the planned gas-fired power plants.

One of the gas-fired plants is Sousse, which will supply the industrial sector. STEG floated bids for construction of a 380- to 450-MW turnkey combined-cycle plant at the end of 2009 in the southern area of Sousse, having financed the scheme and planned to award the successful bidder with a 12-year operations and maintenance contract.

In November 2010 Construction and engineering company SNC-Lavalin Group Incorporated won a $340 million contract to build the planned power plant. SNC-Lavalin will work with partner Ansaldo Energia. The plant is expected to be completed in 2013.

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Japan opens part of last town off-limits since nuclear leaks

Futaba Partial Reopening marks limited access to the Fukushima exclusion zone, highlighting radiation decontamination progress, the train station restart, and regional recovery ahead of the Tokyo Olympics after the 2011 nuclear disaster and evacuation.

 

Key Points

A lift of entry bans in Futaba, signaling Fukushima recovery, decontamination progress, and a train station restart.

✅ Unrestricted access to 2.4 km² around Futaba Station

✅ Symbolic step ahead of Tokyo Olympics torch relay

✅ Decommissioning and decontamination to span decades

 

Japan's government on Wednesday opened part of the last town that had been off-limits due to radiation since the Fukushima nuclear disaster nine years ago, in a symbolic move to show the region's recovery ahead of the Tokyo Olympics, even as grid blackout risks have drawn scrutiny nationwide.

The entire population of 7,000 was forced to evacuate Futaba after three reactors melted down due to damage at the town's nuclear plant caused by a magnitude 9. 0 quake and tsunami March 11, 2011.

The partial lifting of the entry ban comes weeks before the Olympic torch starts from another town in Fukushima, as new energy projects like a large hydrogen system move forward in the prefecture. The torch could also arrive in Futaba, about 4 kilometres (2.4 miles) from the wrecked nuclear plant.

Unrestricted access, however, is only being allowed to a 2.4 square-kilometre (less than 1 square-mile) area near the main Futaba train station, which will reopen later this month to reconnect it with the rest of the region for the first time since the accident. The vast majority of Futaba is restricted to those who get permission for a day visit.

The three reactor meltdowns at the town's Fukushima Dai-ichi nuclear power plant spewed massive amounts of radiation that contaminated the surrounding area and at its peak, forced more than 160,000 people to flee, even as regulators later granted TEPCO restart approval for a separate Niigata plant elsewhere in Japan.

The gate at a checkpoint was opened at midnight Tuesday, and Futaba officials placed a signboard at their new town office, at a time when the shutdown of Germany's last reactors has reshaped energy debates abroad.

“I'm overwhelmed with emotion as we finally bring part of our town operations back to our home town," said Futaba Mayor Shiro Izawa. “I pledge to steadily push forward our recovery and reconstruction."

Town officials say they hope to see Futaba’s former residents return, but prospects are grim because of lingering concern about radiation, and as Germany's nuclear exit underscores shifting policies abroad. Many residents also found new jobs and ties to communities after evacuating, and only about 10% say they plan to return.

Futaba's registered residents already has decreased by 1,000 from its pre-disaster population of 7,000. Many evacuees ended up in Kazo City, north of Tokyo, after long bus trips, various stopovers and stays in shelters at an athletic arena and an abandoned high school. The town's government reopened in a makeshift office in another Fukushima town of Iwaki, while abroad projects like the Bruce reactor refurbishment illustrate long-term nuclear maintenance efforts.

Even after radiation levels declined to safe levels, the region's farming and fishing are hurt by lingering concerns among consumers and retailers. The nuclear plant is being decommission in a process that will take decades, with spent fuel removal delays extending timelines, and it is building temporary storage for massive amounts of debris and soil from ongoing decontamination efforts.

 

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Growing pot sucks up electricity and pumps out an astounding amount of carbon dioxide — it doesn't have to

Sustainable Cannabis Cultivation leverages greenhouse design, renewable energy, automation, and water recapture to cut electricity use, emissions, and pesticides, delivering premium yields with natural light, smart sensors, and efficient HVAC and irrigation control.

 

Key Points

A data-driven, low-impact method that cuts energy, water, and chemicals while preserving premium yields.

✅ 70-90% less electricity vs. conventional indoor grows

✅ Natural light, solar, and rainwater recapture reduce footprint

✅ Automation, sensors, and HVAC stabilize microclimates

 

In the seven months since the Trudeau government legalized recreational marijuana use, licensed producers across the country have been locked in a frenetic race to grow mass quantities of cannabis for the new market.

But amid the rush for scale, questions of sustainability have often taken a back seat, and in Canada, solar adoption has lagged in key sectors.

According to EQ Research LLC, a U.S.-based clean-energy consulting firm, cannabis facilities can need up to 150 kilowatt-hours of electricity per year per square foot. Such input is on par with data centres, which are themselves 50 to 200 times more energy-intensive than a typical office building, and achieving zero-emission electricity by 2035 would help mitigate the associated footprint.

At the Lawrence Berkley National Laboratory in California, a senior scientist estimated that one per cent of U.S. electricity use came from grow ops. The same research — published in 2012 — also found that the procedures for refining a kilogram of weed emit around 4,600 kilograms of carbon dioxide to the atmosphere, equivalent to operating three million cars for a year, though a shift to zero-emissions electricity by 2035 could substantially cut those emissions.

“All factors considered, a very large expenditure of energy and consequent ‘environmental imprint’ is associated with the indoor cultivation of marijuana,” wrote Ernie Small, a principal research scientist for Agriculture and Agri-Food Canada, in the 2018 edition of the Biodiversity Journal.

Those issues have left some turning to technology to try to reduce the industry’s footprint — and the economic costs that come with it — even as more energy sources make better projects for forward-looking developers.

“The core drawback of most greenhouse environments is that you’re just getting large rooms, which are harder to control,” says Dan Sutton, the chief executive officer of Tantalus Labs., a B.C.-based cannabis producer. “What we did was build a system specifically for cannabis.”

Sutton is referring to SunLab, the culmination of four years of construction, and at present the main site where his company nurtures rows of the flowering plant. The 120,000-square foot structure was engineered for one purpose: to prove the merits of a sustainable approach.

“We’re actually taking time-series data on 30 different environmental parameters — really simple ones like temperature and humidity — all the way down to pH of the soil and water flow,” says Sutton. “So if the temperature gets a little too cold, the system recognizes that and kicks on heaters, and if the system senses that the environment is too hot in the summertime, then it automatically vents.”

A lot is achieved without requiring much human intervention, he adds. Unlike conventional indoor operations, SunLab demands up to 90 per cent less electricity, avoids using pesticides, and draws from natural light and recaptured rainwater to feed its crops.

The liquid passes through a triple-filtration process before it is pumped into drip irrigation tubing. “That allows us to deliver a purity of water input that is cleaner than bottled water,” says Sutton.

As transpiration occurs, a state-of-the-art, high-capacity airflow suspended below the ceiling cycles air at seven-minute intervals, repeatedly cooling the air and preventing outbreaks of mould, while genetically modified “guardian” insects swoop in to eliminate predatory pests.

“When we first started, people never believed we would cultivate premium quality cannabis or cannabis that belongs on the top shelf, shoulder to shoulder with the best in the world and the best of indoor,” says Sutton.

Challenges still exist, but they pale in comparison to the obstacles that American companies with an interest in adopting greener solutions persistently face, and in provinces like Alberta, an Alberta renewable energy surge is reshaping the opportunity set.

Although cannabis is legal in a number of states, it remains illegal federally, which means access to capital and regulatory clarity south of the border can be difficult to come by.

“Right now getting a new project built is expensive to do because you can’t get traditional bank loans,” says Canndescent CEO Adrian Sedlin, speaking by phone from California.

In retrofitting the company’s farm to accommodate a sizeable solar field, he struggled to secure investors, even as a solar-powered cannabis facility in Edmonton showcased similar potential.

“We spent over a year and a half trying to get it financed,” says Sedlin. “Finding someone was the hard part.”

Decriminalizing the drug would ultimately increase the supply of capital and lower the costs for innovative designs, something Sedlin says would help incentivize producers to switch to more effective and ecologically sound techniques.

Some analysts argue that selling renewable energy in Alberta could become a major growth avenue that benefits energy-intensive industries like cannabis cultivation.

Canndescent, however, is already there.

“We’re now harnessing the sun to reduce our reliance on fossil fuels and going to sustainable, or replenishable, energy sources, while leveraging the best and most efficient water practices,” says Sedlin. “It’s the right thing to do.”

 

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Siemens Energy to unlock a new era of offshore green hydrogen production

Offshore Wind-to-Hydrogen Integration enables green hydrogen by embedding an electrolyzer in offshore turbines. Siemens Gamesa and Siemens Energy align under H2Mare to decarbonize industry, advance the Paris Agreement, and unlock scalable, off-grid renewable production.

 

Key Points

A method integrating electrolyzers into offshore wind turbines to generate green hydrogen and reduce carbon emissions.

✅ Integrated electrolyzer at turbine base for off-grid operation

✅ Enables scalable, cost-efficient green hydrogen production

✅ Supports decarbonization targets under Paris Agreement

 

To reach the Paris Agreement goals, the world will need vast amounts of green hydrogen and, with offshore wind growth accelerating, wind will provide a large portion of the power needed for its production.

Siemens Gamesa and Siemens Energy announced today that they are joining forces combining their ongoing wind-to-hydrogen developments to address one of the major challenges of our decade - decarbonizing the economy to solve the climate crisis.

The companies are contributing with their developments to an innovative solution that fully integrates an electrolyzer into an offshore wind turbine as a single synchronized system to directly produce green hydrogen. The companies intend to provide a full-scale offshore demonstration of the solution by 2025/2026. The German Federal Ministry of Education and Research, reflecting Germany's clean energy progress, announced today that the developments can be implemented as part of the ideas competition 'Hydrogen Republic of Germany'.

'Our more than 30 years of experience and leadership in the offshore wind industry, coupled with Siemens Energy's expertise in electrolyzers, brings together brilliant minds and cutting-edge technologies to address the climate crisis. Our wind turbines play a huge role in the decarbonization of the global energy system, and the potential of wind to hydrogen means that we can do this for hard-to-abate industries too. It makes me very proud that our people are a part of shaping a greener future,' said Andreas Nauen, Siemens Gamesa CEO.

Christian Bruch, CEO of Siemens Energy, explains: 'Together with Siemens Gamesa, we are in a unique position to develop this game changing solution. We are the company that can leverage its highly flexible electrolyzer technology and create and redefine the future of sustainable offshore energy production. With these developments, the potential of regions with abundant offshore wind, such as the UK offshore wind sector, will become accessible for the hydrogen economy. It is a prime example of enabling us to store and transport wind energy, thus reducing the carbon footprint of economy.'

Over a time frame of five years, Siemens Gamesa plans to invest EUR 80 million and Siemens Energy is targeting to invest EUR 40 million in the developments. Siemens Gamesa will adapt its development of the world's most powerful turbine, the SG 14-222 DD offshore wind turbine to integrate an electrolysis system seamlessly into the turbine's operations. By leveraging Siemens Gamesa's intricate knowledge and decades of experience with offshore wind, electric losses are reduced to a minimum, while a modular approach ensures a reliable and efficient operational set-up for a scalable offshore wind-to-hydrogen solution. Siemens Energy will develop a new electrolysis product to not only meet the needs of the harsh maritime offshore environment and be in perfect sync with the wind turbine, but also to create a new competitive benchmark for green hydrogen.

The ultimate fully integrated offshore wind-to-hydrogen solution will produce green hydrogen using an electrolyzer array located at the base of the offshore wind turbine tower, blazing a trail towards offshore hydrogen production. The solution will lower the cost of hydrogen by being able to run off grid, much like solar-powered hydrogen in Dubai showcases for desert environments, opening up more and better wind sites. The companies' developments will serve as a test bed for making large-scale, cost-efficient hydrogen production a reality and will prove the feasibility of reliable, effective implementation of wind turbines in systems for producing hydrogen from renewable energy.

The developments are part of the H2Mare initiative which is a lighthouse project likely to be supported by the German Federal Ministry of Education and Research ideas competition 'Hydrogen Republic of Germany'. The H2mare initiative under the consortium lead of Siemens Energy is a modular project consisting of multiple sub-projects to which more than 30 partners from industry, institutes and academia are contributing. Siemens Energy and Siemens Gamesa will contribute to the H2Mare initiative with their own developments in separate modular building blocks.

About hydrogen and its role in the green energy transition

Currently 80 million tons of hydrogen are produced each year and production is expected to increase by about 20 million tons by 2030. Just 1% of that hydrogen is currently generated from green energy sources. The bulk is obtained from natural gas and coal, emitting 830 million tons of CO2 per year, more than the entire nation of Germany or the global shipping industry. Replacing this current polluting consumption would require 820 GW of wind generating capacity, 26% more than the current global installed wind capacity. Looking further ahead, many studies suggest that by 2050 production will have grown to about 500 million tons, with a significant shift to green hydrogen already signaled by projects like Brazil's green hydrogen plant now underway. The expected growth will require between 1,000 GW and 4,000 GW of renewable capacity by 2050 to meet demand, and in the U.S. initiatives like DOE hydrogen hubs aim to catalyze this build-out, which highlights the vast potential for growth in wind power.

 

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Duke solar solicitation nearly 6x over-subscribed

Duke Energy Carolinas Solar RFP draws 3.9 GW of utility-scale bids, oversubscribed in DEP and DEC, below avoided cost rates, minimal battery storage, strict PPA terms, and interconnection challenges across North and South Carolina.

 

Key Points

Utility-scale solar procurement in DEC and DEP, evaluated against avoided cost, with few storage bids and PPA terms.

✅ 3.9 GW bids for 680 MW; DEP most oversubscribed

✅ Most projects 7-80 MWac; few include battery storage

✅ Bids must price below 20-year avoided cost estimate

 

Last week the independent administrator for Duke’s 680 MW solar solicitation revealed data about the projects which have bid in response to the offer, showing a massive amount of interest in the opportunity.

Overall, 18 individuals submitted bids for projects in Duke Energy Carolinas (DEC) territory and 10 in Duke Energy Progress (DEP), with a total of more than 3.9 GW of proposals – more nearly 6x the available volume. DEP was relatively more over-subscribed, with 1.2 GWac of projects vying for only 80 MW of available capacity.

This is despite a requirement that such projects come in below the estimate of Duke’s avoided cost for the next 20 years, and amid changes in solar compensation that could affect project economics. Individual projects varied in capacity from 7-80 MWac, with most coming within the upper portion of that range.

These bids will be evaluated in the spring of 2019, and as Duke Energy Renewables continues to expand its portfolio, Duke Energy Communications Manager Randy Wheeless says he expects the plants to come online in a year or two.

 

Lack of storage

Despite recent trends in affordable batteries, of the 78 bids that came in only four included integrated battery storage. Tyler Norris, Cypress Creek Renewables’ market lead for North Carolina, says that this reflects that the methodology used is not properly valuing storage.

“The lack of storage in these bids is a missed opportunity for the state, and it reflects a poorly designed avoided cost rate structure that improperly values storage resources, commercially unreasonable PPA provisions, and unfavorable interconnection treatment toward independent storage,” Norris told pv magazine.

“We’re hopeful that these issues will be addressed in the second RFP tranche and in the current regulatory proceedings on avoided cost and state interconnection standards and grid upgrades across the region.”

 

Limited volume for North Carolina?

Another curious feature of the bids is that nearly the same volume of solar has been proposed for South Carolina as North Carolina – despite this solicitation being in response to a North Carolina law and ongoing legal disputes such as a church solar case that challenged the state’s monopoly model.

 

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UAE’s nuclear power plant connects to the national grid in a major regional milestone

UAE Barakah Nuclear Plant connects Unit 1 to the grid, supplying clean electricity, nuclear baseload power, and lower carbon emissions, with IAEA oversight, FANR regulation, and South Korea collaboration, supporting energy security and economic diversification.

 

Key Points

The UAE Barakah Nuclear Plant is a four-reactor project delivering clean baseload power and reducing CO2.

✅ Unit 1 online; four reactors to supply 25% of UAE electricity

✅ Cuts 21 million tons CO2 annually; clean baseload for grid

✅ FANR-licensed; IAEA and WANO oversight ensure safety

 

Unit 1 of the UAE’s Barakah plant — the Arab world’s first nuclear energy plant in the region — has connected to the national power grid, in a historic moment enabling it to provide cleaner electricity to millions of residents and help reduce the oil-rich country’s reliance on fossil fuels. 

“This is a major milestone, we’ve been planning for this for the last 12 years now,” Mohamed Al Hammadi, CEO of Emirates Nuclear Energy Corporation (ENEC), told CNBC’s Dan Murphy in an exclusive interview ahead of the news.

Unit 1, which has reached 100% power as it steps closer to commercial operations, is the first of what will eventually be four reactors, which when fully operational are expected to provide 25% of the UAE’s electricity and reduce its carbon emissions by 21 million tons a year, according to ENEC. That’s roughly equivalent to the carbon emissions of 3.2 million cars annually.

The Gulf country of nearly 10 million is the newest member of a group of now 31 countries running nuclear power operations. It’s also the first new country to launch a nuclear power plant in three decades, the last being China’s nuclear energy program in 1990.

“The UAE has been growing from an electricity demand standpoint,”  Al Hammadi said. “That’s why we are trying to meet the demand (and) at the same time have it with less carbon emissions.”

The UAE’s electricity mix will continue to include gas and renewable energy, with “the baseload from nuclear,” including emerging next-gen nuclear designs, the CEO added, which he described as a “safe, clean and reliable source of electricity” for the country.

The project is also providing “highly compensated jobs” for the Emiratis and will introduce new industries for the country’s economy, Al Hammadi said. The company noted that it has awarded roughly 2,000 contracts worth more than $4.8 billion for local companies.

International collaboration
The UAE’s nuclear watchdog FANR, the Federal Authority for Nuclear Regulation, granted the operating license for Unit 1 in February, after an extensive inspection process to ensure the plant’s compliance with regulatory requirements. The license is expected to last 60 years. The program also involved collaboration with external bodies including the U.N.’s International Atomic Energy Agency (IAEA) and the government of South Korea, and its pre-start-up review was completed in January by the World Association of Nuclear Operators (WANO). The WANO and the IAEA have conducted over 40 inspection and review missions at Barakah.   

But the project has its critics, particularly some experts from the independent Nuclear Consulting Group non-profit, who have expressed concern about Barakah’s safety features and potential environmental risks.  

In response, ENEC said the “adherence to the highest standards of safety, quality and security is deeply embedded within the fabric of the UAE Peaceful Nuclear Energy Program.”

“The Barakah Plant meets all national and international regulatory requirements and standards for nuclear safety,” a  company statement said. It added that the reactor design had been certified by the Korea Institute of Nuclear Safety, FANR and the US-based Nuclear Regulatory Commission, “demonstrating the robustness of this design for safety and operating reliability.”

Worries of regional proliferation 
The achievement for the UAE is particularly significant given tensions in the wider region over nuclear proliferation. 

Some observers have warned of a regional arms race, though the UAE already partakes in what nuclear energy experts call the “gold standard” of civilian nuclear partnerships: The U.S.-UAE 123 Agreement for Peaceful Civilian Nuclear Energy Cooperation. It allows the UAE to receive nuclear materials, equipment and know-how from the U.S. while precluding it from developing dual-use technology by barring uranium enrichment and fuel reprocessing, the processes required for building a bomb.

By contrast, nearby Iran has suspended its compliance to the multilateral 2015 deal that regulated its nuclear power development and many fear its approach toward bomb-making capability. Meanwhile, Saudi Arabia has voiced its desire to develop a nuclear energy program without adhering to a 123 agreement.

And most recently, in the wake of a historic deal that has seen the UAE become the first Gulf country to normalize relations with Israel, Iran responded by warning the agreement would bring a “dangerous future” for the Emirati government. 

But ENEC and UAE officials emphasize the program’s commitment to safety, transparency and international cooperation, and its necessity for meeting growing electricity demand by cleaner means. 

“The nuclear industry is growing, with milestones around the world being reached, and the UAE is no exception. We are pursuing our electricity demand to meet that in a safe, secure and stable manner, and also doing it in an environmentally friendly way,” Al Hammadi said.

“Having four reactors that will provide 25% of electricity for the nation and will avoid us emitting 21 million tons of CO2 on an annual basis, as part of a broader green industrial revolution approach, is a very serious step to take — and the UAE is not talking about it, it is doing it, and we are reaping the benefits of it as we speak right now.”

 

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35 arrested in India for stealing electricity

BEST vigilance raid on Wadala electricity theft uncovered a Mumbai power theft racket in Antop Hill and Sangam Nagar, with operators, illegal connections, sub-stations, meter cabins, FIRs, and Rs 72 lakh losses flagged by BEST.

 

Key Points

A BEST operation that nabbed operators stealing power via illegal connections in Wadala, exposing a Rs 72 lakh loss.

✅ 35 suspects booked; key operator identified as David Anthony.

✅ Illegal taps from sub-stations and meter cabins in shanties.

✅ BEST filed FIRs; Session court granted bail to accused.

 

In a raid conducted at Antop Hill in Wadala on Saturday, a total of 35 people were nabbed by the vigilance department for stealing electricity to the tune of Rs 72 lakh, in a case similar to a Montreal power-theft ring bust covered internationally.

It was the second such raid conducted in the past one week, where operators have been nabbed.The cash-strapped BEST is now tightening it's grasp on `operators' who steal electricity from BEST sources and provide it to their own customers on a meagre monthly rent, even as Ontario utilities warn about scams affecting customers elsewhere.

After receiving a tip-off about the theft of electricity in the Sangam Nagar area of Wadala, about 90 personnel of the BEST conducted a raid. After visiting the spots, it was found that illegal connections were made from the sub-station and other electricity boxes of the BEST in the area, underscoring how fragile networks can be amid disruptions such as major outages in London that affected thousands.

According to BEST officials, the residents from the area would come up to the accused, identified as David Anthony, and would pay a fixed amount at the end of every month for unlimited supply of power, a dynamic reminiscent of shutoff-threat scams flagged by Manitoba Hydro, though the circumstances differ. Anthony would with draw power directly from meter cabins and electricity boxes in the area. The wires he connected to these were in turn connected to households who made the arrangement with him. An official from BEST also explained that as soon they reach a location to conduct raids and vehicles of BEST officials are spotted by residents, most of the connections are cut off, which makes it difficult for them to prove the theft case However, on Saturday, BEST officials managed to conduct the raid swiftly and nab 35 people.

All who had illegal connections were named in the complaint and an FIR was registered against them, including Anthony, who himself had illegal connections in his house. They were produced in Session court and given bail, while utilities in other regions resort to hydro disconnections during arrears season. Chief Vigilance Officer of BEST, RJ Singh said, "Most of these are commercial establishments in these shanties, which steal electricity. It is very important to catch hold of the operators as they are the providers and we need to break their backbone."

 

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