Indian power, cement and steel industry majors are scouting for coal acquisitions abroad in a bid to secure coal for their expansion plans in the coming years.
Captive coal mines will also insulate industry majors from fluctuations in coal prices.
At the forefront of the coal rush is the Indian power sector, which currently accounts for 75% to 80% of domestic coal demand. The sector is expected to require about 540 million tons of coal per year by 2013. Demand is likely to surpass domestic supply by at least 60 million tons per year by that time, and the gap is expected to widen to 100 million tons by 2015.
Coal Ventures International Limited (CVIL), promoted by five state-owned companies, has invited expressions of interest from global investment banks for assistance in securing overseas thermal and metallurgical coal mines. CVIL is eyeing strategic investment opportunities in metallurgical, pulverized coal injection and steam coal producing companies in Australia, Canada and the U.S.
It will invest in private equity deals with owners of coal assets in Indonesia, Mozambique, South Africa and Zimbabwe. It will also obtain mining licenses to develop coal mines worldwide. The company has been vested with autonomous powers by the government to clear investment proposals of up to $375 million at the board level.
CVIL is promoted by Coal India Limited, National Mineral Development Corporation Limited, National Thermal Power Corporation Limited, Rashtriya Ispat Nigam Limited and Steel Authority of India Limited.
In March, Reliance Power Limited announced the acquisition of three coal mines in Sumatra, Indonesia, with estimated reserves of 2 billion tons. Gujarat NRE Coke Limited has been operating the NRE Wongawilli Colliery near Wollongong, Australia, since last year when it acquired the mine for $50 million. The company now plans to invest an additional $65 million over the next two years to expand the mines to full production capacity of 2.5 million tons per year by 2011-12.
ETA Star India Projects Private Limited, the Indian subsidiary of the ETA Star Group, has joined hands with PTC India Limited and Infrastructure Leasing and Financial Services to acquire overseas coal assets. PTC has agreed to supply coal to power project developers for an aggregate generation capacity of 5,000 megawatts (MW).
IL&FS wants to ensure coal supplies for its 1,600-MW coal-fired power project in Krishnapatnam, Andhra Pradesh, in which it owns a 50% stake. Last year, the ETA Star Group obtained a coal block in Mozambique. In January 2008, it acquired Bara Energy Makmur (Indonesia), which owns two coal blocks.
Tata Power Company Limited has acquired a 30% stake in PT Kaltim Prima Coal and PT Arutmin, thermal coal producers owned by PT Bumi Resources Tbk for $1.1 billion to feed its upcoming power projects. The imported coal requirement for the 7,000 MW of power projects is estimated to be 21 million tons.
In June 2007, infrastructure major Madhucon Projects Limited acquired an Indonesian coalmine with reserves of 50 million tons. It is reportedly scouting for more acquisitions to secure supplies for its proposed 1,000-MW power plant in the special economic zone on the east coast of India. In April 2008, GMR Group announced its decision to pick up a 5% equity stake in Homeland Mining and Energy SA for $15 million to fuel its power projects in India.
Cement and steel majors are also trying to keep pace with power majors in the frenzy for coal acquisitions overseas. Coal accounts for 27% of the manufacturing costs of cement. Binani Cement Limited is looking to acquire coal mines in Indonesia with reserves of 30 million tons for $60 million. The company incurs annual costs of $100 million in coal imports. The acquired mines will supply lignite coal, which is required for Binani's proposed cement project in Gujarat. UltraTech Cement Limited wants to acquire coal mines in South Africa and Indonesia.
In January, Surana Industries announced that it would acquire a 49% stake in PT Agate Resources for $400 million, which will lease out or acquire mining rights in Indonesia. This will enable Surana to meet power requirements for its upcoming integrated steel complex in Raichur, Karnataka. Surana's steel complex will procure 35 MW of power from a thermal power station and 10 MW of power from waste heat recovery.
In May 2008, Tata Steel Limited announced plans to undertake a large-scale expansion of the Carborough Downs mine in Queensland, Australia, in which the company owns a 5% equity stake. The mine is expected to generate 4.9 million tons per year of run-of-mine coal, which will yield 3.7 million tons of coal annually, starting in mid-2009.
Late last year, the company partnered with Riversdale Mining to acquire a 35% stake in a coking-coal-mining project in Mozambique for $88.3 million. It received rights to 40% of the project's output. The mine is estimated to have coal reserves of 1.23 billion tons.
UK Wind and Tidal Power Auction signals strong CfD support for offshore wind, tidal stream projects, investor certainty, and clean electricity, accelerating the net-zero transition, boosting jobs, and strengthening UK energy security and grid integration.
Key Points
A CfD auction awarding contracts for wind and tidal projects to scale clean power and advance UK net-zero.
✅ Jobs, investment, and grid integration accelerate
In a significant development for the UK’s renewable energy sector, the latest auction for renewable energy contracts has underscored a transformative shift towards wind and tidal power. As reported by The Guardian, the auction results reveal a strong commitment to expanding these technologies, with new contracts adding 10 GW to the UK grid, marking a pivotal moment in the UK’s transition to cleaner energy sources.
The Auction’s Impact
The renewable energy auction, which took place recently, has allocated contracts for a substantial increase in wind and tidal power projects. This auction, part of the UK’s Contracts for Difference (CfD) scheme, is designed to support the development of low-carbon energy technologies by providing financial certainty to investors. By offering fixed prices for the electricity generated by these projects, the CfD scheme aims to stimulate investment and accelerate the deployment of renewable energy sources.
The latest results are particularly notable for the significant share of contracts awarded to offshore wind farms and tidal power projects, highlighting how offshore wind is powering up the UK as policy and investment priorities continue to shift. This marks a shift from previous auctions, where solar power and onshore wind were the dominant technologies. The move towards supporting offshore wind and tidal power reflects the UK’s strategic focus on harnessing its abundant natural resources to drive the transition to a low-carbon energy system.
Offshore Wind Power: A Major Contributor
Offshore wind power has emerged as a major player in the UK’s renewable energy landscape, within a global market projected to become a $1 trillion business over the coming decades. The recent auction results highlight the continued growth and investment in this sector.
The UK has been a global leader in offshore wind development, with several large-scale projects already operational and more in the pipeline. The auction has further cemented this position, underscoring what the U.S. can learn from the U.K. in scaling offshore wind capacity, with new projects set to contribute significantly to the country’s renewable energy capacity. These projects are expected to deliver substantial amounts of clean electricity, supporting the UK’s goal of achieving net-zero emissions by 2050.
Tidal Power: An Emerging Frontier
Tidal power, although less developed compared to wind and solar, is gaining momentum as a promising renewable energy source, with companies harnessing oceans and rivers to demonstrate practical potential. The auction results have allocated contracts to several tidal power projects, signaling growing recognition of the potential of this technology.
Tidal power harnesses the energy from tidal movements and currents, which are highly predictable and consistent, and a market outlook for wave and tidal energy points to emerging growth drivers and investment. This makes it a reliable complement to intermittent sources like wind and solar power. The inclusion of tidal power projects in the auction reflects the UK’s commitment to diversifying its renewable energy portfolio and exploring all available options for achieving energy security and sustainability.
Economic and Environmental Benefits
The expansion of wind and tidal power projects through the recent auction offers numerous economic and environmental benefits. From an economic perspective, these projects are expected to create thousands of jobs in construction, maintenance, and manufacturing. They also stimulate investment in local economies and support the growth of the green technology sector.
Environmentally, the increased deployment of wind and tidal power contributes to significant reductions in greenhouse gas emissions. Offshore wind farms and tidal power projects produce clean electricity with minimal environmental impact, helping to mitigate the effects of climate change and improve air quality.
Challenges and Future Outlook
Despite the positive outcomes of the auction, there are challenges to address. Offshore wind farms and tidal power projects require substantial upfront investment and face technical and logistical challenges. Issues such as grid integration, environmental impact assessments, and supply chain constraints need to be carefully managed to ensure the successful deployment of these projects.
Looking ahead, the UK’s renewable energy strategy will continue to evolve as new technologies and innovations emerge, and growth despite Covid-19 underscores sector resilience. The success of the latest auction demonstrates the growing confidence in wind and tidal power and sets the stage for further advancements in renewable energy.
The UK government’s commitment to supporting these technologies through initiatives like the CfD scheme is crucial for achieving long-term energy and climate goals. As the country progresses towards its net-zero target, the continued expansion of wind and tidal power will play a key role in shaping a sustainable and resilient energy future.
Conclusion
The latest renewable energy auction represents a significant milestone in the UK’s transition to a low-carbon energy system. By awarding contracts to wind and tidal power projects, the auction underscores the country’s commitment to harnessing diverse and reliable sources of renewable energy. The expansion of offshore wind and the emerging role of tidal power highlight the UK’s strategic approach to achieving energy security, reducing emissions, and driving economic growth. As the renewable energy sector continues to evolve, the UK remains at the forefront of global efforts to build a sustainable and clean energy future.
Canada 2035 Gasoline Car Ban accelerates EV adoption, zero-emission transport, and climate action, with charging infrastructure, rebates, and industry investment supporting net-zero goals while addressing affordability, range anxiety, and consumer acceptance nationwide.
Key Points
A federal policy to end new gas car sales by 2035, boosting EV adoption, emissions goals, and charging infrastructure.
✅ Ends new gas car and light-truck sales by 2035
✅ Expands charging infrastructure and grid readiness
✅ Incentives, rebates, and industry investment drive adoption
Canada has set its sights on a bold and transformative goal: to ban the sale of new gasoline-powered passenger cars and light-duty trucks by the year 2035. This ambitious target, announced by the federal government, underscores Canada's commitment to combating climate change and accelerating the adoption of electric vehicles (EVs) nationwide, supported by forthcoming EV sales regulations from Ottawa.
The Federal Initiative
Under the leadership of Prime Minister Justin Trudeau, Canada aims to significantly reduce greenhouse gas emissions from the transportation sector, which accounts for a substantial portion of the country's carbon footprint. The initiative aligns with Canada's broader climate objectives, including achieving net-zero emissions by 2050.
Driving Forces Behind the Decision
The decision to phase out internal combustion engine vehicles reflects growing recognition of the urgency to transition towards cleaner transportation alternatives, even as 2019 electricity from fossil fuels still powered a notable share of Canada's grid. Minister of Environment and Climate Change Jonathan Wilkinson emphasizes the environmental benefits of electric vehicles, citing their potential to lower emissions and improve air quality in urban centers across the country.
Challenges and Opportunities
While the move towards electric vehicles presents promising opportunities for reducing emissions, it also poses challenges. Key considerations include infrastructure development, affordability, and consumer acceptance of EV technology, amid EV shortages and wait times that can influence buying decisions. Addressing these hurdles will require coordinated efforts from government, industry stakeholders, and consumers alike.
Industry Response
The automotive industry plays a crucial role in realizing Canada's EV ambitions. Automakers are increasingly investing in electric vehicle production and innovation to meet evolving consumer demand and regulatory requirements, including cross-border Canada-U.S. collaboration on supply chains. The transition offers opportunities for job creation, technological advancement, and economic growth in the clean energy sector.
Provincial Perspectives
Provinces across Canada are pivotal in facilitating the transition to electric vehicles. Some provinces have already implemented incentives such as rebates for EV purchases, charging infrastructure investments, and policy frameworks to support emissions reduction targets, even as Quebec's EV dominance push faces scrutiny from experts. Collaborative efforts between federal and provincial governments are essential in ensuring a cohesive approach to achieving national EV goals.
Consumer Considerations
For consumers, the shift towards electric vehicles represents a paradigm shift in transportation choices. Factors such as range anxiety, charging infrastructure availability, and upfront costs, with one EV cost survey citing price as the main barrier, remain considerations for prospective buyers. Government incentives and subsidies aim to alleviate some of these concerns and promote widespread EV adoption.
Looking Ahead
As Canada navigates towards a future without gasoline-powered vehicles, stakeholders must work together to overcome challenges and capitalize on opportunities presented by the electric vehicle revolution, even as critics of the 2035 mandate question its feasibility. Continued investments in infrastructure, innovation, and consumer education will be critical in paving the way for a sustainable and prosperous automotive industry.
Conclusion
Canada's commitment to phasing out gasoline-powered vehicles by 2035 marks a pivotal moment in the country's climate action agenda. By embracing electric vehicles, Canada aims to lead by example in combatting climate change, fostering innovation, and building a greener future for generations to come. The success of this ambitious initiative hinges on collective efforts to transform the automotive landscape and accelerate towards a sustainable transportation future.
Goreway Power Station Overbilling exposed by Ontario Energy Board shows IESO oversight failures, GCG gaming, and $100M in inappropriate payments at the Brampton natural gas plant, penalized with fines and repayments impacting Ontario ratepayers.
Key Points
Goreway exploited IESO GCG flaws, causing about $100M in improper payouts and fines.
✅ OEB probe flagged $89M in ineligible start-up O&M charges
✅ IESO fined Goreway $10M; majority of excess costs recovered
✅ Audit found $200M in overbilling across nine generators
Hydro customers shelled out about $100 million in "inappropriate" payments to a natural gas plant that exploited flaws in how Ontario manages its private electricity generators, according to the Ontario Energy Board.
The company operating the Goreway Power Station in Brampton "gamed" the system for at least three years, according to an investigation by the provincial energy regulator.
The investigation also delivers stinging criticism of the provincial government's Independent Electricity System Operator (IESO), slamming it for a lack of oversight. The probe by the Ontario Energy Board's market surveillance panel was completed nearly a year ago, but was only made public in November because it was buried on its website without a news release. CBC News is the first media outlet to report on the investigation.
The excess payments to Goreway Power Station included:
$89 million in ineligible expenses billed as the costs of firing up power production.
$5.6 million paid in three months from a flaw in how IESO calculated top-ups for the company committing to generate power a day in advance.
Of $11.2 million paid to compensate the company for IESO ordering it to start or stop generating power, the investigation concluded "a substantial portion ... was the result of gaming."
Most privately-owned natural gas-fired plants in the province do not generate electricity constantly, but start and stop production in response to fluctuating market demand, even as the energy minister has requested an halt to natural gas generation across the grid. IESO pays them a premium for the costs of firing up production, through what it calls "generation cost guarantee" programs.
But the investigation found IESO did little checking into the details of Goreway Power Station's billings.
Goreway Power Station, located near Highway 407 in Brampton, Ont., is an 875 megawatt natural gas power plant. (Goreway)
"Conservatively, at least $89 million of Goreway's submissions were clearly ineligible by any reasonable measure," concludes the report.
"Goreway routinely submitted what were obviously inappropriate expenses to be reimbursed by the IESO, and ultimately borne by Ontario ratepayers,"
The investigation panel found an "extraordinary pattern" to these billings by Goreway Power Station, suggesting the IESO should have caught on sooner. The company submitted more than $100 million in start-up operating and maintenance costs during the three-year period investigated — more than all other gas-fired generators in the province combined. The company's costs per start-up were more than double the next most expensive power generator.
"Goreway repeatedly exploited defects in the GCG (generation cost guarantee) program, and in doing so received at least $89 million in gamed GCG payments."
Company fined $10M
The investigation covered a three-year period from when Goreway Power Station began generating power in June 2009. Investigators said that delays in releasing documents slowed down their probe, and they only obtained all the records they needed in April 2016.
The investigating panel does not have the power to impose penalties on companies it found broke the rules.
The IESO fined Goreway Power Station $10 million. The company has also repaid IESO "a substantial portion" of the excess payments it received during its first six years of operating, but the exact figure is blacked out in the investigation report that was made public.
The control room from which the provincial government's Independent Electricity System Operator manages Ontario's power supply. The agency is also responsible for managing contracts with private power producers.(IESO)
"Goreway does not agree with many of the draft report's findings and conclusions, including any suggestion that Goreway engaged in gaming or that it deliberately misled the IESO," writes lawyer George Vegh on behalf of the company in a response to the investigation report, dated Aug. 1.
"Goreway has implemented initiatives designed to ensure that compliance is a chief operating principle."
The power station, located near Highway 407 in Brampton, is a joint venture between Toyota Tsusho Corp. and JERA Co. Inc. During the period under scrutiny, the project was run by Toyota Tsusho and Chubu Electric Power Inc., both headquartered in Japan.
Investigators fear 'same situation' exists today
The report blames the provincially-controlled IESO for creating a system with defects that allowed the over-billing.
"Goreway was able to — and repeatedly did — exploit these defects," says the investigation report. It goes on to explain the flaws "have created opportunities for exploitation, to the serious financial disadvantage of Ontario's ratepayers," even as greening Ontario's grid could entail massive costs.
The investigation suggests IESO hasn't made adequate changes to ensure it won't happen again, at a time when an analysis of a dirtier grid is raising concerns.
"Goreway stands as a clear example of how generators are able to exploit the generation costs guarantee regime," says the report.
"The Panel is concerned that the same situation remains in place today."
PC energy critic Todd Smith raised CBC News' report on the Goreway Power Station in Tuesday's question period. (Ontario Legislature)
After CBC News broke the story Tuesday, the provincial government was forced to respond in question period, amid a broader push for new gas plants to boost electricity production.
"Here we have yet another gas plant scandal in Peel region that's costing electricity customers over $100 million," said PC energy critic Todd Smith. He slammed "the incompetence of a government that once again failed to look out for electricity customers."
Economic Development Minister Brad Duguid said: "There is no excuse for any company in this province to ever game the system."
Nine companies overbilled $200M: audit
The IESO found out about the overbilling "some time ago," said Duguid.
"They fully investigated, they've recovered most of the cost, they delivered a $10 million fine — the biggest fine on record."
The program that Goreway exploited became the subject of an audit that the IESO launched in 2011. The agency uncovered $200 million in ineligible billings by nine power producers, wrote the IESO vice president for policy Terry Young in an email to CBC News.
The IESO has recovered up to 85 per cent of those ineligible costs, Young noted.
Reforms to the design of the the program have removed the potential for overpayments and made it more efficient, he said, even as Ontario weighs embracing clean power more broadly. Last year, its total annual costs dropped to $23 million, down from $61 million in 2014.
Boeing 787 More-Electric Architecture replaces pneumatics with bleedless pressurization, VFSG starter-generators, electric brakes, and heated wing anti-ice, leveraging APU, RAT, batteries, and airport ground power for efficient, redundant electrical power distribution.
Key Points
An integrated, bleedless electrical system powering start, pressurization, brakes, and anti-ice via VFSGs, APU and RAT.
✅ VFSGs start engines, then generate 235Vac variable-frequency power
✅ Bleedless pressurization, electric anti-ice improve fuel efficiency
✅ Electric brakes cut hydraulic weight and simplify maintenance
The 787 Dreamliner is different to most commercial aircraft flying the skies today. On the surface it may seem pretty similar to the likes of the 777 and A350, but get under the skin and it’s a whole different aircraft.
When Boeing designed the 787, in order to make it as fuel efficient as possible, it had to completely shake up the way some of the normal aircraft systems operated. Traditionally, systems such as the pressurization, engine start and wing anti-ice were powered by pneumatics. The wheel brakes were powered by the hydraulics. These essential systems required a lot of physical architecture and with that comes weight and maintenance. This got engineers thinking.
What if the brakes didn’t need the hydraulics? What if the engines could be started without the pneumatic system? What if the pressurisation system didn’t need bleed air from the engines? Imagine if all these systems could be powered electrically… so that’s what they did.
Power sources
The 787 uses a lot of electricity. Therefore, to keep up with the demand, it has a number of sources of power, much as grid operators track supply on the GB energy dashboard to balance loads. Depending on whether the aircraft is on the ground with its engines off or in the air with both engines running, different combinations of the power sources are used.
Engine starter/generators
The main source of power comes from four 235Vac variable frequency engine starter/generators (VFSGs). There are two of these in each engine. These function as electrically powered starter motors for the engine start, and once the engine is running, then act as engine driven generators.
The generators in the left engine are designated as L1 and L2, the two in the right engine are R1 and R2. They are connected to their respective engine gearbox to generate electrical power directly proportional to the engine speed. With the engines running, the generators provide electrical power to all the aircraft systems.
APU starter/generators
In the tail of most commercial aircraft sits a small engine, the Auxiliary Power Unit (APU). While this does not provide any power for aircraft propulsion, it does provide electrics for when the engines are not running.
The APU of the 787 has the same generators as each of the engines — two 235Vac VFSGs, designated L and R. They act as starter motors to get the APU going and once running, then act as generators. The power generated is once again directly proportional to the APU speed.
The APU not only provides power to the aircraft on the ground when the engines are switched off, but it can also provide power in flight should there be a problem with one of the engine generators.
Battery power
The aircraft has one main battery and one APU battery. The latter is quite basic, providing power to start the APU and for some of the external aircraft lighting.
The main battery is there to power the aircraft up when everything has been switched off and also in cases of extreme electrical failure in flight, and in the grid context, alternatives such as gravity power storage are being explored for long-duration resilience. It provides power to start the APU, acts as a back-up for the brakes and also feeds the captain’s flight instruments until the Ram Air Turbine deploys.
Ram air turbine (RAT) generator
When you need this, you’re really not having a great day. The RAT is a small propeller which automatically drops out of the underside of the aircraft in the event of a double engine failure (or when all three hydraulics system pressures are low). It can also be deployed manually by pressing a switch in the flight deck.
Once deployed into the airflow, the RAT spins up and turns the RAT generator. This provides enough electrical power to operate the captain’s flight instruments and other essentials items for communication, navigation and flight controls.
External power
Using the APU on the ground for electrics is fine, but they do tend to be quite noisy. Not great for airports wishing to keep their noise footprint down. To enable aircraft to be powered without the APU, most big airports will have a ground power system drawing from national grids, including output from facilities such as Barakah Unit 1 as part of the mix. Large cables from the airport power supply connect 115Vac to the aircraft and allow pilots to shut down the APU. This not only keeps the noise down but also saves on the fuel which the APU would use.
The 787 has three external power inputs — two at the front and one at the rear. The forward system is used to power systems required for ground operations such as lighting, cargo door operation and some cabin systems. If only one forward power source is connected, only very limited functions will be available.
The aft external power is only used when the ground power is required for engine start.
Circuit breakers
Most flight decks you visit will have the back wall covered in circuit breakers — CBs. If there is a problem with a system, the circuit breaker may “pop” to preserve the aircraft electrical system. If a particular system is not working, part of the engineers procedure may require them to pull and “collar” a CB — placing a small ring around the CB to stop it from being pushed back in. However, on the 787 there are no physical circuit breakers. You’ve guessed it, they’re electric.
Within the Multi Function Display screen is the Circuit Breaker Indication and Control (CBIC). From here, engineers and pilots are able to access all the “CBs” which would normally be on the back wall of the flight deck. If an operational procedure requires it, engineers are able to electrically pull and collar a CB giving the same result as a conventional CB.
Not only does this mean that the there are no physical CBs which may need replacing, it also creates space behind the flight deck which can be utilised for the galley area and cabin.
A normal flight
While it’s useful to have all these systems, they are never all used at the same time, and, as the power sector’s COVID-19 mitigation strategies showed, resilience planning matters across operations. Depending on the stage of the flight, different power sources will be used, sometimes in conjunction with others, to supply the required power.
On the ground
When we arrive at the aircraft, more often than not the aircraft is plugged into the external power with the APU off. Electricity is the blood of the 787 and it doesn’t like to be without a good supply constantly pumping through its system, and, as seen in NYC electric rhythms during COVID-19, demand patterns can shift quickly. Ground staff will connect two forward external power sources, as this enables us to operate the maximum number of systems as we prepare the aircraft for departure.
Whilst connected to the external source, there is not enough power to run the air conditioning system. As a result, whilst the APU is off, air conditioning is provided by Preconditioned Air (PCA) units on the ground. These connect to the aircraft by a pipe and pump cool air into the cabin to keep the temperature at a comfortable level.
APU start
As we near departure time, we need to start making some changes to the configuration of the electrical system. Before we can push back , the external power needs to be disconnected — the airports don’t take too kindly to us taking their cables with us — and since that supply ultimately comes from the grid, projects like the Bruce Power upgrade increase available capacity during peaks, but we need to generate our own power before we start the engines so to do this, we use the APU.
The APU, like any engine, takes a little time to start up, around 90 seconds or so. If you remember from before, the external power only supplies 115Vac whereas the two VFSGs in the APU each provide 235Vac. As a result, as soon as the APU is running, it automatically takes over the running of the electrical systems. The ground staff are then clear to disconnect the ground power.
If you read my article on how the 787 is pressurised, you’ll know that it’s powered by the electrical system. As soon as the APU is supplying the electricity, there is enough power to run the aircraft air conditioning. The PCA can then be removed.
Engine start
Once all doors and hatches are closed, external cables and pipes have been removed and the APU is running, we’re ready to push back from the gate and start our engines. Both engines are normally started at the same time, unless the outside air temperature is below 5°C.
On other aircraft types, the engines require high pressure air from the APU to turn the starter in the engine. This requires a lot of power from the APU and is also quite noisy. On the 787, the engine start is entirely electrical.
Power is drawn from the APU and feeds the VFSGs in the engines. If you remember from earlier, these fist act as starter motors. The starter motor starts the turn the turbines in the middle of the engine. These in turn start to turn the forward stages of the engine. Once there is enough airflow through the engine, and the fuel is igniting, there is enough energy to continue running itself.
After start
Once the engine is running, the VFSGs stop acting as starter motors and revert to acting as generators. As these generators are the preferred power source, they automatically take over the running of the electrical systems from the APU, which can then be switched off. The aircraft is now in the desired configuration for flight, with the 4 VFSGs in both engines providing all the power the aircraft needs.
As the aircraft moves away towards the runway, another electrically powered system is used — the brakes. On other aircraft types, the brakes are powered by the hydraulics system. This requires extra pipe work and the associated weight that goes with that. Hydraulically powered brake units can also be time consuming to replace.
By having electric brakes, the 787 is able to reduce the weight of the hydraulics system and it also makes it easier to change brake units. “Plug in and play” brakes are far quicker to change, keeping maintenance costs down and reducing flight delays.
In-flight
Another system which is powered electrically on the 787 is the anti-ice system. As aircraft fly though clouds in cold temperatures, ice can build up along the leading edge of the wing. As this reduces the efficiency of the the wing, we need to get rid of this.
Other aircraft types use hot air from the engines to melt it. On the 787, we have electrically powered pads along the leading edge which heat up to melt the ice.
Not only does this keep more power in the engines, but it also reduces the drag created as the hot air leaves the structure of the wing. A double win for fuel savings.
Once on the ground at the destination, it’s time to start thinking about the electrical configuration again. As we make our way to the gate, we start the APU in preparation for the engine shut down. However, because the engine generators have a high priority than the APU generators, the APU does not automatically take over. Instead, an indication on the EICAS shows APU RUNNING, to inform us that the APU is ready to take the electrical load.
Shutdown
With the park brake set, it’s time to shut the engines down. A final check that the APU is indeed running is made before moving the engine control switches to shut off. Plunging the cabin into darkness isn’t a smooth move. As the engines are shut down, the APU automatically takes over the power supply for the aircraft. Once the ground staff have connected the external power, we then have the option to also shut down the APU.
However, before doing this, we consider the cabin environment. If there is no PCA available and it’s hot outside, without the APU the cabin temperature will rise pretty quickly. In situations like this we’ll wait until all the passengers are off the aircraft until we shut down the APU.
Once on external power, the full flight cycle is complete. The aircraft can now be cleaned and catered, ready for the next crew to take over.
Bottom line
Electricity is a fundamental part of operating the 787. Even when there are no passengers on board, some power is required to keep the systems running, ready for the arrival of the next crew. As we prepare the aircraft for departure and start the engines, various methods of powering the aircraft are used.
The aircraft has six electrical generators, of which only four are used in normal flights. Should one fail, there are back-ups available. Should these back-ups fail, there are back-ups for the back-ups in the form of the battery. Should this back-up fail, there is yet another layer of contingency in the form of the RAT. A highly unlikely event.
The 787 was built around improving efficiency and lowering carbon emissions whilst ensuring unrivalled levels safety, and, in the wider energy landscape, perspectives like nuclear beyond electricity highlight complementary paths to decarbonization — a mission it’s able to achieve on hundreds of flights every single day.
Ukraine Power Grid Restoration accelerates across liberated Kharkiv, restoring electricity, heat, and water amid missile and drone strikes, demining operations, blackouts, and winterization efforts, showcasing resilience, emergency repairs, and critical infrastructure recovery.
Key Points
Ukraine's rapid push to repair war-damaged grids, restore heat and water, and stabilize key services before winter.
✅ Priority repairs restore electricity and water in liberated Kharkiv.
✅ Crews de-mine lines and work under shelling, drones, and missiles.
✅ Winterization adds generators, mobile stoves, and large firewood supplies.
On the freshly liberated battlefields of northeast Ukraine, a pile of smashed glass windows outside one Soviet-era block of apartments attests to the violence of six months of Russian occupation, and of Ukraine’s sweeping recent military advances.
Indoors, in cramped apartments, residents lived in the dark for weeks on end.
Now, with a hard winter looming, they marvel at the speed and urgency with which Ukrainian officials have restored another key ingredient to their survival: electric power, a critical effort to keep the lights on this winter across communities.
Among those things governments strive to provide are security, opportunity, and minimal comfort. With winter approaching, and Russia targeting Ukraine’s infrastructure, add to that list heat and light, even as Russia hammers power plants nationwide. It’s requiring a concerted effort.
“Thank God it works! Electricity is civilization – it is everything,” says Antonina Krasnokutska, a retired medical worker, looking affectionately at the lightbulb that came on the day before, and now burns again in her tiny spotless kitchen.
“Without electricity there is no TV, no news, no clothes washing, no charging the phone,” says Ms. Krasnokutska, her gray hair pulled back and a small crucifix around her neck.
“Before, it was like living in the Stone Age,” says her grown son, Serhii Krasnokutskyi, who is more than a head taller. “As soon as it got dark, everyone would go to sleep.”
He shows a picture on his phone from a few days earlier, of a tangle of phone and computer charging cables – including his – plugged in at a local shop with a generator.
“We are very grateful for the people who repaired this electricity, even with shelling continuing,” he says. “They have a very complicated job.”
Indeed, although a lack of power might have been a novel inconvenience during the warm summer season, it increasingly has become a matter of great urgency for Ukrainian citizens and officials.
Coping through Ukraine’s winter with dignity and any degree of security will require courage and perseverance, as the severity and suffering that the season can bring here are being weaponized by Russia, as it seeks to compensate for a string of battlefield losses.
In recent days, Russian attacks have specifically targeted Ukraine’s electrical and other civilian infrastructure – all with the apparent aim of making this winter as hard as possible for Ukrainians, even as Moscow employs other measures to spread the hardship across Europe, while Ukraine helps Spain amid blackouts through grid support.
Ukrainian President Volodymyr Zelenskyy said Monday that Russian barrages across the country with missiles and Iran-supplied kamikaze drones had destroyed 30% of Ukraine’s power stations in the previous eight days, including strikes on western Ukraine that caused outages. Thousands of towns have been left without electricity.
Kharkiv’s challenges
Emblematic of the national challenge is the one facing officials in the northeast Kharkiv region, where Ukraine recaptured more than 3,000 square miles in a September counteroffensive. Ukrainian forces are still making gains on that front, as well as in the south toward Kherson, where Wednesday Russia started evacuating civilians from the first major city it occupied, after launching its three-pronged invasion last February.
Across the Kharkiv region, Ukrainians are stockpiling as much wood, fuel, and food as possible while they still can, and adopting new energy solutions as they prepare, from sources as diverse as the floorboards of destroyed schools and the pine forests in Izium, which are pockmarked with abandoned Russian trenches adjacent to a mass burial site.
“Of course, we have this race against time,” says Serhii Mahdysyuk, the Kharkiv regional director in charge of housing, services, fuel, and energy. “Unfortunately, we probably stand in front of the biggest challenge in Ukraine.”
That is not only because of the scale of liberated territory, he says, but also because the Kharkiv region shares a long border with Russia, as well as with the Russian-controlled areas of the eastern Donbas.
“It’s a great mixture of all threats, and we are sure that shelling and bombings will continue, but we are ready for this,” says Mr. Mahdysyuk. “We know our weak spots that Russia can destroy, but we are prepared for what to do in these situations.”
Ukraine’s battlefield gains have meant a surging need to pick up the pieces after Russian occupation, even as electricity reserves are holding if no new strikes occur, to ensure habitable conditions as more and more surviving residents require services, and as others return to scenes of devastation.
Restoring electricity is the top priority, amid shifting international assistance such as the end of U.S. grid support, because that often restarts running water, too, says Mr. Mahdysyuk. But before that, the area beneath broken power lines must be de-mined.
Indeed, members of an electricity team reconnecting cables on the outskirts of Balakliia – one of the first towns to see power restored, at the end of September – say they lost two fellow workers in the previous two weeks. One died after stepping on an anti-personnel mine, another when his vehicle hit an anti-tank device.
Ukrainian electricity workers restore power lines damaged during six months of Russian military occupation in Balakliia, Ukraine, Sept. 29, 2022. Ukrainians in liberated territory say the restoration of the electrical grid, and with it often the water supply, is a return to civilization.
“For now, our biggest problem is mines,” says the team leader, who gave the name Andrii. “It’s fine within the cities, but in the fields it’s a disaster because it’s very difficult to see them. There is a lot of [them] around here – it will take years and years to get rid of.”
Yet officials only have a few weeks to execute plans to provide for hundreds of thousands of residents in this region, in their various states of need and distress. Some 50 field kitchens capable of feeding 200 to 300 people each have been ordered. Another 1,000 mobile stoves are on their way.
And authorities will provide nearly 200,000 cubic yards of firewood for those who have no access to it, and may have no other means of keeping warm – or where shelling continues to disrupt repairs, says Mr. Mahdysyuk.
“The level of opportunity and resources we have is not the same as the level of destruction,” he says. People in districts and buildings too destroyed to have services restored soon, such as in Saltivka in Kharkiv city, may be moved.
BC Hydro Rate Freeze Rejection details the BCUC decision enabling a 3% rate increase, citing revenue requirements, debt, and capital costs, affecting electricity bills, with NDP government proposing lifeline rates and low-income relief.
Key Points
It is the BCUC ruling allowing a 3% BC Hydro rate hike, citing cost recovery, debt, and capital needs.
✅ BCUC rejects freeze; 3% increase proceeds April 1, 2018
✅ Rationale: cost recovery, debt, capital expenditures
✅ Relief: lifeline rate, $600 grants, winter payment plan
The B.C. Utilities Commission has rejected a request by the provincial government to freeze rates at BC Hydro for the coming year, meaning a pending rate increase of three percent will come into effect as higher BC Hydro rates on April 1, 2018.
BC Hydro had asked for the three per cent increase, aligning with a rate increase proposal that would add about $2 a month, but, last year, Energy Minister Michelle Mungall directed the Crown corporation to resubmit its request in order to meet an NDP election promise.
"After years of escalating electricity costs, British Columbians deserve a break on their bills," she said at the time.
However, the utilities commission found there was "insufficient regulatory justification to approve the zero per cent rate increase."
"Even these increases do not fully recover B.C. Hydro's forecast revenue requirement, which includes items such as operating costs, new capital expenditures and carrying costs on capital expenditures," the commission wrote in a news release.
Mungall said she was disappointed by the decision.
"We were always clear we were going to the BCUC. We need to respect the role the BCUC has here for the ratepayers and for the public. I'm very disappointed obviously with their decision."
Mungall blamed the previous government for leaving BC Hydro in a financial state where a rate freeze was ultimately not possible.
Last month, Moody's Investors Service calculated BC Hydro's total debt at $22 billion and said it was one of the province's two credit challenges going forward.
"There's quite a financial mess that is a B.C. Liberal legacy after 16 years of government. We have the responsibility as a new government to clean that up."
B.C. Liberal leader Andrew Wilkinson said it was an example of the new government not living up to its campaign promises.
"British Columbians, particularly those on fixed incomes, believed the B.C. NDP when they promised a freeze on hydro bills. They planned accordingly and are now left in the lurch and face higher expenses. This is a government that stumbles into messes that cost all of us because they put rhetoric ahead of planning," he said.
Help on the way?
With the freeze being rejected, Mungall said the government would be going forward on other initiatives to help low-income ratepayers, as advocates' call for change after a fund surplus, including:
Legislating a "lifeline rate" program, allowing people with "demonstrated need" to apply for a lower rate for electricity.
Starting in May, providing an emergency grant of $600 for customers who have an outstanding BC Hydro bill.
Hydro's annual winter payment plan also allows people the chance to spread the payment of bills from December to February out over six months, and, with a two-year rate increase on the horizon, a new pilot program to help people paying their bills begins in July.
Mungall couldn't say whether the government would apply for rate freezes in the future.
"I don't have a crystal ball, and can't predict what might happen in two or three years from now, but we need to act swiftly now," she said.
"I appreciate the [BCUC's] rationale, I understand it, and we'll be moving forward with other alternatives for making life more affordable."
Whether you would prefer Live Online or In-Person
instruction, our electrical training courses can be
tailored to meet your company's specific requirements
and delivered to your employees in one location or at
various locations.
