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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.
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."
Trump NEPA Overhaul streamlines environmental reviews, tightening 'reasonably foreseeable' effects, curbing cumulative impacts, codifying CEQ greenhouse gas guidance, expediting permits for pipelines, highways, and wind projects with two-year EIS limits and one lead agency.
Trump NEPA Overhaul streamlines reviews, trims cumulative impacts, keeps GHG analysis for foreseeable effects.
✅ Limits cumulative and indirect impacts; emphasizes foreseeable effects
✅ Caps EIS at two years; one-year environmental assessments
✅ One lead agency; narrower NEPA triggers for low federal funding
President Trump has announced plans for overhauling rules surrounding the nation’s bedrock environmental law, and administration officials refuted claims they were downplaying greenhouse gas emissions, as the administration also pursues replacement power plant rules in related areas.
The president, during remarks at the White House with supporters and Cabinet officials, said he wanted to fix the nation’s “regulatory nightmare” through new guidelines for implementing the National Environmental Policy Act.
“America is a nation of builders,” he said. But it takes too long to get a permit, and that’s “big government at its absolute worst.”
The president said, “We’re maintaining America’s world-class standards of environmental protection.” He added, “We’re going to have very strong regulation, but it’s going to go very quickly.”
NEPA says the federal government must consider alternatives to major projects like oil pipelines, highways and bridges that could inflict environmental harm. The law also gives communities input.
The Council on Environmental Quality has not updated the implementing rules in decades, and both energy companies and environmentalists want them reworked, even as some industry groups warned against rushing electricity pricing changes under related policy debates.
But they patently disagree on how to change the rules.
A central fight surrounds whether the government considers climate change concerns when analyzing a project.
Environmentalists want agencies to look more at “cumulative” or “indirect” impacts of projects. The Trump plan shuts the door on that.
“Analysis of cumulative effects is not required,” the plan states, adding that CEQ “proposes to make amendments to simplify the definition of effects by consolidating the definition into a single paragraph.”
CEQ Chairwoman Mary Neumayr told reporters during a conference call that definitions in the current rules were the “subject of confusion.”
The proposed changes, she said, do in fact eliminate the terms “cumulative” and “indirect,” in favor of more simplified language.
Effects must be “reasonably foreseeable” and require a “reasonably close causal relationship” to the proposed action, she added. “It does not exclude considerations of greenhouse gas emissions,” she said, pointing to parallel EPA proposals for new pollution limits on coal and gas power plants as context.
Last summer, CEQ issued proposed guidance on greenhouse gas reviews in project permitting. The nonbinding document gave agencies broad authority when considering emissions (Greenwire, June 21, 2019).
Environmentalists scoffed and said the proposed guidance failed to incorporate the latest climate science and look at how projects could be more resilient in the face of severe weather and sea-level rise.
The proposed NEPA rules released today include provisions to codify the proposed guidance, which has also been years in the making.
Other provisions
Senior administration officials sought to downplay the effect of the proposed NEPA rules by noting the underlying statute will remain the same.
“If it required NEPA yesterday, it will require NEPA under the new proposal,” an official said when asked how the changes might apply to pipelines like Keystone XL.
And yet the proposed changes could alter the “threshold consideration” that triggers NEPA review. The proposal would exclude projects with minimal federal funding or “participation.”
The Trump plan also proposes restricting an environmental impact statement to two years and an environmental assessment to one.
Neumayr said the average EIS takes 4 ½ years and in some cases longer. Democrats have disputed those timelines. Further, just 1% of all federal actions require an EIS, they argue.
The proposal would also require one agency to take the lead on permitting and require agency officials to “timely resolve disputes that may result in delays.”
In general, the plan calls for environmental documents to be “concise” and “serve their purpose of informing decision makers.”
Both Interior Secretary David Bernhardt and EPA Administrator Andrew Wheeler, whose agency moved to rewrite coal power plant wastewater limits in separate actions, were at the White House for the announcement.
Reaction
An onslaught of critics have said changes to NEPA rules could be the administration’s most far-reaching environmental rollback, and state attorneys general have mounted a legal challenge to related energy actions as well.
The League of Conservation Voters declared the administration was again trying to “sell out the health and well-being of our children and families to corporate polluters.”
On Capitol Hill, House Speaker Nancy Pelosi (D-Calif.) said during a news conference the administration would “no longer enforce NEPA.”
“This means more polluters will be right there, next to the water supply of our children,” she said. “That’s a public health issue. Their denial of climate, they are going to not use the climate issue as anything to do with environmental decisionmaking.”
Sen. Sheldon Whitehouse (D-R.I.) echoed the sentiment, saying he didn’t need any more proof that the fossil fuel industry had hardwired the Trump administration “but we got it anyway.”
Energy companies, including firms focused on renewable energy development, are welcoming the “clarity” of the proposed NEPA rules, even as debates continue over a clean electricity standard in federal climate policy.
“The lack of clarity in the existing NEPA regulations has led courts to fill the gaps, spurring costly litigation across the sector, and has led to unclear expectations, which has caused significant and unnecessary delays for infrastructure projects across the country,” the Interstate Natural Gas Association of America said in a statement.
Last night, the American Wind Energy Association said NEPA rules have caused “unreasonable and unnecessary costs and long project delays” for land-based and offshore wind energy and transmission development.
Trump has famously attacked the wind energy industry for decades, dating back to his opposition to a Scottish wind turbine near his golf course.
The president today said he won’t stop until “gleaming new infrastructure has made America the envy of the world again.”
When asked whether he thought climate change was a “hoax,” as he once tweeted, he said no. “Nothing’s a hoax about that,” he said.
The president said there’s a book about climate he’s planning to read. He said, “It’s a very serious subject.”
UK Electricity Interconnectors secure capacity market subsidies, supporting winter reliability with seabed cables to France and Belgium via the Channel Tunnel, lowering consumer costs, squeezing coal, and challenging new gas plants through cross-border energy trading.
High-voltage cables linking Britain to Europe, securing backup capacity, cutting costs and boosting winter reliability.
✅ Won capacity market contracts at record-low prices
✅ Cables to France and Belgium via Channel Tunnel, seabed routes
✅ Squeezes coal, challenges new gas; renewables may join market
New electricity cables across the Channel to France and Belgium will be a key part of keeping Britain’s lights on during winter amid record electricity prices across Europe in the early 2020s, after their owners won backup power subsidies in a government auction this week.
For the first time, interconnector operators successfully bid for a slice of hundreds of millions’ worth of contracts in the capacity market. That will help cut costs for consumers, given how electricity is priced in Europe today, and squeeze out old coal power plants.
Three new interconnectors are currently being built to Europe, almost doubling existing capacity, with one along the Channel Tunnel and two on the seabed: one between Kent and Zeebrugge and one from Hampshire to Normandy.
The interconnectors were success stories in this week’s capacity auction, which saw power firms bid to provide backup electricity in the winter of 2021/22. Prices for the four-year contracts hit a record low of £8.40 per kilowatt per year, which analysts described as a shock and well below expectations.
One industry source said the figure was “miles away” from what is needed to encourage companies to build big new gas power stations, which some argue are necessary to fill the gap when the UK’s ageing nuclear reactors close as Europe loses nuclear power across the region over the next decade.
While bad news for those firms, the low price is good for consumers. The subsidies will add about £525m to energy bills, or £5.68 for the average household, compared with £11 for the year before, according to analysts Cornwall Insight.
Existing gas power stations scooped up most of the contracts, but new gas ones lost out, as did several coal plants. Battery storage plants, a standout success in the last auction, fared comparatively poorly after changes to the rules.
Experts at Bernstein bank said the the misses by coal meant that around half the UK’s remaining coal power capacity could close from October 2019, when existing capacity market contracts run out. Chaitanya Kumar, policy adviser at thinktank Green Alliance, said: “Coal’s exit from the UK’s energy system just moved a step closer as coal contracts fell by half compared with last year.”
Tom Edwards, an analyst at Cornwall Insight, said that more interconnectors were likely to bid into future rounds of the capacity market, such as the cable being laid between Norway and the UK. Relying on foreign power supplies was fine, he said, provided Brexit did not make energy trading more difficult and the interconnectors delivered at times of need, where events like Irish grid price spikes illustrate the stress points.
However, one industry source, who wants to see new gas plants built in the UK, said the results showed that the system was not working, amid UK peak power prices that have climbed in recent trading. “That self-sufficiency doesn’t seem to be a priority at a time when we’re breaking away from Europe is a bit weird,” they said.
But the prospects for new gas plants in future rounds of the capacity market look bleak. They will very likely face a new source of competition next year, if energy regulator Ofgem approves a proposal to allow renewables to compete too.
Alberta Renewable Energy Market is accelerating as wind and solar prices fall, corporate PPAs expand, and a deregulated, energy-only system, AESO outlooks, and TIER policy drive investment across the province.
An open, energy-only Alberta market where wind and solar growth is driven by corporate PPAs, AESO outlooks, and TIER.
✅ Energy-only, deregulated grid enables private investment
✅ Corporate PPAs lower costs and hedge power price risk
✅ AESO forecasts and TIER policy support renewables
By Chris Varcoe, Calgary Herald
A few things are abundantly clear about the state of renewable energy in Alberta today.
First, the demise of Alberta’s Renewable Electricity Program (REP) under the UCP government isn’t going to see new projects come to a screeching halt.
In fact, new developments are already going ahead.
And industry experts believe private-sector companies that increasingly want to purchase wind or solar power are going to become a driving force behind even more projects in Alberta.
BluEarth Renewables CEO Grant Arnold, who spoke Wednesday at the Canadian Wind Energy Association conference, pointed out the sector is poised to keep building in the province, even with the end of the REP program that helped kick-start projects and triggered low power prices.
“The fundamentals here are, I think, quite fantastic — strong resource, which leads to really competitive wind prices . . . it’s now the cheapest form of new energy in the province,” he told the audience.
“Alberta is in a fundamentally good place to grow the wind power market.”
Unlike other provinces, Alberta has an open, deregulated marketplace, which create opportunities for private-sector investment and renewable power developers as well.
The recent decision by the Kenney government to stick with the energy-only market, instead of shifting to a capacity market, is seen as positive for Alberta's energy future by renewable electricity developers.
There is also increasing interest from corporations to buy wind and solar power from generators — a trend that has taken off in the United States with players such as Google, General Motors and Amazon — and that push is now emerging in Canada.
“It’s been really important in the U.S. for unlocking a lot of renewable energy development,” said Sara Hastings-Simon, founding director of the Business Renewable Centre Canada, which seeks to help corporate buyers source renewable energy directly from project developers.
“You have some companies where . . . it’s what their investors and customers are demanding. I think we will see in Alberta customers who see this as a good way to meet their carbon compliance requirements.
“And the third motivation to do it is you can get the power at a good price.”
Just last month, Perimeter Solar signed an agreement with TC Energy to supply the Calgary-based firm with 74 megawatts from its solar project near Claresholm.
More deals in the industry are being discussed, and it’s expected this shift will drive other projects forward.
There is increasing interest from corporations to buy solar and wind energy directly from generators.
“The single-biggest change has been the price of wind and solar,” Arnold said in an interview.
“Alberta looks really, really bright right now because we have an open market. All other provinces, for regulatory reasons, we can’t have this (deal) . . . between a generator and a corporate buyer of power. So Alberta has a great advantage there.”
These forces are emerging as the renewable energy industry has seen dramatic change in recent years in Alberta, with costs dropping and an array of wind and solar developments moving ahead, even as solar expansion faces challenges in the province.
The former NDP government had an aggressive target to see green energy sources make up 30 per cent of all electricity generation by 2030.
Last week, the Alberta Electric System Operator put out its long-term outlook, with its base-case scenario projecting moderate demand growth for power over the next two decades. However, the expected load growth — expanding by an average of 0.9 per cent annually until 2039 — is only half the rate seen in the past 20 years.
Natural gas will become the main generation source in the province as coal-fired power (now comprising more than one-third of generation) is phased out.
Renewable projects initiated under the former NDP government’s REP program will come online in the near term, while “additional unsubsidized renewable generation is expected to develop through competitive market mechanisms and support from corporate power purchase agreements,” the report states.
AESO forecasts installed generation capacity for renewables will almost double to about 19 per cent by 2030, with wind and solar increasing to 21 per cent by 2039.
Another key policy issue for the sector will likely come within the next few weeks when the provincial government introduces details of its new Technology Innovation and Emissions Reduction program (TIER).
The initiative will require large industrial emitters to reduce greenhouse gas emissions to a benchmark level, pay into the technology fund, or buy offsets or credits. The carbon price is expected to be around $20 to $30 a tonne, and the system will kick in on Jan. 1, 2020.
Industry players point out the decision to stick with Alberta’s energy-only market along with the details surrounding TIER, and a focus by government on reducing red tape, should all help the sector attract investment.
“It is pretty clear there is a path forward for renewables here in the province,” said Evan Wilson, regional director with the Canadian Wind Energy Association.
All of these factors are propelling the wind and solar sector forward in the province, at the same time the oil and gas sector faces challenges to grow.
But it doesn’t have to be an either/or choice for the province moving forward. We’re going to need many forms of energy in the coming decades, and Alberta is an energy powerhouse, with potential to develop more wind and solar, as well as oil and natural gas resources.
“What we see sometimes is the politics and discussion around renewables or oil becomes a deliberate attempt to polarize people,” Arnold added.
“What we are trying to show, in working in Alberta on renewable projects, is it doesn’t have to be polarizing. There are a lot of solutions.
“The combination of solutions is part of what we need to talk about.”
PG&E Public Safety Power Shutoff reduces wildfire risk during extreme winds, triggering de-energization across the North Bay and Sierra Foothills under red flag warnings, with safety inspections and staged restoration to improve grid resilience.
A utility protocol to de-energize lines during extreme fire weather, reducing ignition risks and improving grid safety.
✅ Triggered by red flag warnings, humidity, wind, terrain
✅ Temporary de-energization of transmission and distribution lines
✅ Inspections precede phased restoration to minimize wildfire risk
PG&E purposefully shut off electricity to nearly 60,000 Northern California customers Sunday night, aiming to mitigate wildfire risks from power lines during extreme winds.
Pacific Gas and Electric planned to restore power to 70 percent of affected customers in the North Bay and Sierra Foothills late Monday night. As crews inspect lines for safety by helicopter, vehicles and on foot, the remainder will have power sometime Tuesday.
While it was the first time the company shut off power for public safety, PG&E announced its criteria and procedures for such an event in June, said spokesperson Paul Doherty. After wildfires devastated Northern California's wine country last October, he added, PG&E developed its community wildfire safety program division to make power grids and communities more resilient, and prepares for winter storm season through enhanced local response.
Two sagging PG&E power lines caused one of those wildfires during heavy winds, killing four people and injuring a firefighter, the California Department of Forestry and Fire Protection determined earlier this month. Trees or tree branches hitting PG&E power lines started another four wildfires in October 2017. Altogether, the power company has been blamed for igniting 13 wildfires last year.
"We're adapting our electric system our operating practices to improve safety and reliability," Doherty said of the safety program. "That's really the bottom line for us."
Turning off power to so many customers was a "last resort given the extreme fire danger conditions these communities are experiencing," Pat Hogan, senior vice president of electric operations, said in a statement. Conditions that led the company to shut off power included the National Weather Service's red flag fire warnings, humidity levels, sustained winds, temperature, dry fuel and local terrain, Doherty said, amid possible rolling blackouts during grid strain.
The company de-energized more than 78 miles of transmission lines and more than 2,150 miles of distribution power lines Sunday night. Many schools in the area were closed Monday because of the planned power outage, highlighting unequal access to electricity across communities.
Late Saturday and early Sunday, PG&E warned 97,000 customers in 12 counties that the shut off might go into effect. Through automated calls, texts and emails, the company encouraged customers to have drinking water, canned food, flashlights, prescriptions and baby supplies on hand.
Power was also turned off in Southern California on Monday.
San Diego Gas & Electric turned off service to about 360 customers near Cleveland National Forest, where multiple fires have scorched large swaths of land in recent years.
SDG&E has pre-emptively shut off power to customers in the past, most recently in December when 14,000 customers went without power.
Southern California Edison, the primary electric provider across Southern California — including Los Angeles — has a similar power shutoff program. As of Monday night, SCE had yet to turn off power in any of its service areas, a spokesperson told USA TODAY.
ABL has secured a contract for the UK Subsea Power Link, highlighting ABL Group’s marine warranty role in Eastern Green Link 2, a 2 GW offshore electricity superhighway connecting Scotland and England to enhance grid reliability and renewable energy transmission.
ABL Group has been appointed to provide marine warranty survey services for the 2 GW Eastern Green Link 2 subsea interconnector between Scotland and England.
✅ Manages vessel suitability checks, installation oversight, and DP assurance
✅ Strengthens UK grid reliability and advances the clean energy transition
✅ Sizeable contract valued between USD 1 million and 3 million
Energy and marine consultancy ABL, a subsidiary of ABL Group, has been awarded a contract by Eastern Green Link 2 (EGL2) to provide marine warranty survey (MWS) services for the installation of a new 2 GW subsea power connection between Scotland and England.
EGL2 is one of the United Kingdom’s most significant energy-infrastructure projects, involving the creation of a 505-kilometre “electricity superhighway” that will enable simultaneous power transfer between Peterhead in Aberdeenshire and Drax in North Yorkshire, mirroring a renewable power link announced for the same corridor recently. The project is designed to strengthen grid resilience, integrate renewable energy from Scotland’s offshore resources, and advance the UK’s broader energy transition goals.
Under the terms of the contract, ABL will be responsible for the technical review and approval of the project and procedural documentation, as well as conducting suitability surveys of the proposed fleet for marine transportation and installation operations. The company will also provide dynamic positioning (DP) assurance where required and will review and approve all warranted operations through on-site attendances, reflecting practices used on projects like the Great Northern Transmission Line in North America.
Cable-laying operations for the link are scheduled to take place between January and September 2028, amid wider efforts to fast-track grid connections across the UK. According to ABL, the engagement represents a “sizeable” contract, valued between USD 1 million and 3 million.
“This appointment reflects ABL's reputation as a trusted MWS partner for major power transmission infrastructure development and reinforces our position at the forefront of supporting the UK's energy transition,” said Hege Norheim, CEO of ABL Group. “We look forward to contributing to this strategic initiative.”
The subsea interconnector, known as Eastern Green Link 2, will transmit up to 2 gigawatts of electricity—enough to power approximately 2 million homes. It forms part of the Great Grid Upgrade, National Grid’s nationwide program to modernize and expand the transmission network in preparation for a low-carbon future, alongside a recent 2 GW substation milestone.
By linking renewable-rich northern Scotland with high-demand regions in England, EGL2 is expected to reduce congestion on the existing grid by leveraging HVDC technology to improve transfer efficiency, enhance security of supply, and facilitate the more efficient flow of surplus renewable energy south. The connection will also support the UK government’s target of decarbonizing the electricity system by 2035.
ABL’s appointment follows a period of intensive marine and geotechnical surveys along the proposed cable route to assess seabed conditions and environmental sensitivities. The company’s marine warranty oversight will ensure that transportation and installation operations meet strict safety, technical, and environmental standards demanded by insurers and project partners, as seen in a recent cross-border transmission approval in North America.
For ABL Group, which provides engineering and risk services to the offshore energy and marine industries worldwide, the contract marks another milestone in its expanding portfolio of subsea power and transmission projects across Europe. With operations set to begin in 2028, the Eastern Green Link 2 initiative represents both a major engineering challenge and a key enabler of the UK’s offshore energy ambitions, echoing a recent offshore wind power milestone in the U.S.
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