Manhole explosions close Harvard Square

By Boston Globe


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It was only when Stephen Fopiano noticed the morning's newspapers were missing that he looked around and saw something unusual, even for Harvard Square.

"There was some serious flames coming out of there," Fopiano said as he pointed to the intersection of Dunster Street and Massachusetts Avenue. "There was a lot of flames."

Fopiano was one of dozens who witnessed a persistent fire that sent flames up to 15 feet in the air, following a string of manhole explosions early May 2.

In all, four NStar manholes exploded beginning around 2:30 a.m., forcing partial closure of one of Cambridge's most famous pieces of real estate for about eight hours to both pedestrian and car traffic. MBTA Red Line service continued without interruption, and some bus service was rerouted.

Caroline Allen, an NStar spokeswoman, said crews were working to repair the burned and soaked wiring all weekend, hoping to avoid disruptions of the 24th annual Mayfair, which was held in Harvard Square May 4.

Allen said the cause of the blaze remains under investigation.

Deputy Fire Chief James F. Burns, a department spokesman, said the explosions occurred in three manholes running along the red brick sidewalk in the square and in a fourth at the corner of Dunster and Massachusetts Avenue.

He said that after the initial explosion, lubricating oil used in electrical transmissions caught fire, causing the heavy flames that poured out of the manhole.

Once certain that the problem was limited to the four manholes in the square, Burns said, firefighters allowed the blaze to burn itself out and then sprayed water to cool down the electrical conduit tunnel, so utility workers could begin repairs.

Harvard University classes were not disrupted, but Holyoke Center was closed. Harvard's infirmary was evacuated, and one student was transferred to a Cambridge hospital by ambulance, a Harvard spokesman said.

There were no injuries from the fire, and no substantial damage was reported to businesses in Harvard Square, officials said.

The cable malfunction was akin to a house blowing a fuse, but on a much larger scale, NStar's Allen said. The initial blast knocked out power to 700 customers, but service was fully restored by 12:30 p.m.

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Scottish Wind Delivers Equivalent Of 98% Of Country’s October Electricity Demand

Scotland Wind Energy October saw renewables supply the equivalent of 98 percent of electricity demand, as onshore wind outpaced National Grid needs, cutting emissions and powering households, per WWF Scotland and WeatherEnergy.

 

Key Points

A monthly update showing Scottish onshore wind met the equivalent of 98% of electricity demand in October.

✅ 98% of monthly electricity demand equivalent met by wind

✅ 16 days exceeded total national demand, per data

✅ WWF Scotland and WeatherEnergy cited; lower emissions

 

New figures publicized by WWF Scotland have revealed that wind energy generated the equivalent of 98% of the country’s electricity demand in October, or enough electricity to power millions of Scottish homes across the country.

Scotland has regularly been highlighted as a global wind energy leader, and over the last few years has repeatedly reported record-breaking months for wind generation. Now, it’s all very well and good to say that Scottish wind delivered 98% of the country’s electricity demand, but the specifics are a little different — hence why WWF Scotland always refers to it as wind providing “the equivalent of 98%” of Scotland’s electricity demand. That’s why it’s worth looking at the statistics provided by WWF Scotland, sourced from WeatherEnergy, part of the European EnergizAIR project:

  • National Grid demand for the month – 1,850,512 MWh
  • What % of this could have been provided by wind power across Scotland – 98%
  • Best day – 23rd October 2018, generation was 105,900.94 MWh, powering 8.72m homes, 356% of households. Demand that day was 45,274.5MWh – wind generation was 234% of that.
  • Worst day – 18th October 2018 when generation was 18,377.71MWh powering 1,512,568 homes, 62% of households. Demand that day was 73,628.5MWh – wind generation was 25%
  • How many days generation was over 100% of households – 27
  • How many days generation was over 100% of demand – 16

“What a month October proved to be, with wind powering on average 98 per cent of Scotland’s entire electricity demand for the month, at a time when wind became the UK’s main power source and exceeding our total demand for a staggering 16 out of 31 days,” said Dr Sam Gardner, acting director at WWF Scotland.

“These figures clearly show wind is working, it’s helping reduce our emissions and is the lowest cost form of new power generation. It’s also popular, with a recent survey also showing more and more people support turbines in rural areas. That’s why it’s essential that the UK Government unlocks market access for onshore wind at a time when we need to be scaling up electrification of heat and transport.”

Alex Wilcox Brooke, Weather Energy Project Manager at Severn Wye Energy Agency, added: “Octobers figures are a prime example of how reliable & consistent wind production can be, with production on 16 days outstripping national demand.”

 

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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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Climate change poses high credit risks for nuclear power plants: Moody's

Nuclear Plant Climate Risks span flood risk, heat stress, and water scarcity, threatening operations, safety systems, and steam generation; resilience depends on mitigation investments, cooling-water management, and adaptive maintenance strategies.

 

Key Points

Climate-driven threats to nuclear plants: floods, heat, and water stress requiring resilience and mitigation.

✅ Flooding threats to safety and cooling systems

✅ Heat stress reduces thermal efficiency and output

✅ Water scarcity risks limit cooling capacity

 

 

Climate change can affect every aspect of nuclear plant operations like fuel handling, power and steam generation and the need for resilient power systems planning, maintenance, safety systems and waste processing, the credit rating agency said.

However, the ultimate credit impact will depend upon the ability of plant operators to invest in carbon-free electricity and other mitigating measures to manage these risks, it added.
Close proximity to large water bodies increase the risk of damage to plant equipment that helps ensure safe operation, the agency said in a note.

Moody’s noted that about 37 gigawatts (GW) of U.S. nuclear capacity is expected to have elevated exposure to flood risk and 48 GW elevated exposure to combined rising heat, extreme heat costs and water stress caused by climate change.

Parts of the Midwest and southern Florida face the highest levels of heat stress, while the Rocky Mountain region and California face the greatest reduction in the availability of future water supply, illustrating the need for adapting power generation to drought strategies, it said.

Nuclear plants seeking to extend their operations by 20, or even 40 years, beyond their existing 40-year licenses in support of sustaining U.S. nuclear power and decarbonization face this climate hazard and may require capital investment adjustments, Moody’s said, as companies such as Duke Energy climate report respond to investor pressure for climate transparency.

“Some of these investments will help prepare for the increasing severity and frequency of extreme weather events, highlighting that the US electric grid is not designed for climate impacts today.”

 

 

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British Columbia Accelerates Clean Energy Shift

BC Hydro Grid Modernization accelerates clean energy and electrification, upgrading transmission lines, substations, and hydro dams to deliver renewable power for EVs and heat pumps, strengthen grid reliability, and enable industrial decarbonization in British Columbia.

 

Key Points

A $36B, 10-year plan to expand and upgrade B.C.'s clean grid for electrification, reliability, and industrial growth.

✅ $36B for lines, substations, and hydro dam upgrades

✅ Enables EV charging, heat pumps, and smart demand response

✅ Prioritizes industrial electrification and Indigenous partnerships

 

In a significant move towards a clean energy transition, British Columbia has announced a substantial $36-billion investment to enlarge and upgrade its electricity grid over the next ten years. The announcement last Tuesday from BC Hydro indicates a substantial 50 percent increase from its prior capital plan. A major portion of this investment is directed towards new consumer connections and improving current infrastructure, including substations, transmission lines, and hydro dams for more efficient power generation.

The catalyst behind this major investment is the escalating demand for clean energy across residential, commercial, and industrial sectors in British Columbia. Projections show a 15 percent rise in electricity demand by 2030. According to the Canadian Climate Institute's models, achieving Canada’s climate goals will require extensive electrification across various sectors, raising questions about a net-zero grid by 2050 nationwide.

BC Hydro is planning substantial upgrades to the electrical grid to meet the needs of a growing population, decreasing industry carbon emissions, and the shift towards clean technology. This is vital, especially as the province works towards improving housing affordability and as households face escalating costs from the impacts of climate change and increasing exposure to harsh weather events. Affordable, reliable power and access to clean technologies such as electric vehicles and heat pumps are becoming increasingly important for households.

British Columbia is witnessing a significant shift from fossil fuels to clean electricity in powering homes, vehicles, and workplaces. Electric vehicle usage in B.C. has increased twentyfold in the past six years. Last year, one in every five new light-duty passenger vehicles sold in B.C. was electric – the highest rate in Canada. Additionally, over 200,000 B.C. homes are now equipped with heat pumps, indicating a growing preference for the province’s 98 percent renewable electricity.

The investment also targets reducing industrial emissions and attracting industrial investment. For instance, the demand for transmission along the North Coastline, from Prince George to Terrace, is expected to double this decade, especially from sectors like mining. Mining companies are increasingly looking for locations with access to clean power to reduce their carbon footprint.

This grid enhancement plan in B.C. is reflective of similar initiatives in provinces like Quebec and the legacy of Manitoba hydro history in building provincial systems. Hydro-Québec announced a substantial $155 to $185 billion investment in its 2035 Action Plan last year, aimed at supporting decarbonization and economic growth. By 2050, Hydro-Québec predicts a doubling of electricity demand in the province.

Both utilities’ strategies focus on constructing new facilities and enhancing existing assets, like upgrading dams and transmission lines. Hydro-Québec, for instance, includes energy efficiency goals in its plan to double customer savings and potentially save over 3,500 megawatts of power.

However, with this level of investment, provinces need to engage in dialogue about priorities and the optimal use of clean electricity resources, with concepts like macrogrids offering potential benefits. Quebec, for instance, has shifted from a first-come, first-served basis to a strategic review process for significant new industrial power requests.

B.C. is also moving towards strategic prioritization in its energy strategy, evident in its recent moratorium on new connections for virtual currency mining due to their high energy consumption.

Indigenous partnership and leadership are also key in this massive grid expansion. B.C.’s forthcoming Call for Power and Quebec’s financial partnerships with Indigenous communities indicate a commitment to collaborative approaches. British Columbia has also allocated $140 million to support Indigenous-led power projects.

Regarding the rest of Canada, electricity planning varies in provinces with deregulated markets like Ontario and Alberta. However, these provinces are adapting too, and the federal government has funded an Atlantic grid study to improve regional planning efforts. Ontario, for example, has provided clear guidance to its system operator, mirroring the ambition in B.C. and Quebec.

Utilities are rapidly working to not only expand and modernize energy grids but also to make them more resilient, affordable, and smarter, as demonstrated by recent California grid upgrades funding announcements across the sector. Hydro-Québec focuses on grid reliability and affordability, while B.C. experiments with smart-grid technologies.

Both Ontario and B.C. have programs encouraging consumers to reduce consumption in real-time, demonstrating the potential of demand-side management. A recent instance in Alberta showed how customer participation could prevent rolling blackouts by reducing demand by 150 megawatts.

This is a crucial time for all Canadian provinces to develop larger, smarter energy grids, including a coordinated western Canadian electricity grid approach for a sustainable future. Utilities are making significant strides towards this goal.
 

 

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Data Show Clean Power Increasing, Fossil Fuel Decreasing in California

California clean electricity accelerates with renewables as solar and wind surge, battery storage strengthens grid resilience, natural gas declines, and coal fades, advancing SB 100 targets, carbon neutrality goals, and affordable, reliable power statewide.

 

Key Points

California clean electricity is the state's transition to renewable, zero-carbon power, scaling solar, wind and storage.

✅ Solar generation up nearly 20x since 2012

✅ Natural gas power down 20%; coal nearly phased out

✅ Battery storage shifts daytime surplus to evening demand

 

Data from the California Energy Commission (CEC) highlight California’s continued progress toward building a more resilient grid, achieving 100 percent clean electricity and meeting the state’s carbon neutrality goals.

Analysis of the state’s Total System Electric Generation report shows how California’s power mix has changed over the last decade. Since 2012:

Solar generation increased nearly twentyfold from 2,609 gigawatt-hours (GWh) to 48,950 GWh.

  • Wind generation grew by 63 percent.
  • Natural gas generation decreased 20 percent.
  • Coal has been nearly phased-out of the power mix, and renewable electricity surpassed coal nationally in 2022 as well.

In addition to total utility generation, rooftop solar increased by 10 times generating 24,309 GWh of clean power in 2022. The state’s expanding fleet of battery storage resources also help support the grid by charging during the day using excess renewable power for use in the evening.

“This latest report card showing how solar energy boomed as natural gas powered electricity experienced a steady 20 percent decline over the last decade is encouraging,” said CEC Vice Chair Siva Gunda. “Even as climate impacts become increasingly severe, California remains committed to transitioning away from polluting fossil fuels and delivering on the promise to build a future power grid that is clean, reliable and affordable.”

Senate Bill 100 (2018) requires 100 percent of California’s electric retail sales be supplied by renewable and zero-carbon energy sources by 2045. To keep the state on track, last year Governor Gavin Newsom signed SB 1020, establishing interim targets of 90 percent clean electricity by 2035 and 95 percent by 2040.

The state monitors progress through the Renewables Portfolio Standard (RPS), which tracks the power mix of retail sales, and regional peers such as Nevada's RPS progress offer useful comparison. The latest data show that in 2021 more than 37 percent of the state’s electricity came from RPS-eligible sources such as solar and wind, an increase of 2.7 percent compared to 2020. When combined with other sources of zero-carbon energy such as large hydroelectric generation and nuclear, nearly 59 percent of the state’s retail electricity sales came from nonfossil fuel sources.

The total system electric generation report is based on electric generation from all in-state power plants rated 1 megawatt (MW) or larger and imported utility-scale power generation. It reflects the percentage of a specific resource compared to all power generation, not just retail sales. The total system electric generation report accounts for energy used for water conveyance and pumping, transmission and distribution losses and other uses not captured under RPS.

 

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Opinion: With deregulated electricity, no need to subsidize nuclear power

Pennsylvania Electricity Market Deregulation has driven competitive pricing, leveraged low-cost natural gas, and spurred private investment, jobs, and efficient power plants, while nuclear subsidies threaten wholesale market signals and long-term consumer savings.

 

Key Points

Policy that opens generation to competition, leverages cheap gas, lowers rates, and resists subsidies for nuclear plants.

✅ Competitive wholesale pricing benefits consumers statewide

✅ Gas-driven plants add efficient, flexible capacity and jobs

✅ Nuclear subsidies distort market signals and raise costs

 

For decades, the government regulation of Pennsylvania's electricity markets dictated all aspects of power generation resources in the state, thus restricting market-driven prices for consumers and hindering new power plant development and investment.

Deregulation has enabled competitive markets to drive energy prices downward, as recent grid auction payouts fell 64% indicate, which has transformed Pennsylvania from a higher-electricity-cost state to one with prices below the national average.

Recently, the economic advantage of abundant low-cost natural gas has spurred an influx of billions of dollars of private capital investment and thousands of jobs to construct environmentally responsible natural gas power generation facilities throughout the commonwealth — including our three power generation facilities in operation and one presently under construction.

Calpine is an independent power provider with a national portfolio of 80 highly efficient power plants in operation or under construction with an electric generating capacity of approximately 26,000 megawatts. Collectively, these resources can provide sufficient power for more than 30 million residential homes. We are not a regulated utility receiving a guaranteed rate of return on investment. Rather, Calpine competes to sell wholesale power into the electric markets, and the economics of supply and demand are fundamental to the success of our business.

Pennsylvania's deregulated electricity market is working. Consumers are benefiting from low-cost natural gas, as broader evidence shows competition benefits consumers and the environment across markets, and companies such as Calpine are investing billions of dollars and creating thousands of jobs to build advanced, energy efficient, environmentally responsible and flexible power generating facilities.

There are presently seven electric generating projects under construction in the commonwealth, representing about a $7 billion capital investment that will produce about 7,000 megawatts of efficient electrical power, with additional facilities being planned.

Looking back 20 years following the enactment of the Pennsylvania Electricity Generation Customer Choice and Competition Act, Pennsylvania's regulators and policymakers must conclude that the results of a free and fair market-driven structure have delivered indisputable benefits to the consumer, even amid potential winter rate spikes for residents, and the Pennsylvania economy.

While consumers are now reaping the benefits of open and competitive electricity markets, we see challenges on the horizon that could threaten the foundation of those markets. Due to pressure from nuclear power generators, state policymakers throughout the nation have been increasing efforts to impact the generation mix in their respective states by offering ratepayer funded subsidies to existing nuclear generation resources or by considering a market structure overhaul in New England.

Subsidizing one power generation type over others is having a significant, negative impact on wholesale electric markets, competitive retails markets and ultimately the cost the consumer will have to pay, and can exacerbate disruptions in coal and nuclear industries that strain the economy and risk brownouts.

In Pennsylvania, these subsidies would follow nearly $9 billion already paid by ratepayers to help the commonwealth's nuclear industry transition from regulated to competitive energy markets.

The deregulation of Pennsylvania's electricity markets in the late 1990s allowed the nuclear industry to receive billions of dollars from ratepayers to recover "stranded costs" related to investments in the commonwealth's nuclear plants. These costs were negotiated amounts based on settlements with Pennsylvania's Public Utility Commission to allow the nuclear industry to prepare and transition to competitive electricity markets.

Enough is enough. Regulatory or governmental interference in well functioning markets does not lead to better outcomes. Pennsylvania's state Legislature should not pick winners and losers by enacting legislation that would create an uneven playing field that subsidizes nuclear generating resources in the commonwealth.

William Ferguson is regional vice president for Calpine Corp.

 

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