U.S. Secretary of Energy Steven Chu announced selections for the award of approximately $40 million in total to two teams led by Pittsburgh-based Westinghouse Electric Co. and San Diego-based General Atomics for conceptual design and planning work for the Next Generation Nuclear Plant (NGNP).
The results of this work will help the Administration determine whether to proceed with detailed efforts toward construction and demonstration of the NGNP. If successful, the NGNP Demonstration Project will demonstrate high-temperature gas-cooled reactor technology that will be capable of producing electricity as well as process heat for industrial applications and will be configured for low technical and safety risk with highly reliable operations. Final cost-shared awards are subject to the negotiation of acceptable terms and conditions.
About 16 percent of the nation's greenhouse gas emissions come from industrial process heat applications. The process heat or steam generated by the high-temperature nuclear reactors could be used for highly-efficient electricity co-generation, which has the potential to help energy-intensive industries, such as petrochemical producers, reduce carbon dioxide emissions.
"This investment reflects President Obama's commitment to building the next generation of nuclear reactors that will create thousands of jobs and supply the clean energy to power our economy," said Secretary Chu. "It's time for America to recapture the lead in the nuclear energy industry and lay the foundation for a stronger, cleaner, and more competitive economic future."
The NGNP project is being conducted in two phases. Phase 1 comprises research and development, conceptual design and development of licensing requirements. The selections will support the development of conceptual designs, cost and schedule estimates for demonstration project completion and a business plan for integrating Phase 2 activities. The Department of Energy will use information from its independent Federal advisory committee, the Nuclear Energy Advisory Committee, information and data gathered in Phase 1, and other factors in determining whether the project should continue to Phase 2.
Phase 2 would entail detailed design, license review and construction of a demonstration plant.
The Department will now negotiate the final terms and conditions for the awards with the intention of completing conceptual designs by August 31.
Duke Energy Clean Energy Strategy targets smart grid upgrades, wind and solar expansion, efficient gas, and high-reliability nuclear, cutting CO2, boosting decarbonization, and advancing energy efficiency and reliability for the Carolinas.
Key Points
A plan investing in smart grids, renewables, gas, and nuclear to cut CO2 and enhance reliability and efficiency by 2030.
✅ US$25bn smart grid upgrades; US$11bn renewables and gas
✅ 40% CO2 reduction and >80% low-/zero-carbon generation by 2030
The US power group Duke Energy plans to invest US$25bn on grid modernization over the 2017-2026 period, including the implementation of smart grid technologies to cope with the development of renewable energies, along with US$11bn on the expansion of renewable (wind and solar) and gas-fired power generation capacities.
The company will modernize its fleet and expects more than 80% of its power generation mix to come from zero and lower CO2 emitting sources, aligning with nuclear and net-zero goals, by 2030. Its current strategy focuses on cutting down CO2 emissions by 40% by 2030. Duke Energy will also promote energy efficiency and expects cumulative energy savings - based on the expansion of existing programmes - to grow to 22 TWh by 2030, i.e. the equivalent to the annual usage of 1.8 million households.
#google#
Duke Energy’s 11 nuclear generating units posted strong operating performance in 2017, as U.S. nuclear costs hit a ten-year low, providing the Carolinas with nearly 90 billion kilowatt-hours of carbon-free electricity – enough to power more than 7 million homes.
Globally, China's nuclear program remains on a steady development track, underscoring broader industry momentum.
“Much of our 2017 success is due to our focus on safety and work efficiencies identified by our nuclear employees, along with ongoing emphasis on planning and executing refueling outages to increase our fleet’s availability for producing electricity,” said Preston Gillespie, Duke Energy chief nuclear officer.
Some of the nuclear fleet’s 2017 accomplishments include, as a new U.S. reactor comes online nationally:
The 11 units achieved a combined capacity factor of 95.64 percent, second only to the fleet’s 2016 record of 95.72 percent, marking the 19th consecutive year of attaining a 90-plus percent capacity factor (a measure of reliability).
The two units at Catawba Nuclear Station produced more than 19 billion kilowatt-hours of electricity, and the single unit at Harris Nuclear Plant generated more than 8 billion kilowatt-hours, both setting 12-month records.
Brunswick Nuclear Plant unit 2 achieved a record operating run.
Both McGuire Nuclear Station units completed their shortest refueling outages ever and unit 1 recorded its longest operating run.
Oconee Nuclear Station unit 2 achieved a fleet record operating run.
The Robinson Nuclear Plant team completed the station’s 30th refueling outage, which included a main generator stator replacement and other life-extension activities, well ahead of schedule.
“Our nuclear employees are committed to providing reliable, clean electricity every day for our Carolinas customers,” added Gillespie. “We are very proud of our team’s 2017 accomplishments and continue to look for additional opportunities to further enhance operations.”
California income-based utility charges face bipartisan pushback as the PUC weighs fixed fees for PG&E, SDG&E, and Southern California Edison, reshaping rate design, electricity affordability, energy equity, and privacy amid proposed per-kWh reductions.
Key Points
PUC-approved fixed fees tied to household income for PG&E, SDG&E, and SCE, offset by lower per-kWh rates.
✅ Critics warn admin, privacy, legal risks and higher bills for savers
✅ Backers say lower-income pay less; kWh rates cut ~33% in PG&E area
Efforts are being made across California's political landscape to derail a legislative initiative that introduced income-based utility charges for customers of Southern California Edison and other major utilities.
Legislators from both the Democratic and Republican parties have proposed bills aimed at nullifying the 2022 legislation that established a sliding scale for utility charges based on customer income, a decision made in a late-hour session and subsequently endorsed by Governor Gavin Newsom.
The plan, pending final approval from the state Public Utilities Commission (PUC) — all of whose current members were appointed by Governor Newsom — would enable utilities like Southern California Edison, San Diego Gas & Electric, and PG&E to apply new income-based charges as early as this July.
Among the state legislators pushing back against the income-based charge scheme are Democrats Jacqui Irwin and Marc Berman, along with Republicans Janet Nguyen, Kelly Seyarto, Rosilicie Ochoa Bogh, Scott Wilk, Brian Dahle, Shannon Grove, and Roger Niello.
A cadre of specialists, including economist Ahmad Faruqui who has advised all three utilities implicated in the fee proposal, have outlined several concerns regarding the PUC's pending decision.
Faruqui and his colleagues argue that the proposed charges are excessively high in comparison to national standards, reflecting soaring electricity prices across the state, potentially leading to administrative challenges, legal disputes, and negative unintended outcomes, such as penalizing energy-conservative consumers.
Advocates for the income-based fee model, including The Utility Reform Network (TURN) and the National Resources Defense Council, argue it would result in higher charges for wealthier consumers and reduced fees for those with lower incomes. They also believe that the utilities plan to decrease per kilowatt-hour rates as part of a broader rate structure review to balance out the new fees.
However, even supporters like TURN and the Natural Resources Defense Council acknowledge that the income-based fee model is not a comprehensive solution to making soaring electricity bills more affordable.
If implemented, California would have the highest income-based utility fees in the country, with averages far surpassing the national average of $11.15, as reported by EQ Research:
Southern California Edison would charge $51.
San Diego Gas & Electric would levy $73.31.
PG&E would set fees at $50.92.
The proposal has raised concerns among state legislators about the additional financial burden on Californians already struggling with high electricity costs.
Critics highlight several practical challenges, including the PUC's task of assessing customers' income levels, a process fraught with privacy concerns, potential errors, and constitutional questions regarding access to tax information.
Economists have pointed out further complications, such as the difficulty in accurately assessing incomes for out-of-state property owners and the variability of customers' incomes over time.
The proposed income-based charges would differ by income bracket within the PG&E service area, for example, with lower-income households facing lower fixed charges and higher-income households facing higher charges, alongside a proposed 33% reduction in electricity rates to help mitigate the fixed charge impact.
Yet, the economists warn that most customers, particularly low-usage customers, could end up paying more, essentially rewarding higher consumption and penalizing efficiency.
This legislative approach, they caution, could inadvertently increase costs for moderate users across all income brackets, a sign of major changes to electric bills that could emerge, challenging the very goals it aims to achieve by promoting energy inefficiency.
ITER Nuclear Fusion advances tokamak magnetic confinement, heating deuterium-tritium plasma with superconducting magnets, targeting net energy gain, tritium breeding, and steam-turbine power, while complementing laser inertial confinement milestones for grid-scale electricity and 2025 startup goals.
Key Points
ITER Nuclear Fusion is a tokamak project confining D-T plasma with magnets to achieve net energy gain and clean power.
✅ Tokamak magnetic confinement with high-temp superconducting coils
✅ Deuterium-tritium fuel cycle with on-site tritium breeding
✅ Targets net energy gain and grid-scale, low-carbon electricity
It sounds like the stuff of dreams: a virtually limitless source of energy that doesn’t produce greenhouse gases or radioactive waste. That’s the promise of nuclear fusion, often described as the holy grail of clean energy by proponents, which for decades has been nothing more than a fantasy due to insurmountable technical challenges. But things are heating up in what has turned into a race to create what amounts to an artificial sun here on Earth, one that can provide power for our kettles, cars and light bulbs.
Today’s nuclear power plants create electricity through nuclear fission, in which atoms are split, with next-gen nuclear power exploring smaller, cheaper, safer designs that remain distinct from fusion. Nuclear fusion however, involves combining atomic nuclei to release energy. It’s the same reaction that’s taking place at the Sun’s core. But overcoming the natural repulsion between atomic nuclei and maintaining the right conditions for fusion to occur isn’t straightforward. And doing so in a way that produces more energy than the reaction consumes has been beyond the grasp of the finest minds in physics for decades.
But perhaps not for much longer. Some major technical challenges have been overcome in the past few years and governments around the world have been pouring money into fusion power research as part of a broader green industrial revolution under way in several regions. There are also over 20 private ventures in the UK, US, Europe, China and Australia vying to be the first to make fusion energy production a reality.
“People are saying, ‘If it really is the ultimate solution, let’s find out whether it works or not,’” says Dr Tim Luce, head of science and operation at the International Thermonuclear Experimental Reactor (ITER), being built in southeast France. ITER is the biggest throw of the fusion dice yet.
Its $22bn (£15.9bn) build cost is being met by the governments of two-thirds of the world’s population, including the EU, the US, China and Russia, at a time when Europe is losing nuclear power and needs energy, and when it’s fired up in 2025 it’ll be the world’s largest fusion reactor. If it works, ITER will transform fusion power from being the stuff of dreams into a viable energy source.
Constructing a nuclear fusion reactor ITER will be a tokamak reactor – thought to be the best hope for fusion power. Inside a tokamak, a gas, often a hydrogen isotope called deuterium, is subjected to intense heat and pressure, forcing electrons out of the atoms. This creates a plasma – a superheated, ionised gas – that has to be contained by intense magnetic fields.
The containment is vital, as no material on Earth could withstand the intense heat (100,000,000°C and above) that the plasma has to reach so that fusion can begin. It’s close to 10 times the heat at the Sun’s core, and temperatures like that are needed in a tokamak because the gravitational pressure within the Sun can’t be recreated.
When atomic nuclei do start to fuse, vast amounts of energy are released. While the experimental reactors currently in operation release that energy as heat, in a fusion reactor power plant, the heat would be used to produce steam that would drive turbines to generate electricity, even as some envision nuclear beyond electricity for industrial heat and fuels.
Tokamaks aren’t the only fusion reactors being tried. Another type of reactor uses lasers to heat and compress a hydrogen fuel to initiate fusion. In August 2021, one such device at the National Ignition Facility, at the Lawrence Livermore National Laboratory in California, generated 1.35 megajoules of energy. This record-breaking figure brings fusion power a step closer to net energy gain, but most hopes are still pinned on tokamak reactors rather than lasers.
In June 2021, China’s Experimental Advanced Superconducting Tokamak (EAST) reactor maintained a plasma for 101 seconds at 120,000,000°C. Before that, the record was 20 seconds. Ultimately, a fusion reactor would need to sustain the plasma indefinitely – or at least for eight-hour ‘pulses’ during periods of peak electricity demand.
A real game-changer for tokamaks has been the magnets used to produce the magnetic field. “We know how to make magnets that generate a very high magnetic field from copper or other kinds of metal, but you would pay a fortune for the electricity. It wouldn’t be a net energy gain from the plant,” says Luce.
One route for nuclear fusion is to use atoms of deuterium and tritium, both isotopes of hydrogen. They fuse under incredible heat and pressure, and the resulting products release energy as heat
The solution is to use high-temperature, superconducting magnets made from superconducting wire, or ‘tape’, that has no electrical resistance. These magnets can create intense magnetic fields and don’t lose energy as heat.
“High temperature superconductivity has been known about for 35 years. But the manufacturing capability to make tape in the lengths that would be required to make a reasonable fusion coil has just recently been developed,” says Luce. One of ITER’s magnets, the central solenoid, will produce a field of 13 tesla – 280,000 times Earth’s magnetic field.
The inner walls of ITER’s vacuum vessel, where the fusion will occur, will be lined with beryllium, a metal that won’t contaminate the plasma much if they touch. At the bottom is the divertor that will keep the temperature inside the reactor under control.
“The heat load on the divertor can be as large as in a rocket nozzle,” says Luce. “Rocket nozzles work because you can get into orbit within minutes and in space it’s really cold.” In a fusion reactor, a divertor would need to withstand this heat indefinitely and at ITER they’ll be testing one made out of tungsten.
Meanwhile, in the US, the National Spherical Torus Experiment – Upgrade (NSTX-U) fusion reactor will be fired up in the autumn of 2022, while efforts in advanced fission such as a mini-reactor design are also progressing. One of its priorities will be to see whether lining the reactor with lithium helps to keep the plasma stable.
Choosing a fuel Instead of just using deuterium as the fusion fuel, ITER will use deuterium mixed with tritium, another hydrogen isotope. The deuterium-tritium blend offers the best chance of getting significantly more power out than is put in. Proponents of fusion power say one reason the technology is safe is that the fuel needs to be constantly fed into the reactor to keep fusion happening, making a runaway reaction impossible.
Deuterium can be extracted from seawater, so there’s a virtually limitless supply of it. But only 20kg of tritium are thought to exist worldwide, so fusion power plants will have to produce it (ITER will develop technology to ‘breed’ tritium). While some radioactive waste will be produced in a fusion plant, it’ll have a lifetime of around 100 years, rather than the thousands of years from fission.
At the time of writing in September, researchers at the Joint European Torus (JET) fusion reactor in Oxfordshire were due to start their deuterium-tritium fusion reactions. “JET will help ITER prepare a choice of machine parameters to optimise the fusion power,” says Dr Joelle Mailloux, one of the scientific programme leaders at JET. These parameters will include finding the best combination of deuterium and tritium, and establishing how the current is increased in the magnets before fusion starts.
The groundwork laid down at JET should accelerate ITER’s efforts to accomplish net energy gain. ITER will produce ‘first plasma’ in December 2025 and be cranked up to full power over the following decade. Its plasma temperature will reach 150,000,000°C and its target is to produce 500 megawatts of fusion power for every 50 megawatts of input heating power.
“If ITER is successful, it’ll eliminate most, if not all, doubts about the science and liberate money for technology development,” says Luce. That technology development will be demonstration fusion power plants that actually produce electricity, where advanced reactors can build on decades of expertise. “ITER is opening the door and saying, yeah, this works – the science is there.”
Taltson Hydro Electric Heating directs surplus hydro power in the South Slave to space heat via discounted rates, displacing diesel and cutting greenhouse gas emissions, with rebates, separate metering, and backup systems shaping adoption.
Key Points
An initiative using Taltson's surplus hydro to heat buildings, discount rates replace diesel and cut emissions.
✅ 6.3 cents/kWh heating rate needs separate metering, backup heat
✅ 4-6 MW surplus hydro; outages require diesel; rebates available
✅ Program may be curtailed if new mines or mills demand power
A Northwest Territories green energy advocate says there's an obvious way to expand demand for electricity in the territory's South Slave region without relying on new mining developments — direct it toward heating.
One of the reasons the N.W.T. has always had some of the highest electricity rates in Canada is that a small number of people have to shoulder the huge costs of hydro facilities and power plants.
But some observers point out that residents consume as much energy for heat as they do for conventional uses of electricity, such as lighting and powering appliances. Right now almost all of that heat is generated by expensive oil imported from the United States.
The Northwest Territories Power Corporation says the 18-megawatt Taltson hydro system that serves the South Slave typically has four to six megawatts of excess generating capacity, even as record demand in Yukon is reported. It says using some of that to generate heat is a government priority.
But renewable energy advocate and former N.W.T. MP Dennis Bevington, who lives in the South Slave and heats his home using electricity, says the government is not making it easy for people to tap into that surplus to heat their homes and businesses, a debate that some say would benefit from independent planning at the national level.
Discount rate for heating, but there are catches The power corporation offers hydro electricity from Taltson to use for heating at a much lower price than it charges for electricity generally. The discounted rate is not available to residential customers.
According to the corporation, consumers pay only 6.3 cents per kilowatt hour compared to the regular rate of just under 24 cents, while Manitoba Hydro financial pressures highlight the risks of expanding demand without new generation.
But to distinguish between the two, users are required to cover the cost of installing a separate power meter. Bevington, who developed the N.W.T.'s first energy strategy, says that is an unnecessary expense.
Taltson expansion key to reducing N.W.T.'s greenhouse gas emissions, says gov't "The billing is how you control that," he said. "You establish an average electrical use in the winter months. That could be the base rate. Then, if you use power in the winter months above that, you get the discount."
Users are also required to have a back-up heating system. Taltson hydro power offers heating on the understanding that when the hydro system is down — such as during power outages or annual summer maintenance of the hydro system — electricity is not available for heating. The president and CEO of the power corporation says there's a good reason for that. "The diesels are more expensive to run and they're actually greenhouse gas emitting," said Noel Voykin. "The whole idea of this [electric heat] program is to provide clean energy that is not otherwise being used."
According to the corporation, there have been huge savings for the few who have tapped into the hydro system to heat their buildings, and across Canada utilities are exploring novel generation such as NB Power's Belledune seawater project to diversify supply.
It's being used to heat Aurora College's Breynat Hall, and Joseph B. Tyrrell Elementary School and the transportation department garage in Fort Smith, N.W.T. Electricity is also used to heat the Jackfish power plant in the North Slave region.
The corporation says that during a four-year period, this saved more than 600,000 litres of diesel fuel and reduced greenhouse gas emissions by about 1,700 tonnes.
Bevington says the most obvious place to expand the use of electrical heat is to government housing.
"We have a hundred public housing units in Fort Smith," he said. "The government is putting diesel into those units [for heating] and they could be putting in their own electricity."
Heating a tiny part of energy market The corporation says it sells only about 2.5 megawatts of electricity for heating each year, which is less than four per cent of the power it sells in the region. It says with some upgrades, another two megawatts of electricity could be made available for electrical heat.
Bevington says the corporation could do more to market electricity for heating. Voykin said that's the government's job. There are three programs that offer rebates to residents and businesses converting to electric heating.
If you build it, will they come? N.W.T. gov't hopes hydro expansion will attract investment There are better options than billion dollar Taltson expansion, say energy leaders There may be a reason why the government and the corporation are not more aggressively promoting using surplus electricity in the Taltson system for heating, as large hydro ambitions have reopened old wounds in places like Quebec and Newfoundland and Labrador during recent debates.
It is anticipating that new industrial customers may require that excess capacity in the coming years, and experiences elsewhere show that accommodating new energy-intensive customers can be challenging for utilities. Voykin said those potential new customers include a proposed mine at Pine Point and a pellet mill in Enterprise, N.W.T., even as biomass use faces environmental pushback in some regions.
The corporation says any surplus power in the system will be sold at standard rates to any new industrial customers instead of at discount rates for heating. If that requires cutting back on the heating program, it will be cut back.
National Grid power supply warning highlights electricity shortage risks amid low wind output, generator outages, and cold weather, reducing capacity margins and grid stability; considering demand response and reserve power to avoid blackout risk.
Key Points
An alert that reduced capacity from low wind and outages requires actions to maintain UK grid stability.
✅ Low wind output and generator outages reduce capacity margins
✅ ESO exploring demand response and reserve generation options
✅ Aim: maintain grid stability and avoid blackout risk
National Grid has warned that Britain’s electricity will be in short supply over the next few days after a string of unplanned power plant outages and unusually low wind speeds this week, as cheap wind power wanes across the system.
The electricity system operator said it will take action to “make sure there is enough generation” during the cold weather spell, including virtual power plants and other demand-side measures, to prevent a second major blackout in as many years.
“Unusually low wind output coinciding with a number of generator outages means the cushion of spare capacity we operate the system with has been reduced,” the company told its Twitter followers.
“We’re exploring measures and actions to make sure there is enough generation available to increase our buffer of capacity.”
A spokeswoman for National Grid said the latest electricity supply squeeze was not expected to be as severe as recorded last month, following reports that the government’s emergency energy plan was not going ahead, and added that the company did not expect to issue an official warning in the next 24 hours.
“We’re monitoring how the situation develops,” she said.
The warning is the second from the electricity system operator in recent weeks. In mid-September the company issued an official warning to the electricity market as peak power prices climbed, that its ‘buffer’ of power reserves had fallen below 500MW and it may need to call on more power plants to help prevent a blackout. The notice was later withdrawn.
Concerns over National Grid’s electricity supplies have been relatively rare in recent years. It was forced in November 2015 to ask businesses to cut their demand as a “last resort” measure to keep the lights on after a string of coal plant breakdowns.
But since then, National Grid’s greater challenge has been an oversupply of electricity, partly due to record wind generation, which has threatened to overwhelm the grid during times of low electricity demand.
National Grid has already spent almost £1bn on extra measures to prevent blackouts over the first half of the year by paying generators to produce less electricity during the coronavirus lockdown, as daily demand fell.
The company paid wind farms to turn off, and EDF Energy to halve the nuclear generation from its Sizewell B nuclear plant, to avoid overwhelming the grid when demand for electricity fell by almost a quarter from last year.
The electricity supply squeeze comes a little over a year after National Grid left large parts of England and Wales without electricity after the biggest blackout in a decade left a million homes in the dark. National Grid blamed a lightning strike for the widespread power failure.
Similar supply strains have recently caused power cuts in China, underscoring how weather and generation mix can trigger blackouts.
Martha's Vineyard 100% Renewable Energy advances electrification across EVs, heat pumps, distributed solar, offshore wind, microgrids, and battery storage, cutting emissions, boosting efficiency, and strengthening grid resilience for storms and sea-level rise.
Key Points
It is an islandwide plan to electrify transport and buildings using wind, solar, storage, and a modern resilient grid.
✅ Electrify transport: EV adoption and SSA hybrid-electric ferries.
✅ Deploy heat pumps for efficient heating and cooling in buildings.
✅ Modernize the grid: distributed solar, batteries, microgrids, VPP.
Over the past year, it has become increasingly clear that climate change is accelerating. Here in coastal New England, annual temperatures and precipitation have risen more quickly than expected, tidal flooding is now commonplace, and storms have increased in frequency and intensity. The window for avoiding the worst consequences of a climate-changed planet is closing.
At their recent special town meeting, Oak Bluffs citizens voted to approve the 100 per cent renewable Martha’s Vineyard warrant article; now, all six towns have adopted the same goals for fossil fuel reduction and green electricity over the next two decades. Establishing these targets for the adoption of renewable energy, though, is only an initial step. Town and regional master plans for energy transformation are being developed, but this is a whole-community effort as well. Now is the time for action.
There is much to do to combat climate change, but our most important task is to transition our energy system from one heavily dependent on fossil fuels to one that is based on clean electricity. The good news is that this can be accomplished with currently available technology, and can be done in an economically efficient manner.
Electrification not only significantly lowers greenhouse gas emissions, but also is a powerful energy efficiency measure. So even though our detailed Island energy model indicates that eliminating all (or almost all) fossil fuel use will mean our electricity use will more than double, posing challenges for state power grids in some regions, our overall annual energy consumption will be significantly lower.
So what do we specifically need to do?
The primary targets for electrification are transportation (roughly 60 peer cent of current fossil fuel use on Martha’s Vineyard) and building heating and cooling (40 per cent).
Over the past two years, the increase in the number of electric vehicle models available across a wide range of price points has been remarkable — sedans, SUVs, crossovers, pickup trucks, even transit vans. When rebates and tax credits are considered, they are affordable. Range anxiety is being addressed both by increases in vehicle performance and the growing availability of charging locations (other than at home, which will be the predominant place for Islanders to refuel) and, over time, enable vehicle-to-grid support for our local system. An EV purchase should be something everyone should seriously consider when replacing a current fossil vehicle.
The elephant in the transportation sector room is the Steamship Authority. The SSA today uses roughly 10 per cent of the fossil fuel attributable to Martha’s Vineyard, largely but not totally in the ferries. The technology needed for fully electric short-haul vessels has been under development in Scandinavia for a number of years and fully electric ferries are in operation there. A conservative approach for the SSA would be to design new boats to be hybrid diesel-electric, retrofittable to plug-in hybrids to allow for shoreside charging infrastructure to be planned and deployed. Plug-in hybrid propulsion could result in a significant reduction in emissions — perhaps as much as 95 per cent, per the long-range plan for the Washington State ferries. While the SSA has contracted for an alternative fuel study for its next boat, given the long life of the vessels, an electrification master plan is needed soon.
For building heating and cooling, the answer for electrification is heat pumps, both for new construction and retrofits. These devices move heat from outside to inside (in the winter) or inside to outside (summer), and are increasingly integrated into connected home energy systems for smarter control. They are also remarkably efficient (at least three times more efficient than burning oil or propane), and today’s technology allows their operation even in sub-zero outside temperatures. Energy costs for electric heating via heat pumps on the Vineyard are significantly below either oil or propane, and up-front costs are comparable for new construction. For new construction and when replacing an existing system, heat pumps are the smart choice, and air conditioning for the increasingly hot summers comes with the package.
A frequent objection to electrification is that fossil-fueled generation emits greenhouse gases — thus a so-called green grid is required in order to meet our targets. The renewable energy fraction of our grid-supplied electricity is today about 30 per cent; by 2030, under current legislation that fraction will reach 54 per cent, and by 2040, 77 per cent. Proposed legislation will bring us even closer to our 2040 goals. The Vineyard Wind project will strongly contribute to the greening of our electricity supply, and our local solar generation (almost 10 per cent of our overall electricity use at this point) is non-negligible.
A final important facet of our energy system transformation is resilience. We are dependent today on our electricity supply, and this dependence will grow. As we navigate the challenges of climate change, with increasingly more frequent and more serious storms, 2021 electricity lessons underscore that resilience of electricity supply is of paramount importance. In many ways, today’s electricity distribution system is basically the same approach developed by Edison in the late 19th century. In partnership with our electric utility, we need to modernize the grid to achieve our resiliency goals.
While the full scope of this modernization effort is still being developed, the outline is clear. First, we need to increase the amount of energy generated on-Island — to perhaps 25 per cent of our total electricity use. This will be via distributed energy resources (in the form of distributed solar and battery installations as well as community solar projects) and the application of advanced grid control systems. For emergency critical needs, the concept of local microgrids that are detachable from the main grid when that grid suffers an outage are an approach that is technically sound and being deployed elsewhere. Grid coordination of distributed resources by the utility allows for handling of peak power demand; in the early 2030s this could result in what is known as a virtual power plant on the Island.
The adoption of the 100 renewable Martha’s Vineyard warrant articles is an important milestone for our community. While the global and national efforts in the climate crisis may sometimes seem fraught, we can take some considerable pride in what we have accomplished so far and will accomplish in coming years. As with many change efforts, the old catch-phrase applies: think globally, act locally.
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.
