Echelon, T-Mobile work together to reduce cost of smart grid

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.
 

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PG&E Wildfire Lawsuit alleges utility negligence, inadequate infrastructure maintenance, and faulty transmission lines, as victims seek compensation. Regulators investigate the blaze, echoing class actions after Victoria's Black Saturday mega-fires and utility oversight failures.

Key Points

PG&E Wildfire Lawsuit alleges utility negligence and power line faults, seeking victim compensation amid investigations.

✅ Alleged failure to maintain transmission infrastructure

✅ Spark reports and regulator filings before blaze erupted

✅ Class action parallels with Australia's Black Saturday

Victims of California's most destructive wildfire have filed a lawsuit accusing Pacific Gas & Electric Co. of causing the massive blaze, a move that follows the utility's 2018 Camp Fire guilty plea in a separate case.

The suit filed on Tuesday in state court in California accuses the utility of failing to maintain its infrastructure and properly inspect and manage its power transmission lines, amid prior reports that power lines may have sparked fires in California.

The utility's president said earlier the company doesn't know what caused the fire, but is cooperating with the investigation by state agencies, and other utilities such as Southern California Edison have faced wildfire lawsuits in California.

PG&E told state regulators last week that it experienced a problem with a transmission line in the area of the fire just before the blaze erupted.

A landowner near where the blaze began said PG&E notified her the day before the wildfire that crews needed to come onto her property because some wires were sparking, and the company later promoted its wildfire assistance program for victims seeking aid.

A massive class action after Australia's last mega-fire, Victoria's Black Saturday in 2009, saw $688.5 million paid in compensation to thousands of claimants affected by the Kilmore-Kinglake and Murrindindi-Marysville fires, partly by electricity company SP Ausnet, and partly by government agencies, while in California PG&E's bankruptcy plan won support from wildfire victims addressing compensation claims.

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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.

Key Points

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.”

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Duke Energy zero-coal 2050 plan outlines a decarbonized energy mix, aligning with Paris goals, cutting greenhouse gas emissions, driven by investor pressure, shifting to natural gas, extending nuclear power, and phasing out coal.

Key Points

An investor-driven scenario to end coal by 2050, shift to natural gas, extend nuclear plants, and manage climate risk.

✅ Eliminates coal from the generation mix by 2050

✅ Prioritizes natural gas transitions without CCS breakthroughs

✅ Extends nuclear plant licenses to limit carbon emissions

One of America’s largest utility companies, Duke Energy, is set to release a report later this month that sketches a drastically changed electricity mix in a carbon-constrained future.

The big picture: Duke is the latest energy company to commit to releasing a report about climate change in response to investor pressure, echoing shifts such as Europe's oil majors going electric across the sector, conveyed by non-binding but symbolically important shareholder resolutions. Duke provides electricity to more than seven million customers in the Carolinas, the Midwest and Florida.

Gritty details: The report is expected to find that coal, currently 33% of Duke’s mix, gone entirely from its portfolio by 2050 in a future scenario where the world has taken steps to cut greenhouse gas emissions, and where global coal-fired electricity use is falling markedly, to a level consistent with keeping global temperatures from rising two degrees Celsius. That’s the big ambition of the 2015 Paris climate deal, but the current commitments aren’t close to reaching that.

What they're saying: “What’s difficult about this is we are trying to overlay what we understand currently about technology,” Lynn Good, Duke CEO, told Axios in an interview on the sidelines of a major energy conference here.

She went on to say that this scenario of zero coal by 2050 doesn’t assume any breakthroughs in technology that captures carbon emissions from coal-fired power plants. “We don’t see that technology today, and we need to make economic decisions to get those units moving and replacing them with natural gas.”

Good also stressed the benefits of its several nuclear power plants, highlighting the role of sustaining U.S. nuclear power in decarbonization, which emit no carbon emissions. She said Duke isn’t considering investing in new nuclear plants, but plans to seek federal relicensing of current plants.

“If I turn them off, the resource that would replace them today is natural gas, so carbon will go up,” Good said. “Our objective is to continue to keep those plants as long as possible.”

What’s next: A spokesman said the other details of their 2050 scenario estimates will be available when the report is officially released by month’s end.

Axios reports that Duke Energy will release a report later this month that detail the utility's efforts to mitigate climate change risks and plan carbon-free electricity investments across its operations. The report includes a scenario that eliminates coal entirely from the company's power mix by 2050. Coal currently makes up about a third of Duke's generation.

Duke CEO Lynn Good told the news outlet the scenario ending coal-fired generation assumes no technological advances in emissions capture, seemingly leaving open the possibility.

Last year, a report by the Union of Concerned Scientists concluded one in four of the remaining operating coal-fired plants in the U.S. are slated for closure or conversion to natural gas, amid falling power-sector carbon emissions across the country. Duke's report is expected to be released by the end of the month.

Duke's report on its carbon plans comes at the behest of shareholders, a trend utility companies have seen growing among investors who are increasingly concerned about companies' sustainability and their financial exposure to climate policy.

Last year, a majority of shareholders of Pennsylvania utility PPL Corp. called on company management to publish a report on how climate change policies and technological innovations will affect the company's bottom line. Almost 60% of shareholders voted in favor of the non-binding proposal.

The vote, reportedly a first for the power sector, followed a similar decision by shareholders of Occidental Petroleum, which was supported by about 66% of shareholders.

Duke's Good told Axios that right now the utility does not see the coal technology on the horizon that would keep it operating plants. “We don't see that technology today, and we need to make economic decisions to get those units moving and replacing them with natural gas," Good said. However, it does not mean the utility is making near-term efforts to erase coal from its power mix. However, some utilities are taking those steps as they prepare for en energy landscape with more carbon regulations.

In addition to the 25% of coal plants heading for closure or conversion, the UCS report also said that another 17% of the nation’s operating coal plants are uneconomic compared with natural gas-fired generation, and could face retirement soon. But there is plenty of ongoing research into "clean coal" possibilities, and the federal government has expressed an interest in smaller, modular coal units.

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BC Affordability & BC Hydro Bill Credits provide inflation relief and cost of living support, lowering electricity bills for families and small businesses through automatic utility credits and income-tested tax rebates across British Columbia.

Key Points

BC relief lowering electricity bills and offering rebates to help families and businesses facing inflation.

✅ $100 credit for residential BC Hydro users; applied automatically.

✅ Avg $500 bill credit for small and medium commercial customers.

✅ Income-based BC Affordability Credit via CRA in January.

The new B.C. premier announced on Friday morning families and small businesses in B.C. will get a one-time cost of living credit on their BC Hydro bill this fall, and a new B.C. Affordability Credit in January.

Eby focused on the issue of affordability in his speech following being sworn in as B.C.’s 37th premier, including electricity costs addressed by BC Hydro review recommendations that aim to keep power affordable.

A BC Hydro bill credit of $100 will be provided to all eligible residential and commercial electricity customers, including those who receive their electricity service indirectly from BC Hydro through FortisBC or a municipal utility.

“People and small businesses across B.C. are feeling the squeeze of global inflation,” Eby said.

“It’s a time when people need their government to continue to be there for them. That’s why we’re focused on helping people most impacted by the rising costs we’re seeing around the world – giving people a bit of extra credit, especially at a time of year when expenses can be quick to add up.”

Eby takes over as premier of the province with a growing number of concerns piling up on his plate, even as the province advances grid development and job creation projects to support long-term growth.

Economists in the province have warned of turbulent economic times ahead due to global economic pressures and power supply challenges tied to green energy ambitions.

The one-time $100 cost of living credit works out to approximately one month of electricity for a family living in a detached home or more than two months of electricity for a family living in an apartment.

Commercial ratepayers, including small and medium businesses like restaurants and tourism operators, will receive a one-time bill credit averaging $500 as B.C. expands EV charging infrastructure to accelerate electrification.

The amount will be based on their prior year’s electricity consumption.

British Columbians will have the credit automatically applied to their electricity accounts.

BC Hydro customers will have the credit applied in early December. Customers of FortisBC and municipal utilities will likely begin to see their bill credits applied early in the new year.

‘I proudly and unreservedly turn to the tallest guy in the room’: John Horgan on David Eby

The B.C. Affordability Credit is separate and will be based on income.

Eligible people and families will automatically receive the new credit through the Canada Revenue Agency, the same way the enhanced Climate Action Tax Credit was received in October.

An eligible person making an income of up to $36,901 will receive the maximum BC Affordability Credit with the credit fully phasing out at $79,376.

An eligible family of four with a household income of $43,051 will get the maximum amount, with the credit fully phasing out by $150,051.

This additional support means a family of four can receive up to an additional $410 in early January 2023 to help offset some of the added costs people are facing, while EV owners can access more rebates for home and workplace charging to reduce transportation expenses.

“Look for B.C.’s new Affordability Credit in your bank account in January 2023,” Eby said.

“We know it won’t cover all the bills, but we hope the little bit extra helps folks out this winter.”

Eby’s swearing-in marks a change at the premier’s office but not a shift in focus.

The premier expects to continue on with former premier John Horgan’s mandate with a focus on affordability issues and clean growth supported by green energy investments from both levels of government.

In a ceremony held in the Musqueam Community Centre, Eby made a commitment to make meaningful improvements in the lives of British Columbians and continue work with First Nations communities, with clean-tech growth underscored by the B.C. battery plant announcement made with the prime minister.

The ceremony was the first-ever swearing-in hosted by a First Nation in British Columbia.

“British Columbia is a wonderful place to call home,” Eby said.

“At the same time, people are feeling uncertain about the future and worried about their families. I’m proud of the work done by John Horgan and our government to put people first. And there’s so much more to do. I’m ready to get to work with my team to deliver results that people will be able to see and feel in their lives and in their communities.”

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Belarus Nuclear Power Infrastructure Review evaluates IAEA INIR Phase 3 readiness at Ostrovets NPP, VVER-1200 reactors, legal and regulatory framework, commissioning, safety, emergency preparedness, and energy diversification in a low-carbon program.

Key Points

An IAEA INIR Phase 3 assessment of Belarus readiness to commission and operate the Ostrovets NPP with VVER-1200 units.

✅ Reviews legal, regulatory, and institutional arrangements

✅ Confirms Phase 3 readiness for safe commissioning and operation

✅ Highlights good practices in peer reviews and emergency planning

An International Atomic Energy Agency (IAEA) team of experts today concluded a 12-day mission to Belarus to review its infrastructure development for a nuclear power programme. The Integrated Nuclear Infrastructure Review (INIR) was carried out at the invitation of the Government of Belarus.

Belarus, seeking to diversify its energy production with a reliable low-carbon source, and aware of the benefits of energy storage for grid flexibility, is building its first nuclear power plant (NPP) at the Ostrovets site, about 130 km north-west of the capital Minsk. The country has engaged with the Russian Federation to construct and commission two VVER-1200 pressurised water reactors at this site and expects the first unit to be connected to the grid this year.

The INIR mission reviewed the status of nuclear infrastructure development using the Phase 3 conditions of the IAEA’s Milestones Approach. The Ministry of Energy of Belarus hosted the mission.

The INIR team said Belarus is close to completing the required nuclear power infrastructure for starting the operation of its first NPP. The team made recommendations and suggestions aimed at assisting Belarus in making further progress in its readiness to commission and operate it, including planning for integration with variable renewables, as advances in new wind turbines are being deployed elsewhere to strengthen the overall energy mix.

“This mission marks an important step for Belarus in its preparations for the introduction of nuclear power,” said team leader Milko Kovachev, Head of the IAEA’s Nuclear Infrastructure Development Section. “We met well-prepared, motivated and competent professionals ready to openly discuss all infrastructure issues. The team saw a clear drive to meet the objectives of the programme and deliver benefits to the Belarusian people, such as supporting the country’s economic development, including growth in EV battery manufacturing sectors.”

The team comprised one expert from Algeria and two experts from the United Kingdom, as well as seven IAEA staff. It reviewed the status of 19 nuclear infrastructure issues using the IAEA evaluation methodology for Phase 3 of the Milestones Approach, noting that regional integration via an electricity highway can shape planning assumptions as well. It was the second INIR mission to Belarus, who hosted a mission covering Phases 1 and 2 in 2012.

Prior to the latest mission, Belarus prepared a Self-Evaluation Report covering all infrastructure issues and submitted the report and supporting documents to the IAEA.

The team highlighted areas where further actions would benefit Belarus, including the need to improve institutional arrangements and the legal and regulatory framework, drawing on international examples of streamlined licensing for advanced reactors to ensure a stable and predictable environment for the programme; and to finalize the remaining arrangements needed for sustainable operation of the nuclear power plant.

The team also identified good practices that would benefit other countries developing nuclear power in the areas of programme and project coordination, the use of independent peer reviews, cooperation with regulators from other countries, engagement with international stakeholders and emergency preparedness, and awareness of regional initiatives such as new electricity interconnectors that can enhance system resilience.

Mikhail Chudakov, IAEA Deputy Director General and Head of the Department of Nuclear Energy attended the Mission’s closing meeting. “Developing the infrastructure required for a nuclear power programme requires significant financial and human resources, and long lead times for preparation and the approval of major transmission projects that support clean power flows, and the construction activities,” he said. “Belarus has made commendable progress since the decision to launch a nuclear power programme 10 years ago.”

“Hosting the INIR mission, Belarus demonstrated its transparency and genuine interest to receive an objective professional assessment of the readiness of its nuclear power infrastructure for the commissioning of the country’s first nuclear power plant,” said Mikhail Mikhadyuk, Deputy Minister of Energy of the Republic of Belarus. ”The recommendations and suggestions we received will be an important guidance for our continuous efforts aimed at ensuring the highest level of safety and reliability of the Belarusian NPP."
 

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