State brainstorms renewable energy proposals

By McClatchy Tribune News


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A state task force on renewable energy is recommending an eightfold increase in solar-energy development, offering incentives to attract green-energy businesses to the state and suggesting changes in the law to encourage companies to produce renewable energy on-site.

All of the recommendations are aimed at increasing renewable energy sources to make up 25 percent of the state's energy demand by 2013. At a recent meeting to announce the initiatives, Lt. Gov. David Paterson said the recommendations would put New York "on a path to become part of the global solution" to global warming and emissions-belching traditional power sources.

Increasing sources of solar energy eightfold would push energy levels derived from photovoltaic cells in the state to more than 100 megawatts, the renewable energy task force said in a statement. The recommendations also include development and support of a "green-collar" workforce to nurture and maintain renewable energy sources.

That element of the plan includes coordination and expansion of green-energy training programs, including in disadvantaged communities. The task force, whose members include Long Island Power Authority chief executive Kevin Law, said 43,000 new jobs could be created in the state if New York follows through on a proposal to require 25 percent of the state's energy to come from renewable resources by 2013.

Incentives to attract renewable energy companies would be aimed at building "clusters" of solar, wind, biomass and other green-energy industries around the state. Changes in the law to encourage on-site installation of renewable energy sources at companies would include extending the net-metering law to corporations, not just residences.

Net metering allows a home to sell energy back to the grid when it exceeds a home's requirements. "Our challenge is not a lack of renewable energy potential," Gov. Eliot Spitzer said in a statement, "it is finding ways to effectively develop it and create economic opportunities in our own backyard."

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IAEA Warns of Nuclear Risks from Russian Attacks on Ukraine Power Grids

Ukraine nuclear safety risks escalate as IAEA warns of power grid attacks threatening reactor cooling, diesel generators, and Zaporizhzhia oversight, prompting UN calls for demilitarized zones to prevent radioactive releases and accidents.

 

Key Points

Escalating threats from grid attacks and outages that jeopardize reactor cooling, IAEA oversight, and public safety.

✅ Power grid strikes threaten reactor cooling systems.

✅ Emergency diesel generators are last defense lines.

✅ Calls grow for demilitarized zones around plants.

 

In early February 2025, Rafael Grossi, Director General of the International Atomic Energy Agency (IAEA), expressed grave concerns regarding the safety of Ukraine's nuclear facilities amid ongoing Russian attacks on the country's power grids, as Kyiv warned of a difficult winter without power after deadly strikes on energy infrastructure. Grossi's warnings highlight the escalating risks to nuclear safety and the potential for catastrophic accidents.

The Threat to Nuclear Safety

Ukraine's nuclear infrastructure, including the Zaporizhzhia Nuclear Power Plant—the largest in Europe—relies heavily on a stable power supply to maintain critical cooling systems and other safety measures. Russian military operations targeting Ukraine's energy infrastructure have led to power outages, and created hazards akin to those highlighted in downed power line safety guidance during emergency repairs, jeopardizing the safe operation of these facilities. Grossi emphasized that such disruptions could result in severe nuclear accidents if cooling systems fail.

IAEA's Response and Actions

In response to these threats, the IAEA has been actively involved in monitoring and assessing the situation. Grossi visited Kyiv to inspect electrical substations and discuss safety measures with Ukrainian officials. He underscored the necessity of ensuring uninterrupted power to nuclear plants and the critical role of emergency diesel generators as a last line of defense, and noted that maintaining staffing continuity, including measures such as staff living on site at critical facilities, may be necessary. The IAEA has also postponed the rotation of its mission at the Zaporizhzhia plant due to security concerns, as reported by Reuters.

International Concerns and Diplomatic Efforts

The international community has expressed deep concern over the potential for nuclear accidents in Ukraine, echoing earlier grid overseer warnings about systemic risks in other crises that stress energy systems. The United Nations and various countries have called for the establishment of a demilitarized zone around nuclear facilities to prevent military activities that could compromise their safety. Diplomatic efforts are ongoing to facilitate dialogue between Russia and Ukraine, aiming to ensure the protection of nuclear sites and the safety of surrounding populations.

The Zaporizhzhia Nuclear Power Plant

The Zaporizhzhia Nuclear Power Plant, located in southeastern Ukraine, has been under Russian control since early in the conflict, with Rosatom cooperation agreements reflecting broader nuclear policy priorities that frame Moscow's approach to the sector. The plant consists of six reactors and has been a focal point of international concern due to its size and the potential consequences of any incident. The IAEA has been working to maintain oversight and ensure the plant's safety amid the ongoing conflict.

Potential Consequences of Nuclear Accidents

A nuclear accident at any of Ukraine's nuclear facilities could have catastrophic consequences, including the release of radioactive materials, displacement of populations, and long-term environmental damage, with communities potentially facing weeks without electricity and basic services in the aftermath. The proximity of these plants to densely populated areas further amplifies the risks. The international community continues to monitor the situation closely, emphasizing the need for immediate action to safeguard nuclear facilities.

The ongoing conflict in Ukraine has introduced unprecedented challenges to nuclear safety. The IAEA's warnings and actions underscore the critical need for international cooperation to protect nuclear facilities from the dangers posed by military activities. Ensuring the safety of these sites is paramount to prevent potential disasters that could have far-reaching humanitarian and environmental impacts, and sustained attention to nuclear workers' safety concerns helps maintain operational readiness under strain.

 

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Ireland: We are the global leaders in taking renewables onto the grid

Ireland 65% Renewable Grid Capability showcases world leading integration of intermittent wind and solar, smart grid flexibility, EU-SysFlex learnings, and the Celtic Interconnector to enhance stability, exports, and energy security across the European grid.

 

Key Points

Ireland can run its isolated power system with 65% variable wind and solar, informing EU grid integration and scaling.

✅ 65% system non-synchronous penetration on an isolated grid

✅ EU-SysFlex roadmap supports large-scale renewables integration

✅ Celtic Interconnector adds 700MW capacity and stability

 

Ireland is now able to cope with 65% of its electricity coming from intermittent electricity sources like wind and solar, as highlighted by Ireland's green electricity outlook today – an expertise Energy Minister Denish Naugthen believes can be replicated on a larger scale as Europe moves towards 50% renewable power by 2030.

Denis Naughten is an Irish politician who serves as Minister for Communications, Climate Action and Environment since May 2016.

Naughten spoke to editor Frédéric Simon on the sidelines of a EURACTIV event in the European  Parliament to mark the launch of EU-SysFlex, an EU-funded project, which aims to create a long-term roadmap for the large-scale integration of renewable energy on electricity grids.

What is the reason for your presence in Brussels today and the main message that you came to deliver?

The reason that I’m here today is that we’re going to share the knowledge what we have developed in Ireland, right across Europe. We are now the global leaders in taking variable renewable electricity like wind and solar onto our grid.

We can take a 65% loading on to the grid today – there is no other isolated grid in the world that can do that. We’re going to get up to 75% by 2020. This is a huge technical challenge for any electricity grid and it’s going to be a problem that is going to grow and grow across Europe, even as Europe's electricity demand rises in the coming years, as we move to 50% renewables onto our grid by 2030.

And our knowledge and understanding can be used to help solve the problems right across Europe. And the sharing of technology can mean that we can make our own grid in Ireland far more robust.

What is the contribution of Ireland when it comes to the debate which is currently taking place in Europe about raising the ambition on renewable energy and make the grid fit for that? What are the main milestones that you see looking ahead for Europe and Ireland?

It is a challenge for Europe to do this, but we’ve done it Ireland. We have been able to take a 65% loading of wind power on our grid, with Irish wind generation hitting records recently, so we can replicate that across Europe.

Yes it is about a much larger scale and yes, we need to work collaboratively together, reflecting common goals for electricity networks worldwide – not just in dealing with the technical solutions that we have in Ireland at the fore of this technology, but also replicating them on a larger scale across Europe.

And I believe we can do that, I believe we can use the learnings that we have developed in Ireland and amplify those to deal with far bigger challenges that we have on the European electricity grid.

Trialogue talks have started at European level about the reform of the electricity market. There is talk about decentralised energy generation coming from small-scale producers. Do you see support from all the member states in doing that? And how do you see the challenges ahead on a political level to get everyone on board on such a vision?

I don’t believe there is a political problem here in relation to this. I think there is unanimity across Europe that we need to support consumers in producing electricity for self-consumption and to be able to either store or put that back into the grid.

The issues here are more technical in nature. And how you support a grid to do that. And who actually pays for that. Ireland is very much a microcosm of the pan-European grid and how we can deal with those challenges.

What we’re doing at the moment in Ireland is looking at a pilot scheme to support consumers to generate their own electricity to meet their own needs and to be able to store that on site.

I think in the years to come a lot of that will be actually done with more battery storage in the form of electric vehicles and people would be able to transport that energy from one location to another as and when it’s needed. In the short term, we’re looking at some novel solutions to support consumers producing their own electricity and meeting their own needs.

So I think this is complex from a technical point of view at the moment, I don’t think there is an unwillingness from a political perspective to do it, and I think working with this particular initiative and other initiatives across Europe, we can crack those technical challenges.

To conclude, last year, the European Commission allocated €4 million to a project to link up the Irish electricity grid to France. How is that going to benefit Ireland? And is that related to worries that you may have over Brexit?

The plan, which is called the Celtic Interconnector, is to link France with the Irish electricity grid. It’s going to have a capacity of about 700MW. It allows us to provide additional stability on our grid and enables us to take more renewables onto the grid. It also allows us to export renewable electricity onto the main European grid as well, and provide stability to the French network.

So it’s a benefit to both individual networks as well as allowing far more renewables onto the grid. We’ve been working quite closely with RTE in France and with both regulators. We’re hoping to get the support of the European Commission to move it now from the design stage onto the construction stage. And I understand discussions are ongoing with the Commission at present with regard to that.

And that is going to diversify potential sources of electricity coming in for Ireland in a situation which is pretty uncertain because of Brexit, correct?

Well, I don’t think there is uncertainty because of Brexit in that we have agreements with the United Kingdom, we’re still going to be part of the broader energy family in relation to back-and-forth supply across the Irish Sea, with grid reinforcements in Scotland underscoring reliability needs.  But I think it is important in terms of meeting the 15% interconnectivity that the EU has set in relation to electricity.

And also in relation of providing us with an alternative support in relation to electricity supply outside of Britain. Because Britain is now leaving the European Union and I think this is important from a political point of view, and from a broader energy security point of view. But we don’t see it in the short term as causing threats in relation to security of supply.

 

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Egypt, Eni ink MoU on hydrogen production projects

Egypt-ENI Hydrogen MoU outlines joint feasibility studies for green and blue hydrogen using renewable energy, carbon capture, and CO2 storage, targeting domestic demand, exports, and net-zero goals within Egypt's energy transition.

 

Key Points

A pact to study green and blue hydrogen in Egypt, leveraging renewables, CO2 storage, and export/demand pathways.

✅ Feasibility study for green and blue hydrogen projects

✅ Uses renewables, SMR, carbon capture, and CO2 storage

✅ Targets local demand, exports, and net-zero alignment

 

The Egyptian Electricity Holding Company (EEHC) and the Egyptian Natural Gas Holding Company (EGAS) signed a memorandum of understanding (MoU) with the Italian energy giant Eni to assess the technical and commercial feasibility of green and blue hydrogen production projects in Egypt, which many see as central to power companies' future strategies worldwide today.

Under the MoU, a study will be conducted to assess joint projects for the production of green hydrogen using electricity generated from renewable energy and supported by regional electricity interconnections where relevant, and blue hydrogen using the storage of CO2 in depleted natural gas fields, according to a statement by the Ministry of Petroleum on Thursday.

The study will also estimate the potential local market consumption of hydrogen and export opportunities, taking cues from Ontario's hydrogen economy proposal to align electricity rates for growth.

This agreement is part of Eni's objective to achieve zero net emissions by 2050 and Egypt's strategy towards diversifying the energy mix and developing hydrogen projects in collaboration with major international companies, taking note of Italy's green hydrogen initiatives in Sicily as a comparable effort.

It signed the deal with Egyptian Natural Gas Holding (EGAS) and Egyptian Electricity Holding Co. (EEHC).

The companies will carry out a joint study on producing renewable energy powered green hydrogen, informed by electrolyzer investments in similar projects, where applicable. They will also work on blue hydrogen. This involves reforming natural gas and capturing the resulting CO2, in this instance in depleted natural gas fields.

The study will also consider domestic hydrogen use and export options, including funding models like the Hydrogen Innovation Fund now in Ontario.

Eni said the MoU was in line with its plans to eliminate net emissions and emissions cancel emission intensity by 2050. The company noted the agreement was in line with Egypt’s plan for the energy transition, in which it pursues hydrogen plans with major international companies, alongside broader clean-tech collaboration such as Tesla cooperation discussions in Dubai, to accelerate progress.

 

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Alberta set to retire coal power by 2023, ahead of 2030 provincial deadline

Alberta coal phaseout accelerates as utilities convert to natural gas, cutting emissions under TIER regulations and deploying hydrogen-ready, carbon capture capable plants, alongside new solar projects in a competitive, deregulated electricity market.

 

Key Points

A provincewide shift from coal to natural gas and renewables, cutting power emissions years ahead of the 2030 target.

✅ Capital Power, TransAlta converting coal units to gas

✅ TIER pricing drives efficiency, carbon capture readiness

✅ Hydrogen-ready turbines, solar projects boost renewables

 

Alberta is set to meet its goal to eliminate coal-fired electricity production years earlier than its 2030 target, amid a broader shift to cleaner energy in the province, thanks to recently announced utility conversion projects.

Capital Power Corp.’s plan to spend nearly $1 billion to switch two coal-fired power units west of Edmonton to natural gas, and stop using coal entirely by 2023, was welcomed by both the province and the Pembina Institute environmental think-tank.

In 2014, 55 per cent of Alberta’s electricity was produced from 18 coal-fired generators. The Alberta government announced in 2015 it would eliminate emissions from coal-fired electricity generation by 2030.

Dale Nally, associate minister of Natural Gas and Electricity, said Friday that decisions by Capital Power and other utilities to abandon coal will be good for the environment and demonstrates investor confidence in Alberta’s deregulated electricity market, where the power price cap has come under scrutiny.

He credited the government’s Technology Innovation and Emissions Reduction (TIER) regulations, which put a price on industrial greenhouse gas emissions, as a key factor in motivating the conversions.

“Capital Power’s transition to gas is a great example of how private industry is responding effectively to TIER, as it transitions these facilities to become carbon capture and hydrogen ready, which will drive future emissions reductions,” Nally said in an email.

Capital Power said direct carbon dioxide emissions at its Genesee power facility near Edmonton will be about 3.4 million tonnes per year lower than 2019 emission levels when the project is complete.

It says the natural gas combined cycle units it’s installing will be the most efficient in Canada, adding they will be capable of running on 30 per cent hydrogen initially, with the option to run on 95 per cent hydrogen in future with minor investments.

In November, Calgary-based TransAlta Corp. said it will end operations at its Highvale thermal coal mine west of Edmonton by the end of 2021 as it switches to natural gas at all of its operated coal-fired plants in Canada four years earlier than previously planned.

The Highvale surface coal mine is the largest in Canada, and has been in operation on the south shore of Wabamun Lake in Parkland County since 1970.

The moves by the two utilities and rival Atco Ltd., which announced three years ago it would convert to gas at all of its plants by this year, mean significant emissions reduction and better health for Albertans, said Binnu Jeyakumar, director of clean energy for Pembina.

“Alberta’s early coal phaseout is also a great lesson in good policy-making done in collaboration with industry and civil society,” she said.

“As we continue with this transformation of our electricity sector, it is paramount that efforts to support impacted workers and communities are undertaken.”

She added the growing cost-competitiveness of renewable energy, such as wind power, makes coal plant retirements possible, applauding Capital Power’s plans to increase its investments in solar power.

In Ontario, clean power policy remains a focus as the province evaluates its energy mix.

The company announced it would go ahead with its 75-megawatt Enchant Solar power project in southern Alberta, investing between $90 million and $100 million, and that it has signed a 25-year power purchase agreement with a Canadian company for its 40.5-MW Strathmore Solar project now under construction east of Calgary.
 

 

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FERC needs to review capacity market performance, GAO recommends

FERC Capacity Markets face scrutiny as GAO flags inconsistent data on resource adequacy and costs, urging performance goals, risk assessment, and better metrics across PJM, ISO-NE, NYISO, and MISO amid cost-recovery proposals.

 

Key Points

FERC capacity markets aim for resource adequacy, but GAO finds weak data and urges goals and performance reviews.

✅ GAO cites inconsistent data on resource adequacy and costs

✅ Calls for performance goals, metrics, and risk assessment

✅ Applies to PJM, ISO-NE, NYISO; MISO market is voluntary

 

Capacity markets may or may not be functioning properly, but FERC can't adequately make that determination, according to the GAO report.

"Available information on the level of resource adequacy ... and related costs in regions with and without capacity markets is not comprehensive or consistent," the report found. "Moreover, consistent data on historical trends in resource adequacy and related costs are not available for regions without capacity markets."

The review concluded that FERC collects some useful information in regions with and without capacity markets, but GAO said it "identified problems with data quality, such as inconsistent data."

GAO included three recommendations, including calling for FERC to take steps to improve the quality of data collected, and regularly assess the overall performance of capacity markets by developing goals for those assessments.

"FERC should develop and document an approach to regularly identify, assess, and respond to risks that capacity markets face," the report also recommended. The commission "has not established performance goals for capacity markets, measured progress against those goals, or used performance information to make changes to capacity markets as needed."

The recommendation comes as the agency is grappling with a controversial proposal to assure cost-recovery for struggling coal and nuclear plants in the power markets. So far, the proposal would only apply to power markets with capacity markets, including PJM Interconnection, the New England ISO, the New York ISO and possibly MISO. However MISO only has a voluntary capacity market, making it unclear how the proposed rule would be applied there. 

 

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All-electric home sports big windows, small footprint

Cold-Climate Heat Pumps deliver efficient heating and cooling for Northern B.C. Net Zero Ready homes, with air-source Mitsubishi H2i systems, triple-pane windows, blower door ACH 0.8, BC Hydro rebates, and CleanBC incentives.

 

Key Points

Electric air-source systems that heat and cool in subzero climates, cutting emissions and lowering energy costs.

✅ Net Zero Ready, Step Code 5, ACH 0.8 airtightness

✅ Operate efficiently to about -28 C with backup heat

✅ Eligible for BC Hydro and CleanBC rebates

 

Heat pump provides heating, cooling in northern B.C. home
It's a tradition at Vanderhoof-based Northern Homecraft that, on the day of the blower door test for a just-completed home, everyone who worked on the build gathers to watch it happen. And in the spring of 2021, on a dazzling piece of land overlooking the mouth of the Stuart River near Fort St. James, that day was a cause for celebration.

A new 3,400-square foot home subjected to the blower door test – a diagnostic tool to determine how much air is entering or escaping from a home – was rated as having just .8 air changes per hour (ACH). That helps make it a Net Zero Ready home, and BC Energy Code Step 5 compliant. That means it would take about a third of the amount of energy to heat the home compared to a typical similar-sized home in B.C. today.

From an energy-efficiency perspective, this is a home whose evident beauty is anything but skin deep.

"The home has lot of square footage of finished living space, and it also has a lot of glazing," says Northern Homecraft owner Shay Bulmer, referring to the home's large windows. "We had a lot of window space to deal with, as well as large vaulted open areas where you can only achieve so much additional insulation. There were a few things that the home had going against it as far as performance goes. There were challenges in keeping it comfortable year-round."


Well-insulated home ideal for heat pump option
Most homes in colder areas of B.C. lean on gas-fueled heating systems to deal with the often long, chilly winters. But with the arrival of cold climate heat pumps capable of providing heat efficiently when temperatures dip as low as -30°C, there's now a clean option for those homes, and using more electricity for heat is gaining support in the North as well.

Heat pumps are an increasingly popular option, both for new and existing homes, because they avoid carbon emissions associated with fossil use while also offering summer cooling, even as record-high electricity demand in Yukon underscores the need for efficient systems.

The Fort St. James home, which was built with premium insulation, airtightness and energy efficiency in mind, made the decision to opt for a heat pump even easier. Still, the heat pump option took the home's owners Dexter and Cheryl Hodder by surprise. While their focus was on designing a home that took full advantage of views down to the river, the couple was under the distinct impression that heat pumps couldn't cut it in the chilly north.

"I wasn't really considering a heat pump, which I thought was only a good solution in a moderate climate," says Dexter, who as director of research and education for the John Prince Research Forest, studies wildlife and forestry interactions in north central B.C. "The specs on the heat pump indicate it would work down to -28°C, and I was skeptical of that. But it worked exactly to spec. It almost seems ridiculous to generate heat from outside air at those low temperatures, but it does."

 

Getting it right with support and rebates
Northern Homecraft took advantage of BC Hydro's Mechanical System Design Pilot program to ensure proper heat pump system design, installation, and verification for the home were applied, and with BC Hydro's first call for power in 15 years driven by electrification, the team prioritized efficient load management.

Based on the home's specific location, size, and performance targets, they installed a ducted Mitsubishi H2I air-source heat pump system. Windows are triple pane, double coated, and a central feature of the home, while insulation specifications were R-40 deep frame insulation in the exterior walls, R-80 insulation in the attic, and R-40 insulation in the vaulted ceilings.

The combination of the year-round benefits of heat pumps, their role in reducing fossil fuel emissions, and the availability of rebates, is making the systems increasingly attractive in B.C., especially as two new BC generating stations were recently commissioned to expand clean supply.

BC Hydro offers home renovation rebates of up to $10,000 for energy-efficient upgrades to existing homes. Rebates are available for windows and doors, insulation, heat pumps, and heat pump hot water heaters. In partnership with CleanBC, rebates of up to $11,000 are also available – when combined with the federal Greener Homes program – for those switching from fossil fuel heating to an electric heat pump.


'Heat dome' pushes summer highs to 40°C
Cooling wasn't really a consideration for Dexter and Cheryl when they were living in a smaller bungalow shaded by trees. But they knew that with the big windows, vaulted ceiling in the living room, and an upstairs bedroom in the new home, there may come a time when they needed air conditioning.

That day arrived shortly after the home was built, as the infamous "heat dome" settled on B.C. and drove temperatures at Fort St. James to a dizzying 40°C.

"It was disgustingly hot, and I don't care if I never see that again here," says Hodder, with a laugh. "But the heat pump maintained the house really nicely throughout, at about 22 degrees. The whole house stayed cool. We just had to close the door to the upper bedroom so it wasn't really heating up during the day."

Hodder says he had to work with the heat pump manufacturer Mitsubishi a couple times over that first year to fix a few issues with the system's controls. But he's confident that the building's tight and well-insulated envelope, and the heat pump's backup electric heat that kicks in when temperatures dip below -28°C, will make it the system-for-all-seasons it was designed to be.

Even with the use of supplemental electric heating during the record chill of December-January, the home's energy costs weren't much higher than the mid-winter energy bills they used to pay in the couple's smaller bungalow that relied on a combination of gas-fired in-floor heating and electric baseboards, as gas-for-electricity swaps are being explored elsewhere.

Fort St. James is a former fur trading post located northwest of Prince George and a short drive north of Vanderhoof. Winters are cold and snowy, with average daily low temperatures in December and January of around -14°C.

"During the summer and into the fall, we were paying well less than $100 a month," says Hodder, looking back at electricity bills over the first year in the home. "And that's everything. We're only electric here, and we also had both of us working from home all last year."

 

Word of mouth making heat pumps popular in Fort St. James
While the size of the home presented new challenges for the builders, it's one of five Net Zero Ready or Net Zero homes – all equipped with some form of heat pump – that Northern Homecraft has built in Fort St. James, even as debates about going nuclear for electricity continue in B.C.

The smallest of the homes is a two-bedroom, one-bathroom home that's just under 900 square feet. Northern Homecraft may be based in Vanderhoof, but it's the much smaller town of Fort St. James where they're making their mark with super-efficient homes. Net Zero Ready homes are up to 80% more efficient than the standard building code, and become Net Zero once renewable energy generation – usually in the form of photovoltaic solar – is installed, and programs like switching 5,000 homes to geothermal show the broader momentum for clean heating.

"We were pretty proud that the first home we built in Fort St. James was the first single family Net Zero Ready home built in B.C.," says Northern Homecraft's Bulmer. "And I think it's kind of caught on in a smaller community where everyone talks to everyone."

 

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