Officials mull alternative-energy regulations

UK Hydrogen Storage Caverns enable long-duration, low-carbon electricity balancing, storing surplus wind and solar power as green hydrogen in salt formations to enhance grid reliability, energy security, and net zero resilience by 2035 and 2050.

Key Points

They are salt caverns storing green hydrogen to balance wind and solar, stabilizing a low-carbon UK grid.

✅ Stores surplus wind and solar as green hydrogen in salt caverns

✅ Enables long-duration, low-carbon grid balancing and security

✅ Complements wind and solar; reduces dependence on flexible CCS

The U.K. government must kick-start the construction of large-scale hydrogen storage facilities if it is to meet its pledge that all electricity will come from low-carbon electricity sources by 2035 and reach legally binding net zero targets by 2050, according to a report by the Royal Society.

The report, "Large-scale electricity storage," published Sep. 8, examines a wide variety of ways to store surplus wind and solar generated electricity—including green hydrogen, advanced compressed air energy storage (ACAES), ammonia, and heat—which will be needed when Great Britain's electricity generation is dominated by volatile wind and solar power.

It concludes that large scale electricity storage is essential to mitigate variations in wind and sunshine, particularly long-term variations in the wind, and to keep the nation's lights on. Storing most of the surplus as hydrogen, in salt caverns, would be the cheapest way of doing this.

The report, based on 37 years of weather data, finds that in 2050 up to 100 Terawatt-hours (TWh) of storage will be needed, which would have to be capable of meeting around a quarter of the U.K.'s current annual electricity demand. This would be equivalent to more than 5,000 Dinorwig pumped hydroelectric dams. Storage on this scale, which would require up to 90 clusters of 10 caverns, is not possible with batteries or pumped hydro.

Storage requirements on this scale are not currently foreseen by the government, and the U.K.'s energy transition faces supply delays. Work on constructing these caverns should begin immediately if the government is to have any chance of meeting its net zero targets, the report states.

Sir Chris Llewellyn Smith FRS, lead author of the report, said, "The need for long-term storage has been seriously underestimated. Demand for electricity is expected to double by 2050 with the electrification of heat, transport, and industrial processing, as well as increases in the use of air conditioning, economic growth, and changes in population.

"It will mainly be met by wind and solar generation. They are the cheapest forms of low-carbon electricity generation, but are volatile—wind varies on a decadal timescale, so will have to be complemented by large scale supply from energy storage or other sources."

The only other large-scale low-carbon sources are nuclear power, gas with carbon capture and storage (CCS), and bioenergy without or with CCS (BECCS). While nuclear and gas with CCS are expected to play a role, they are expensive, especially if operated flexibly.

Sir Peter Bruce, vice president of the Royal Society, said, "Ensuring our future electricity supply remains reliable and resilient will be crucial for our future prosperity and well-being. An electricity system with significant wind and solar generation is likely to offer the lowest cost electricity but it is essential to have large-scale energy stores that can be accessed quickly to ensure Great Britain's energy security and sovereignty."

Combining hydrogen with ACAES, or other forms of storage that are more efficient than hydrogen, could lower the average cost of electricity overall, and would lower the required level of wind power and solar supply.

There are currently three hydrogen storage caverns in the U.K., which have been in use since 1972, and the British Geological Survey has identified the geology for ample storage capacity in Cheshire, Wessex and East Yorkshire. Appropriate, novel business models and market structures will be needed to encourage construction of the large number of additional caverns that will be needed, the report says.

Sir Chris observes that, although nuclear, hydro and other sources are likely to play a role, Britain could in principle be powered solely by wind power and solar, supported by hydrogen, and some small-scale storage provided, for example, by batteries, that can respond rapidly and to stabilize the grid. While the cost of electricity would be higher than in the last decade, we anticipate it would be much lower than in 2022, he adds.

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Smart Grid Modernization unites distributed energy resources, energy storage, EV charging, advanced metering, and bidirectional power flows to upgrade transmission and distribution infrastructure for reliability, resilience, cybersecurity, and affordable, clean power.

Key Points

Upgrading grid hardware and software to integrate DERs, storage, and EVs for a reliable and affordable power system.

✅ Enables DER, storage, and EV integration with bidirectional flows

✅ Improves reliability, resilience, and grid cybersecurity

✅ Requires early investment in sensors, inverters, and analytics

Much has been written, predicted, and debated in recent years about the future of the electricity system. The discussion isn’t simply about fossil fuels versus renewables, as often dominates mainstream energy discourse. Rather, the discussion is focused on something much larger and more fundamental: the very design of how and where electricity should be generated, delivered, and consumed.

Central to this discussion are arguments in support of, or in opposition to, the traditional model versus that of the decentralized or “emerging” model. But this is a false choice. The only choice that needs making is how to best transition to a smarter grid, and do so in a reliable and affordable manner that reflects grid modernization affordability concerns for utilities today. And the most effective and immediate means to accomplish that is to encourage and facilitate early investment in grid-related infrastructure and technology.

The traditional, or centralized, model has evolved since the days of Thomas Edison, but the basic structure is relatively unchanged: generate electrons at a central power plant, transmit them over a unidirectional system of high-voltage transmission lines, and deliver them to consumers through local distribution networks. The decentralized, or emerging, model envisions a system that moves away from the central power station as the primary provider of electricity to a system in which distributed energy resources, energy storage, electric vehicles, peer-to-peer transactions, connected appliances and devices, and sophisticated energy usage, pricing, and load management software play a more prominent role.

Whether it’s a fully decentralized and distributed power system, or the more likely centralized-decentralized hybrid, it is apparent that the way in which electricity is produced, delivered, and consumed will differ from today’s traditional model. And yet, in many ways, the fundamental design and engineering that makes up today’s electric grid will serve as the foundation for achieving a more distributed future. Indeed, as the transition to a smarter grid ramps up, the grid’s basic structure will remain the underlying commonality, allowing the grid to serve as a facilitator to integrate emerging technologies, including EV charging stations, rooftop solar, demand-side management software, and other distributed energy resources, while maximizing their potential benefits and informing discussions about California’s grid reliability under ambitious transition goals.

A loose analogy here is the internet. In its infancy, the internet was used primarily for sending and receiving email, doing homework, and looking up directions. At the time, it was never fully understood that the internet would create a range of services and products that would impact nearly every aspect of everyday life from online shopping, booking travel, and watching television to enabling the sharing economy and the emerging “Internet of Things.”

Uber, Netflix, Amazon, and Nest would not be possible without the internet. But the rapid evolution of the internet did not occur without significant investment in internet-related infrastructure. From dial-up to broadband to Wi-Fi, companies have invested billions of dollars to update and upgrade the system, allowing the internet to maximize its offerings and give way to technological breakthroughs, innovative businesses, and ways to share and communicate like never before.  

The electric grid is similar; it is both the backbone and the facilitator upon which the future of electricity can be built. If the vision for a smarter grid is to deploy advanced energy technologies, create new business models, and transform the way electricity is produced, distributed, and consumed, then updating and modernizing existing infrastructure and building out new intelligent infrastructure need to be top priorities. But this requires money. To be sure, increased investment in grid-related infrastructure is the key component to transitioning to a smarter grid; a grid capable of supporting and integrating advanced energy technologies within a more digital grid architecture that will result in a cleaner, more modern and efficient, and reliable and secure electricity system.

The inherent challenges of deploying new technologies and resources — reliability, bidirectional flow, intermittency, visibility, and communication, to name a few, as well as emerging climate resilience concerns shaping planning today, are not insurmountable and demonstrate exactly why federal and state authorities and electricity sector stakeholders should be planning for and making appropriate investment decisions now. My organization, Alliance for Innovation and Infrastructure, will release a report Wednesday addressing these challenges facing our infrastructure, and the opportunities a distributed smart grid would provide. From upgrading traditional wires and poles and integrating smart power inverters and real-time sensors to deploying advanced communications platforms and energy analytics software, there are numerous technologies currently available and capable of being deployed that warrant investment consideration.

Making these and similar investments will help to identify and resolve reliability issues earlier, and address vulnerabilities identified in the latest power grid report card findings, which in turn will create a stronger, more flexible grid that can then support additional emerging technologies, resulting in a system better able to address integration challenges. Doing so will ease the electricity evolution in the long-term and best realize the full reliability, economic, and environmental benefits that a smarter grid can offer.  

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NGCP-SGCC Partnership drives transmission grid modernization in the Philippines, boosting high-voltage capacity, reliability, and resilience, while developing engineering talent via the Trailblazers Program to meet Southeast Asia best practices and utility standards.

Key Points

A partnership to modernize the Philippines' grid, boost high-voltage capacity, and upskill NGCP engineers.

✅ Modernizes transmission assets and grid reliability nationwide

✅ Trailblazers Program develops NGCP's engineering leadership

✅ SGCC knowledge transfer on UHV, high-voltage, and best practices

The National Grid Corp. of the Philippines (NGCP) is building on its partnership with State Grid Corp of China (SGCC) to expand and modernize transmission facilities, as well as enhance the capabilities of its personnel to advance the country's grid network, aligning with smart grid transformation in Egypt seen in other markets. NGCP Internal Affairs Department head Edwin Natividad said the grid operator is implementing various development programs with SGCC to make the country's power grid among the best power utilities in Asia.

"We have to look at policies aligned with best global practices, including smart grid solutions increasingly adopted worldwide, that we can choose in adopting in the Philippines too," he said. One of NGCP's flagship development program is the Trailblazers Program, the company's strategy to further develop engineers "who will not just be technical experts, but also be the change agents and movers in the NGCP organization as well as in the Philippines' power sector," Natividad said.

"Having the support of the largest utility in the world gives us comfort that this program is designed and implemented by the best in the power industry," he said. Under the program, high performing personnel participating will be prepared for bigger roles later on in their careers at NGCP.

Business ( Article MRec ), pagematch: 1, sectionmatch: 1 "The advantage of such a pool is that it provides flexibility and, eventually, organizational self-sufficiency around the current and future talent needs of NGCP," Natividad said. Now on its third edition, the Trailblazers Program has already sent 76 personnel since it started in November 2016. Natividad said more than 16 of those who previously attended similar programs have already assumed higher roles in NGCP.

Apart from technical skills development, NGCP's partnership with SGCC also provides technical development to improve on the physical transmission assets. "If you will compare the facilities being handled by SGCC with other countries, in terms of handling high voltage capability, SGCC is way ahead.

The higher the voltage it's going to be more difficult to handle," Natividad said, adding they can handle more power to distribute to power distributors. As an example, SGCC's transmission facilities can handle high voltage to as much as 1,000 kiloVolts (kV), whereas the Philippines only has one high voltage facility, the interconnection between Luzon and Visayas, which can handle 500 kV, echoing proposals for macrogrids in Canada to improve reliability.

Natividad said NGCP was the first and biggest investment of SGCC outside of China before it made investments in other parts of the world, even as cybersecurity concerns in Britain have influenced supplier choices. A consortium among businessmen Henry Sy Jr., Robert Coyuito Jr., and SGCC as technical partner, NGCP holds a 25-year concession contract to operate and maintain the country's transmission grid.

Earlier, Sy, NGCP president and CEO, said the company is targeting to become the best utility firm in Southeast Asia. Since it took over the operations and maintenance of the country's power transmission network in 2009, the grid operator has introduced major physical and technological upgrades to ageing state-owned lines and facilities, while in Great Britain an independent operator model is being advanced to reshape system operations.

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Lake Erie Connector Investment advances a 1,000 MW HVDC transmission link connecting Ontario to the PJM Interconnection, enhancing grid reliability, clean power trade, and GHG reductions through a public-private partnership led by CIB and ITC.

Key Points

A $1.7B public-private HVDC project linking Ontario and PJM to boost reliability, cut GHGs, and enable clean power trade.

✅ 1,000 MW, 117 km HVDC link between Ontario and PJM

✅ $655M CIB and $1.05B private financing, ITC to own-operate

✅ Cuts system costs, boosts reliability, reduces GHG emissions

The Canada Infrastructure Bank (CIB) and ITC Investment Holdings (ITC) have signed an agreement in principle to invest $1.7 billion in the Lake Erie Connector project.

Under the terms of the agreement, the CIB will invest up to $655 million or up to 40% of the project cost. ITC, a subsidiary of Fortis Inc., and private sector lenders will invest up to $1.05 billion, the balance of the project's capital cost.

The CIB and ITC Investment Holdings signed an agreement in principle to invest $1.7B in the Lake Erie Connector project.

The Lake Erie Connector is a proposed 117 kilometre underwater transmission line connecting Ontario with the PJM Interconnection, the largest electricity market in North America, and aligns with broader regional efforts such as the Maine transmission line to import Quebec hydro to strengthen cross-border interconnections.

The 1,000 megawatt, high-voltage direct current connection will help lower electricity costs for customers in Ontario and improve the reliability and security of Ontario's energy grid, complementing emerging solutions like battery storage across the province. The Lake Erie Connector will reduce greenhouse gas emissions and be a source of low-carbon electricity in the Ontario and U.S. electricity markets.

During construction, the Lake Erie Connector is expected to create 383 jobs per year and drive more than $300 million in economic activity, and complements major clean manufacturing investments like a $1.6 billion battery plant in the Niagara Region that supports the EV supply chain. Over its life, the project will provide 845 permanent jobs and economic benefits by boosting Ontario's GDP by $8.8 billion.

The project will also help Ontario to optimize its current infrastructure, avoid costs associated with existing production curtailments or shutdowns. It can leverage existing generation capacity and transmission lines to support electricity demand, alongside new resources such as the largest battery storage project planned for southwestern Ontario.

ITC continues its discussions with First Nations communities and is working towards meaningful participation in the near term and as the project moves forward to financial close.

The CIB anticipates financial close late in 2021, pending final project transmission agreements, with construction commencing soon after. ITC will own the transmission line and be responsible for all aspects of design, engineering, construction, operations and maintenance.

ITC acquired the Lake Erie Connector project in August 2014 and it has received all necessary regulatory and permitting approvals, including a U.S. Presidential Permit and approval from the Canada Energy Regulator.

This is the CIB's first investment commitment in a transmission project and another example of the CIB's momentum to quickly implement its $10B Growth Plan, amid broader investments in green energy solutions in British Columbia that support clean growth.

Endorsements

This project will allow Ontario to export its clean, non-emitting power to one of the largest power markets in the world and, as a result, benefit Canadians economically while also significantly contributing to greenhouse gas emissions reductions in the PJM market. The project allows Ontario to better manage peak capacity and meet future reliability needs in a more sustainable way. This is a true win-win for both Canada and the U.S., both economically and environmentally.
Ehren Cory, CEO, Canada Infrastructure Bank

The Lake Erie Connector has tremendous potential to generate customer savings, help achieve shared carbon reduction goals, and increase electricity system reliability and flexibility. We look forward to working with the CIB, provincial and federal governments to support a more affordable, customer-focused system for Ontarians. 
Jon Jipping, EVP & COO, ITC Investment Holdings Inc., a subsidiary of Canadian-based Fortis Inc. 

We are encouraged by this recent announcement by the Canada Infrastructure Bank. Mississaugas of the Credit First Nation has an interest in projects within our historic treaty lands that have environmental benefits and that offer economic participation for our community.
Chief Stacey Laforme, Mississaugas of the Credit First Nation

While our evaluation of the project continues, we recognize this project can contribute to the economic resilience of our Shareholder, the Mississaugas of the Credit First Nation. Subject to the successful conclusion of our collaborative efforts with ITC, we look forward to our involvement in building the necessary infrastructure that enable Ontario's economic engine.
Leonard Rickard, CEO, Mississaugas of the Credit Business Corporation

The Lake Erie Connector demonstrates the advantages of public-private partnerships to develop critical infrastructure that delivers greater value to Ontarians. Connecting Ontario's electricity grid to the PJM electricity market will bring significant, tangible benefits to our province. This new connection will create high-quality jobs, improve system flexibility, and allow Ontario to export more excess electricity to promote cost-savings for Ontario's electricity consumers.
Greg Rickford, Minister of Energy, Northern Development and Mines, Minister of Indigenous Affairs

With the US pledging to achieve a carbon-free electrical grid by 2035, Canada has an opportunity to export clean power, helping to reduce emissions, maximizing clean power use and making electricity more affordable for Canadians. The Lake Erie Connector is a perfect example of that. The Canada Infrastructure Bank's investment will give Ontario direct access to North America's largest electricity market - 13 states and D.C. This is part of our infrastructure plan to create jobs across the country, tackle climate change, and increase Canada's competitiveness in the clean economy, alongside innovation programs like the Hydrogen Innovation Fund that foster clean technology.

Quick Facts

• The Lake Erie Connector is a 1,000 megawatt, 117 kilometre long underwater transmission line connecting Ontario and Pennsylvania.
• The PJM Interconnection is a regional transmission organization coordinating the movement of wholesale electricity in all or parts of Delaware, Illinois, Indiana, Kentucky, Maryland, Michigan, New Jersey, North Carolina, Ohio, Pennsylvania, Tennessee, Virginia, West Virginia and the District of Columbia.
• The project will help to reduce electricity system costs for customers in Ontario, and aligns with ongoing consultations on industrial electricity pricing and programs, while helping to support future capacity needs.
• The CIB is mandated to invest CAD $35 billion and attract private sector investment into new revenue-generating infrastructure projects that are in the public interest and support Canadian economic growth.
• The investment commitment is subject to final due diligence and approval by the CIB's Board.

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U.S. Power Grid Supply Shortages strain reliability as heat waves, hurricanes, and drought drive peak demand; transformer scarcity, gas constraints, and renewable delays raise outage risks across ERCOT and MISO, prompting FERC warnings.

Key Points

They are equipment and fuel constraints that, amid extreme weather and peak demand, elevate outage risks.

✅ Transformer shortages delay storm recovery and repairs.

✅ Record gas burn, low hydro tighten generation capacity.

✅ ERCOT and MISO warn of rolling outages in heat waves.

U.S. power companies are facing supply crunches amid the U.S. energy crisis that may hamper their ability to keep the lights on as the nation heads into the heat of summer and the peak hurricane season.

Extreme weather events such as storms, wildfires and drought are becoming more common in the United States. Consumer power use is expected to hit all-time highs this summer, reflecting unprecedented electricity demand across the Eastern U.S., which could strain electric grids at a time when federal agencies are warning the weather could pose reliability issues.

Utilities are warning of supply constraints for equipment, which could hamper efforts to restore power during outages. They are also having a tougher time rebuilding natural gas stockpiles for next winter, after the Texas power system failure highlighted cold-weather vulnerabilities, as power generators burn record amounts of gas following the shutdown of dozens of coal plants in recent years and extreme drought cuts hydropower supplies in many Western states.

"Increasingly frequent cold snaps, heat waves, drought and major storms continue to challenge the ability of our nation’s electric infrastructure to deliver reliable affordable energy to consumers," Richard Glick, chairman of the U.S. Federal Energy Regulatory Commission (FERC), said earlier this month.

Federal agencies responsible for power reliability like FERC have warned that grids in the western half of the country could face reliability issues this summer as consumers crank up air conditioners to escape the heat, with nationwide blackout risks not limited to Texas. read more

Some utilities have already experienced problems due to the heat. Texas' grid operator, the Electric Reliability Council of Texas (ERCOT), was forced to urge customers to conserve energy as the Texas power grid faced another crisis after several plants shut unexpectedly during an early heat wave in mid-May. read more

In mid-June, Ohio-based American Electric Power Co (AEP.O) imposed rolling outages during a heat wave after a storm damaged transmission lines and knocked out power to over 200,000 homes and businesses.

The U.S. Midwest faces the most severe risk because demand is rising while nuclear and coal power supplies have declined. read more

The Midcontinent Independent System Operator (MISO), which operates the grid from Minnesota to Louisiana, warned that parts of its coverage area are at increased risk of temporary outages to preserve the integrity of the grid.

Supply-chain issues have already delayed the construction of renewable energy projects across the country, and the aging U.S. grid is threatening progress on renewables and EVs. Those renewable delays coupled with tight power in the Midwest prompted Wisconsin's WEC Energy Group Inc (WEC.N) and Indiana's NiSource Inc (NI.N) to delay planned coal plant shutdowns in recent months.

BRACING FOR SUPPLY SHORTAGES
Utility operators are conserving their inventory of parts and equipment as they plan to prevent summer power outages during severe storms. Over the last several months, that means operators have been getting creative.

"We’re doing a lot more splicing, putting cables together, instead of laying new cable because we're trying to maintain our new cable for inventory when we need it," Nick Akins, chief executive of AEP, said at the CERAWeek energy conference in March.

Transformers, which often sit on top of electrical poles and convert high-voltage energy to the power used in homes, are in short supply.

New Jersey-based Public Service Enterprise Group Inc (PSEG) (PEG.N) Chief Executive Ralph Izzo told Reuters the company has had to look at alternate supply options for low voltage transformers.

"You don’t want to deplete your inventory because you don't know when that storm is coming, but you know it's coming," Izzo said.

Some utilities are facing waiting times of more than a year for transformer parts, the National Rural Electric Cooperative Association and the American Public Power Association told U.S. Energy Secretary Jennifer Granholm in a May letter.

Summer is just starting, but U.S. weather so far this year has already been about 21% warmer than the 30-year norm, according to data provider Refinitiv.

"If we have successive days of 100-degree-heat, those pole top transformers, they start popping like Rice Krispies, and we would not have the supply stack to replace them," Izzo said.

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UK Market Stability Outlook remains febrile as the Bank of England, Treasury, and OBR forecasts shape fiscal policy, interest rates, gilt yields, inflation, energy bills, and pound sterling, with Oct. 31 guidance to reassure investors.

Key Points

A view of investor confidence as BOE policy, fiscal plans, and energy aid shape inflation and interest rates.

✅ Markets await Oct. 31 fiscal statement and OBR projections

✅ Energy support design drives inflation and disposable income

✅ Pound weakness adds imported inflation; rates seen up 75 bps

Bank of England Deputy Governor Dave Ramsden said financial markets are still unsettled about the outlook for the UK and that a Treasury statement due on Oct. 31 may provide some reassurance.

Speaking to the Treasury Committee in Parliament, Ramsden said officials in government and the central bank are dealing with huge economic shocks, notably the surge in energy prices that came with Russia’s attack on Ukraine. Investors are reassessing where interest rates and the fiscal stance are headed.

“Markets remain quite febrile,” Ramsden told members of Parliament in London on Monday. “Things have not settled down yet.”

He described the events following Prime Minister Liz Truss’s ill-fated fiscal statement on Sept. 23, which set out a series of tax cuts funded by borrowing that spooked investors and triggered a rout in UK assets. Ramsden said those events damaged the UK’s credibility among investors, but reversing that program and Truss’s decision to step aside have helped the nation regain confidence.

“Credibility is hard won and easily lost,” Ramsden said. “That credibility is being recovered. That has to be followed through. A return to the kind of stability around policy making and around the framing of fiscal events will be really important.”

He said the issue with the Sept. 23 statement was that “it had one side of the fiscal arithmetic in it” and that the decision to include forecasts from the Office for Budget Responsibility will help underpin the confidence investors have in assessing the UK budget due out next week, including potential moves to end the link between gas and electricity prices for consumers.

“What we are going to get on Oct. 31 will be very important,” Ramsden said, “as it will address measures such as the price cap on household energy bills and other fiscal choices.”

“My sense is that will take account of all the statements on both the revenue and on the spending side.”

The central bank already was getting some information from Chancellor of the Exchequer Jeremy Hunt’s team about the fiscal statement due. Hunt said last week he’d curtail government plans to subsidize household fuel bills in April, when a 16% decrease in energy bills is anticipated, instead of letting it run as long as planned and replace it with a more targeted program. 

“To the extent possible, we will obviously have a little bit of time to take account of that before we make our decisions later next week,” Ramsden said.

With Truss stepping down in the next day and handing power to Rishi Sunak, it isn’t certain the Oct. 31 statement will go ahead as planned. Ramsden’s remarks confirm reports that Hunt is preparing to make the statement, amid a free electricity debate in the industry, even before Sunak names his team.

Any hint about what sort of package Hunt will offer on energy is crucial to the BOE’s forecasts. Without aid for energy, consumers will be exposed to high winter heating and electricity costs and to the full force of whatever happens in natural gas and electricity markets, and that will have a big impact on how much disposable income is available to households.

The energy plan, alongside the energy security bill, “will be a key element, as obviously it will have a bearing on the path for inflation, which is critical, but also how much additional support relative to what we were assuming at the time of the September MPC there will be for households at different points in the income distribution,” Ramsden added.

Investors currently expect the BOE to hike rates by 75 basis points next week.

Ramsden also said the BOE is watching the pound’s decline to assess how that changes the outlook for inflation.

“We have to take account of it,” Ramsden said. “When sterling deprreciaties that feeds through to imported inflation. It’s fallen quite significantly. The overall trend is down.”

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