Re-Volted by policy

By Financial Post


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When GM CEO Rick Wagoner unveiled the latest version of the plug-in Chevrolet Volt during the company’s 100th anniversary celebrations, he whistled the happy tune that current financial turmoil wouldn’t affect U.S. government loan guarantees to develop such “alternative” vehicles.

But Washington is suddenly looking strapped for cash, so the prospects for the $25-billion of cheap loans to the automotive industry that were approved last year as part of an energy bill are looking distinctly iffy. That is far from the VoltÂ’s only problem.

“The Volt symbolizes GM’s commitment to the future,” declared Mr. Wagoner, “the kind of technological innovation that our industry needs to respond to today and tomorrow’s energy and environmental challenges.”

But what it really symbolizes is a desperate response to the power of radical environmentalism, the threat of draconian policies and the dubious desire for energy independence.

Ironically, Bob Lutz, GM’s vice-chairman and the man brought in to revitalize its car line-up, has claimed that the theory of man-made climate change is a “crock of shit.” However, he is a convert to energy independence, which is one hell of a burden to put on any company’s balance sheet.

Mr. Lutz demonstrated his bravery by appearing on The Colbert Report, where he admitted that the Volt wouldn’t lay rubber in going from 0-60, but might get its owner laid with “no-makeup environmental types.”

Private pursuit of political or social objectives always tends to be a risky business, but the auto industry is being asked to help save the planet by performing just-in-time technological miracles.

The Volt, which GM announced two years ago, is being peddled as the great white hope of less gasoline-intensive driving (although perhaps such terminology is not entirely appropriate since a recent article in The Atlantic referred to the Volt — tongue in cheek — as “the Barack Obama of automobiles — everyone’s hope for change.”

According to GM, the car will have a top speed of 160 km/h and a range of 64 km without using any gasoline. Then a gas engine will charge up — not to run the car, but to run its generator and charge its battery, which will continue to supply the car’s motive power.

There are a couple of gargantuan hurdles facing the Volt. One is that the technology to achieve the above-mentioned marvels doesnÂ’t actually exist. Success still depends on advances in lithium ion battery technology that cannot be guaranteed. In any sane world, the battery technology breakthrough would be made before you started building a car around it, but GM is using the ready, fire, aim approach.

The other problem is that even if the thousands of engineers toiling at GM and its component suppliers actually pull of this marvel, its retail cost is estimated at between $35,000 and $50,000.

Within GM, apparently, the Volt project is being compared to the Apollo moonshot, but presumably they donÂ’t mean crushingly expensive and commercially pointless. GM cannot afford a no-expenses spared approach because it happens to be a profit-making corporation.

But invoking Apollo is perhaps useful in trying to pry loose those taxpayer funds.

Fighting man-made climate change is the new Earth-bound Apollo program, a rocket aimed at the worldÂ’s economy. But then if governments want to dictate what people drive, then presumably they should cough up some of the cash.

After all, as David Paterson, GM Canada’s VP of corporate and environmental affairs, told the Post’s Nicholas Van Praet, “We’re literally reinventing automobiles by regulation.”

The North American industry was already reeling from failure to respond to superior overseas competitors, and to horrendous legacy costs, which have now significantly been addressed, but it is hardly in sound shape.

Protecting the environment for future generations appears a legitimate if somewhat megalomanic objective, but this worthy sentiment has been hijacked by the UNÂ’s sustainable development agenda, which amounts to the greatest attack on markets since Das Kapital.

As for the VoltÂ’s prospects, we might remember that in 1999, DaimlerChrysler, as it then was, unveiled a sexy-looking soon-to-be-commercial vehicle, powered by a government-subsidized Ballard fuel cell, that reportedly went at 90 miles per hour for 280 miles. The problem was that the fuel cell (not the car, just the fuel cell) reportedly cost $35,000.

DaimlerChryslerÂ’s then head, Jurgen Schrempp, nevertheless claimed that such fuel-cell-powered cars could be on the road by 2004.

You will notice that they are not.

Perhaps the worst of all outcomes would be if GM did pull off its Volt miracle, because that would encourage activists and governments to believe that all they have to do to control the economy in the public — not to mention the planetary — interest is to threaten and regulate. But the odds seem stacked against any such success.

Like its previous electric car, the EV1, which was a dud, the Volt faces an uphill battle, and electric motors have trouble with hills. Meanwhile we can be absolutely sure about one critical aspect of the Volt, which is perhaps its most bizarre feature: it wonÂ’t have the slightest impact on either the global environment or the geopolitics of oil.

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As California enters a brave new energy world, can it keep the lights on?

California Grid Transition drives decarbonization with renewable energy, EV charging, microgrids, and energy storage, while tackling wildfire risk, aging infrastructure, and cybersecurity threats to build grid resilience and reliability across a rapidly electrifying economy.

 

Key Points

California Grid Transition is the statewide shift to renewables, storage, EVs, and resilient, secure infrastructure.

✅ Integrates solar, wind, storage, and demand response at scale

✅ Expands microgrids and DERs to enhance reliability and resilience

✅ Addresses wildfire, aging assets, and cybersecurity risks

 

Gretchen Bakke thinks a lot about power—the kind that sizzles through a complex grid of electrical stations, poles, lines and transformers, keeping the lights on for tens of millions of Californians who mostly take it for granted.

They shouldn’t, says Bakke, who grew up in a rural California town regularly darkened by outages. A cultural anthropologist who studies the consequences of institutional failures, she says it’s unclear whether the state’s aging electricity network and its managers can handle what’s about to hit it, as U.S. blackout risks continue to mount.

California is casting off fossil fuels to become something that doesn’t yet exist: a fully electrified state of 40 million people. Policies are in place requiring a rush of energy from renewable sources such as the sun and wind and calling for millions of electric cars that will need charging—changes that will tax a system already fragile, unstable and increasingly vulnerable to outside forces.

“There is so much happening, so fast—the grid and nearly everything about energy is in real transition, and there’s so much at stake,” said Bakke, who explores these issues in a book titled simply, “The Grid.”

The state’s task grew more complicated with this week’s announcement that Pacific Gas and Electric, which provides electricity for more than 5 million customer accounts, intends to file for bankruptcy in the face of potentially crippling liabilities from wildfires. But the reshaping of California’s energy future goes far beyond the woes of a single company.

The 19th-century model of one-way power delivery from utility companies to customers is being reimagined. Major utilities—and the grid itself—are being disrupted by rooftops paved with solar panels and the rise of self-sufficient neighborhood mini-grids. Whole cities and counties are abandoning big utilities and buying power from wholesalers and others of their choosing.

With California at the forefront of a new energy landscape, officials are racing to design a future that will not just reshape power production and delivery but also dictate how we get around and how our goods are made. They’re debating how to manage grid defectors, weighing the feasibility of an energy network that would expand to connect and serve much of the West and pondering how to appropriately regulate small power producers.

“We are in the depths of the conversation,” said Michael Picker, president of the state Public Utilities Commission, who cautions that even as the system is being rebooted, like repairing a car while driving in practice, there’s no real plan for making it all work.

Such transformation is exceedingly risky and potentially costly. California still bears the scars of having dropped its regulatory reins some 20 years ago, leaving power companies to bilk the state of billions of dollars it has yet to completely recover. And utility companies will undoubtedly pass on to their customers the costs of grid upgrades to defend against natural and man-made threats.

Some weaknesses are well known—rodents and tree limbs, for example, are common culprits in power outages, even as longer, more frequent outages afflict other parts of the U.S. A gnawing squirrel squeezed into a transformer on Thanksgiving Day three years ago, shutting off power to parts of Los Angeles International Airport. The airport plans to spend $120 million to upgrade its power plant.

But the harsh effects of climate change expose new vulnerabilities. Rising seas imperil coastal power plants. Electricity infrastructure is both threatened by and implicated in wildfires. Picker estimates that utility operations are related to one in 10 wildland fires in California, which can be sparked by aging equipment and winds that send tree branches crashing into power lines, showering flammable landscapes with sparks.

California utilities have been ordered to make their lines and equipment more fire-resistant as they’re increasingly held accountable for blazes they cause. Pacific Gas and Electric reported problems with some of its equipment at a starting point of California’s deadliest wildfire, which killed at least 86 people in November in the town of Paradise. The cause of the fire is under investigation.

New and complex cyber threats are more difficult to anticipate and even more dangerous. Computer hackers, operating a world away, can—and have—shut down electricity systems, toggling power on and off at will, and even hijacked the computers of special teams dispatched to restore control.

Thomas Fanning, CEO of Southern Co., one of the country’s largest utilities, recently disclosed that his teams have fended off multiple attempts to hack a nuclear power plant the firm operates. He called grid hacking “the most important under-reported war in American history.”

However, if you’ve got what seems like an insoluble problem requiring a to-the-studs teardown and innovative rebuild, California is a good place to start. After all, the first electricity grid was built in San Francisco in 1879, three years before Thomas Edison’s power station in New York City. (Edison’s plant burned to the ground a decade later.)

California’s energy-efficiency regulations have helped reduce statewide energy use, which peaked a decade ago and is on the decline, somewhat easing pressure on the grid. The major utilities are ahead of schedule in meeting their obligation to obtain power from renewable sources.

California’s universities are teaming with national research labs to develop cutting-edge solutions for storing energy produced by clean sources. California is fortunate in the diversity of its energy choices: hydroelectric dams in the north, large-scale solar operations in the Mojave Desert to the east, sprawling windmill farms in mountain passes and heat bubbling in the Geysers, the world’s largest geothermal field north of San Francisco. A single nuclear-power plant clings to the coast near San Luis Obispo, but it will be shuttered in 2025.

But more renewable energy, accessible at the whims of weather, can throw the grid off balance. Renewables lack the characteristic that power planners most prize: dispatchability, ready when called on and turned off when not immediately needed. Wind and sun don’t behave that way; their power is often available in great hunks—or not at all, as when clouds cover solar panels or winds drop.

In the case of solar power, it is plentiful in the middle of the day, at a time of low demand. There’s so much in California that most days the state pays its neighbors to siphon some off,  lest the excess impede the grid’s constant need for balance—for a supply that consistently equals demand.

So getting to California’s new goals of operating on 100 percent clean energy by 2045 and having 5 million electric vehicles within 12 years will require a shift in how power is acquired and managed. Consumers will rely more heavily on battery storage, whose efficiency must improve to meet that demand.

 

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Maritime Link sends first electricity between Newfoundland, Nova Scotia

Maritime Link HVDC Transmission connects Newfoundland and Nova Scotia to the North American grid, enabling renewable energy imports, subsea cable interconnection, Muskrat Falls hydro power delivery, and lower carbon emissions across Atlantic Canada.

 

Key Points

A 500 MW HVDC intertie linking Newfoundland and Nova Scotia to deliver Muskrat Falls hydro power.

✅ 500 MW capacity using twin 170 km subsea HVDC cables

✅ Interconnects Newfoundland and Nova Scotia to the North American grid

✅ Enables Muskrat Falls hydro imports, cutting CO2 and costs

 

For the first time, electricity has been sent between Newfoundland and Nova Scotia through the new Maritime Link.

The 500-megawatt transmission line — which connects Newfoundland to the North American energy grid for the first time and echoes projects like the New England Clean Power Link underway — was tested Friday.

"This changes not only the energy options for Newfoundland and Labrador but also for Nova Scotia and Atlantic Canada," said Rick Janega, the CEO of Emera Newfoundland and Labrador, which owns the link.

"It's an historic event in our eyes, one that transforms the electricity system in our region forever."

 

'On time and on budget'

It will eventually carry power from the Muskrat Falls hydro project in Labrador, where construction is running two years behind schedule and $4 billion over budget, a context in which the Manitoba Hydro line to Minnesota has also faced delay, to Nova Scotia consumers. It was supposed to start producing power later this year, but the new deadline is 2020 at the earliest.

The project includes two 170-kilometre subsea cables across the Cabot Strait between Cape Ray in southwestern Newfoundland and Point Aconi in Cape Breton.

The two cables, each the width of a two-litre pop bottle, can carry 250 megawatts of high voltage direct current, and rest on the ocean floor at depths up to 470 metres.

This reel of cable arrived in St. John's back in April aboard the Norwegian vessel Nexans Skagerrak, after the first power cable reached Nova Scotia earlier in the project. (Submitted by Emera NL)

The Maritime Link also includes almost 50 kilometres of overland transmission in Nova Scotia and more than 300 kilometres of overland transmission in Newfoundland, paralleling milestones on Site C transmission work in British Columbia.

The link won't go into commercial operation until January 1.

Janega said the $1.6-billion project is on time and on budget.

"We're very pleased to be in a position to be able to say that after seven years of working on this. It's quite an accomplishment," he said.

This Norwegian vessel was used to transport the 5,500 tonne subsea cable. (Submitted by Emera NL)

Once in service, the link will improve electrical interconnections between the Atlantic provinces, aligning with climate adaptation guidance for Canadian utilities.

"For Nova Scotia it will allow it to achieve its 40 per cent renewable energy target in 2020. For Newfoundland it will allow them to shut off the Holyrood generating station, in fact using the Maritime Link in advance of the balance of the project coming into service," Janega said.

Karen Hutt, president and CEO of Nova Scotia Power, which is owned by Emera Inc., calls it a great day for Nova Scotia.

"When it goes into operation in January, the Maritime Link will benefit Nova Scotia Power customers by creating a more stable and secure system, helping reduce carbon emissions, and enabling NSP to purchase power from new sources," Hutt said in a statement.

 

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Ukraine's parliament backs amendments to electricity market law

Ukraine Electricity Market Price Caps empower the regulator, the National Commission, to set marginal prices on day-ahead, intraday, and balancing markets, stabilize competition, support thermal plants, and sustain the heating season via green tariff obligations.

 

Key Points

Regulatory limits set by the National Commission to curb price spikes, ensure competition, and secure heat supply.

✅ Sets marginal prices for day-ahead, intraday, balancing markets

✅ Mitigates collusion risks; promotes effective competition

✅ Ensures TPP operation and heat supply during heating season

 

The Verkhovna Rada, Ukraine's parliament, has adopted at first reading a draft law that proposes giving the National Commission for State Regulation of Energy and Public Utilities the right to set marginal prices in the electricity market, amid EU market revamp plans that aim to reshape pricing, until 2023.

A total of 259 MPs voted for the document at a parliament meeting on Tuesday, November 12, amid electricity import pressures that have tested the grid, according to an Ukrinform correspondent.

Bill No. 2233 introducing amendments to the law on the electricity market provides for the legislative regulation of the mechanism for fulfilling special obligations for the purchase of electricity at a "green" tariff, preventing the uncontrolled growth of electricity prices due to the lack of effective competition, including recent price-fixing allegations that have raised concerns, ensuring heat supply to consumers during the heating period by regulating the issue of the functioning of thermal power plants in the new electricity market.

It is proposed to introduce respective amendments to the law of Ukraine on the electricity market, alongside steps toward synchronization with ENTSO-E to enhance system stability.

In particular, the draft law gives the regulator the right for the period until July 1, 2023 to set marginal prices on the day-ahead market, the intraday market and the balancing market for each trade zone, reflecting similar EU fixed-price contract initiatives being discussed, and to decide on the obligation for producers to submit proposals (applications) for the sale of electricity on the day-ahead market.

Lawmakers think that the adoption of the bill and empowering the regulator to set marginal prices in the relevant segments of the electricity market will prevent, even as rolling back prices in Europe remains difficult for policymakers, "an uncontrolled increase in electricity prices due to the lack of effective competition or collusion between market players, as well as regulate the issue of the functioning of thermal power plants during the autumn and winter period, which is a necessary prerequisite for providing heat to consumers during the heating period."

The new model of the electricity market was launched on July 1 as the UK weighs decoupling gas and power prices to shield consumers, in accordance with the provisions of the law on the electricity market, adopted in 2017.

 

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Hydro One stock has too much political risk to recommend, Industrial Alliance says

Hydro One Avista merger faces regulatory scrutiny in Washington, Oregon, and Idaho, as political risk outweighs defensive utilities fundamentals like stable cash flow, rate base growth, EPS outlook, and a near 5% dividend yield.

 

Key Points

A planned Hydro One-Avista acquisition awaiting key state approvals amid elevated political and regulatory risk.

✅ Hold rating, $24 price target, 28.1% implied return

✅ EPS forecast: $1.27 in 2018; $1.38 in 2019

✅ Defensive utility: stable cash flow, 4-6% rate base growth

 

A seemingly positive development for Hydro One is overshadowed by ongoing political and regulatory risk, as seen after the CEO and board ouster, Industrial Alliance Securities analyst Jeremy Rosenfield says.

On October 4, staff from the Washington Utilities and Transportation Commission filed updated testimony in support of the merger of Hydro One and natural gas distributor Avista, which had previously received U.S. antitrust clearance from federal authorities.

The merger, which was announced in July of 2017 has received the green light from federal and key states, with Washington, Oregon and Idaho being exceptions, though the companies would later seek reconsideration from U.S. regulators in the process.

But Rosenfield says even though decisions from Oregon and Idaho are expected by December, there are still too many unknowns about Hydro One to recommend investors jump into the stock.

 

Hydro One stock defensive but risky

“We continue to view Hydro One as a fundamentally defensive investment, underpinned by (1) stable earnings and cash flows from its regulated utility businesses (2) healthy organic rate base and earning growth (4-6%/year through 2022) and (3) an attractive dividend (~5% yield, 70-80% target payout),” the analyst says. “In the meantime, and ahead of key regulatory approvals in the AVA transaction, we continue to see heightened political/regulatory risk as an overhand on the stock, outweighing Hydro One’s fundamentals in the near term.”

In a research update to clients today, Rosenfield maintained his “Hold” rating and one year price target of $24.00 on Hydro One, implying a return of 28.1 per cent at the time of publication.

Rosenfield thinks Hydro One will generate EPS of $1.27 per share in fiscal 2018, even though its Q2 profit plunged 23% as electricity revenue fell. He expects that number will improve to EPS of $1.38 a share the following year.

 

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California Public Utilities Commission sides with community energy program over SDG&E

CPUC Decision on San Diego Community Power directs SDG&E to use updated forecasts, stabilizing electricity rates for CCA customers and supporting clean energy in San Diego with accurate rate forecasting and reduced volatility.

 

Key Points

A CPUC ruling directing SDG&E to use updated forecasts to ensure accurate, stable CCA rates and limit volatility.

✅ Uses 2021 sales forecasts for rate setting

✅ Aims to prevent undercollection and bill spikes

✅ Levels changes across customer classes

 

The California Public Utilities Commission on Thursday sided with the soon-to-launch San Diego community energy program in a dispute it had with San Diego Gas & Electric.

San Diego Community Power — which will begin to purchase power for customers in San Diego, Chula Vista, La Mesa, Encinitas and Imperial Beach later this year — had complained to the commission that data SDG&E intended to use to calculate rates, including community choice exit fees that could make the new energy program less attractive to prospective customers.

SDG&E argued it was using numbers it was authorized to employ as part of a general rate case amid a potential rate structure revamp that is still being considered by the commission.

But in a 4-0 vote, the commission, or CPUC, sided with San Diego Community Power and directed SDG&E to use an updated forecast for energy sales.

"This was not an easy decision," said CPUC president Marybel Batjer at the meeting, held remotely due to COVID-19 restrictions. "In my mind, this outcome best accounts for the shifting realities ... in the San Diego area while minimizing the impact on ratepayers during these difficult financial times."

In filings to the commission, SDG&E predicted a rate decrease of 12.35 percent in the coming year. While that appears to be good news for customers, Californians still face soaring electricity prices statewide, Commissioner Martha Guzman Aceves said the data set SDG&E wanted to use would lead to an undercollection of $150 million to $260 million.

That would result in rates that would be "artificially low," Guzman Aceves said, and rates "would inevitably go up quite a bit after the undercollection was addressed."

San Diego Community Power, or SDCP, said the temporary reduction would make its rates less attractive than SDG&E's, especially amid SDG&E's minimum charge proposal affecting low-usage customers, just as it is about to begin serving customers. SDCP's board members wrote an open letter last month to the commission, accusing the utility of "willful manipulation of data."

Working with an administrative law judge at the CPUC, Guzman Aceves authored a proposal requiring SDG&E to use numbers based on 2021 forecasts, as regulators simultaneously weigh whether the state needs more power plants to ensure reliability. The utility argued that could result in an increase of "roughly 40 percent" for medium and large commercial and industrial customers this year.

To help reduce potential volatility, Guzman Aceves, SDCP and other community energy supporters called for using a formula that would average out changes in rates across customer classes amid debates over income-based utility charges statewide. That's what the commissioners OK'd Thursday.

"It is essential that customer commodity rates be as accurate as we can possibly get them to avoid undercollections," said Commissioner Genevieve Shiroma.

San Diego Community Power is one of 23 community choice aggregation, or CCA, energy programs that have launched in California in the past decade.

CCAs compete with traditional power companies amid California's evolving power competition landscape, in one important role — purchasing power for a given community. They were created to boost the use of cleaner energy sources, such as wind and solar, at rates equal to or lower than investor-owned utilities.

However, CCAs do not replace utilities because the incumbent power companies still perform all of the tasks outside of power purchasing, such as transmission and distribution of energy and customer billing.

When a CCA is formed, California rules stipulate the utility customers in that area are automatically enrolled in the CCA. If customers prefer to stay with their previous power company, they can opt out of joining the CCA.

The shift of customers from SDG&E to San Diego Community Power is expected to be large. The total number of accounts for SDCP is expected to be 770,000, which would make it the second-largest CCA in the state. That's why SDCP considered Thursday's CPUC decision to be so important.

"At a time when customers are choosing between sticking with San Diego Gas & Electric and migrating to a CCA, we want them to have accurate bill information," said Commissioner Clifford Rechtschaffen.

"SDCP is very happy with today's CPUC decision, and that the commissioners shared our goal of limiting rate volatility for businesses and families in the region," said SDCP interim CEO Bill Carnahan. "This is definitely a win for accurate rate forecasting, and our mutual customers, and we look forward to working with SDG&E on next steps."

In an email, SDG&E spokeswoman Helen Gao said, "We are committed to continuing to work collaboratively with local Community Choice Aggregation programs to support their successful launch in 2021 and ensure that our mutual customers receive excellent customer service."

San Diego Community Power's case before the CPUC was joined by the California Community Choice Association, a trade group advocating for CCAs, and the Clean Energy Alliance — the North County-based CCA representing Del Mar, Solana Beach and Carlsbad that is scheduled to launch this summer.

SDCP will begin its rollout this year, folding in about 71,000 municipal, commercial and industrial accounts. The bulk of its roughly 700,000 residential accounts is expected to come in January 2022.

 

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Metering Pilot projects may be good example for Ontario utilities

Ontario Electricity Pricing Pilot Projects explore alternative rates beyond time-of-use, with LDCs and the Ontario Energy Board testing dynamic pricing, demand management, smart-meter billing, and residential customer choice to enhance service and energy efficiency.

 

Key Points

Ontario LDC trials testing alternatives to time-of-use rates to improve billing, demand response, and efficiency.

✅ Data shared across LDCs and Ontario Energy Board provincewide

✅ Tests dynamic pricing, peak/off-peak plans, demand management

✅ Insights to enhance customer choice, bills, and energy savings

 

The results from three electricity pilot projects being offered in southern Ontario will be valuable to utility companies across the province.

Ontario Energy Minister Glenn Thibeault was in Barrie on Tuesday to announce the pilot projects, which will explore alternative pricing plans for electricity customers from three different utility companies, informed by the electricity cost allocation framework guiding rate design.

"Everyone in the industry is watching to see how the pilots deliver.", said Wendy Watson, director of communications for Greater Sudbury Utilities.

"The data will be shared will all the LDCs [local distribution companies] in the province, and probably beyond...because the industry tends to share that kind of information."

Most electricity customers in the province are billed using time-of-use rates, including options like the ultra-low overnight rates that lower costs during off-peak periods, where the cost of electricity varies depending on demand.

The Ontario Energy Board said in a media release that the projects will give residential customers more choice in how much they pay for electricity at different times, reflecting changes for Ontario electricity consumers that expand plan options.

Pilot projects can help improve service

Watson says these kinds of projects give LDCs the chance to experiment and explore new ways of delivering their service, including demand-response initiatives like the Peak Perks program that encourage conservation.

"Any pilot project is a great way to see if in practice if the theory proves out, so I think it's great that the province is supporting these LDCs," she says.

GSU recently completed its own pilot project, the Home Energy Assessment and Retrofit (HEAR) program, which focused on customers who use electric baseboards to heat their homes, amid broader provincial support for electric bills to ease costs."We installed some measures, like programmable thermostats and a few other pieces of equipment into their house," Watson says. "We also made some recommendations about other things that they could do to make their homes more energy efficient."

At the end of the program, GSU provided customers with a report so that they could the see the overall impact on their energy consumption.

Watson says a report on the results of the HEAR program will be released in the near future, for other LDCs interested in new ways to improve their service.

"We think it's incumbent on every LDC...to see what ideas that they can come up with and get approved so they can best serve their customers."

 

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