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August 12, 2024

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Entergy Regulators Mount Challenge to MISO South Cost Allocation

State regulators from MISO South have publicly opposed a “postage stamp” cost allocation design, potentially setting the stage for a showdown between them and RTO planners preparing a third portfolio of long-range transmission projects.

The Entergy Regional State Committee (E-RSC) on June 30 adopted a resolution denouncing any use of postage stamp rates — in which costs are allocated across an entire footprint based on transmission customers’ load-ratio shares — to pay for the third of four iterations of MISO’s long-range transmission planning (LRTP).

Last month, MISO suggested eschewing a total subregional postage stamp design in favor of a half-subregional, half-zonal cost-sharing plan as it prepares to assemble a third LRTP portfolio that concentrates for the first time on the MISO South region. (See MISO Suggests Changing Cost Allocation for South Projects.)

But the E-RSC — which comprises the public utility commissions of Texas, Arkansas, Mississippi and Louisiana, as well as the New Orleans City Council, each of which regulates entities in one of the five cost allocation zones in MISO South — said any use of a postage stamp allocation is unacceptable. It called for “cost-causation and beneficiary-pays principles” and said parties who “receive negligible or negative benefits” should not owe anything.

For the third cycle of LRTP, “not all retail jurisdictions and loads are likely to be equal cost causers and beneficiaries,” the E-RSC said. A postage stamp design will “not align LRTP-related costs with the expected beneficiaries.” MISO should consider assigning costs to interconnecting generators that will benefit from LRTP lines through reduced network upgrade costs, it said.

The resolution called upon MISO to develop an allocation that metes out costs “based only on accurate, objective, measurable, quantifiable, non-duplicative, forward-looking and replicable metrics that are supported by data” to protect consumers. MISO’s design should be shaped by benefit ideas from MISO South regulators and stakeholders, and each LRTP project should be able to pass a benefit-cost analysis on a stand-alone basis, as opposed to sizing up benefits from a portfolio perspective, it said.

MISO did not say whether the E-RSC’s resolution will influence its cost allocation proposal. Via spokesperson Brandon Morris, the RTO said it appreciates the E-RSC’s feedback and is reviewing its resolution.

“We are committed to working with our stakeholders to develop a cost allocation solution for tranche 3 that balances the different needs of our subregions,” Morris said in a statement to RTO Insider.

In May, leadership of the Organization of MISO States said the RTO’s allocation proposal for its South subregion sparked several questions and a need to understand MISO’s end goal. State regulatory staffs said it was unclear whether the 50/50 allocation will completely replace MISO’s subregional postage stamp rate going forward and whether the RTO is planning to use the design on the fourth LRTP portfolio.

At the time, multiple representatives from MISO state regulatory bodies also said they remain interested in adding a generator-pays component to LRTP cost allocation.

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Moniz Calls for ‘Substantial Effort’ on Bioenergy with Carbon Capture

To achieve its net-zero targets by 2050, the United States will need a major deployment of bioenergy paired with carbon capture and storage (BECCS), with a goal of sequestering 500 million metric tons (MMT) of carbon dioxide per year, according to a new report from the Energy Futures Initiative (EFI).

Ethanol from corn and biodiesel from cooking oil are the most common forms of bioenergy, but the report sees wider options for feedstock, such as agricultural waste or trees and underbrush culled for forestry management. It also stakes out a claim for BECCS as a carbon-negative technology, taking more carbon out of the atmosphere than it emits, which could “counterbalance residual emissions from difficult-to-decarbonize sectors of the economy.”

“We know there are voices that would prefer other pathways toward very deep decarbonization,” said Ernest Moniz, former U.S. secretary of energy and EFI’s CEO. “But the reality is ― in our view, has been consistently ― that we need all [technologies] because the fight … for every damn tenth of a degree is really important.”

Speaking at a recent launch event for the report, Moniz cited figures from the United Nations International Panel on Climate Change, projecting that carbon dioxide removal technologies will need to cut global emissions by 6 gigatons per year by midcentury to keep climate change to 1.5 or 2 degrees Celsius. About half of that total could come from BECCS, Moniz said.

“And to put that in context, that 6 gigatons … is larger than the total U.S. emissions today of carbon dioxide,” he said. “So, this is not for the faint of heart. We’re going to need a very, very substantial effort.”

A gigaton is one billion tons, and the most recent figures from the Environmental Protection Agency, for 2021, peg U.S. CO2 emissions at 5.58 MMT.

The EFI report outlines what that substantial effort might look like, from setting ambitious goals, to expanding sources of biomass, to enacting supportive federal policies, such as tax incentives and changes to the Farm Bill now being debated in Congress. Last amended and reauthorized in 2018, the Farm Bill is updated every five years.

EFI recommends the 2023 update include increased funding for BECCS research and the inclusion of BECCS in existing programs, such as the Advanced Biofuels Payment Program, which provides financial support for biofuels not based on corn.

The report also sees a major opportunity to increase BECCS feedstocks through forest management, harvesting fast-growing trees and other plants that can result in “overstocked” forestlands and increased risk of wildfires. Citing a study from Yale University and the University of California, Berkeley, the report estimates “that between 265 million and 1 billion bone-dry tons (BDT) of biomass overstock are in wildfire prone counties in five Western states alone (California, Idaho, Nevada, Oregon and Washington).”

A bone-dry ton is a measure of wood with zero moisture content.

“BECCS creates a value proposition for more active forest wildfire management by providing a market for this overstocked biomass,” the report says. Job creation and economic development for rural communities would be another strong selling point, the report says.

But federal regulations strictly limit the use of forest biomass harvested from federal lands for biofuel production, the report says. For example, biofuels made from biomass harvested from federal forests do not qualify for EPA’s Renewable Fuel Standard. The EFI report recommends that exclusion be lifted.

Neutral or Negative?

With the world’s hottest days on record grabbing headlines, Moniz’s call for all-of-the-above climate action is timely and undeniable, but like carbon capture itself, BECCS raises skepticism and a lot of questions among environment groups.

EFI’s basic argument for BECCS begins with its claim that bioenergy is essentially carbon neutral — that is, the CO2 naturally sequestered in wood or other organic matter via photosynthesis offsets the carbon emitted when that feedstock is burned or otherwise processed to produce biofuels or other energy. Storing those emissions underground or sequestering them by other means makes them, at least potentially, carbon negative, said Joseph S. Hezir, EFI’s executive vice president.

“Depending on where you want to start the cycle, you could either have the carbon intake up front and then release [it] later or the release now and then capture or recapture later,” Hezir said in an interview with NetZero Insider.

EFI also notes that biomass already is the largest source of renewable energy in the U.S., based on figures from the International Energy Agency (IEA), which include its use in ethanol and other biofuels. Biomass is more widely used for heat and power generation in Europe, but it accounts for only 1.3% of power generation in the U.S, according to the U.S. Energy Information Administration.

An analysis from the National Resources Defense Council (NRDC) disputes the carbon neutrality of bioenergy, arguing such calculations leave out emissions associated with the full supply chain of procuring and transporting biomass.

“Far from being carbon negative, the lifecycle of this approach to BECCS generates about 80% as much carbon as comes out of a coal plant smokestack per megawatt-hour. This is because a large fraction of the total emissions occur off-site,” according to an NRDC issue brief.

Echoing NRDC, a Sierra Club analysis says, “The process of vegetation capturing CO2 from the atmosphere is carbon negative. Transporting those plants and refining, capturing and storing CO2 is not. For BECCS to be carbon negative, all of the above would have to be done with renewable energy.”

NRDC also raises concerns that widespread deployment of BECCS “would tax global ecological limits, threaten public health and cost a fortune.”

Food vs. Fuel

The EFI report acknowledges the carbon accounting, land use and economic obstacles BECCS will have to overcome and calls for “responsible” development of the technology.

One of the report’s key priorities is the development of “science-based, transparent guidelines for estimating … [greenhouse gas] emissions contributions from BECCS,” while also noting the challenges of building consensus and confidence for such guidelines. For example, given the wide range of bioenergy feedstocks, developing science-based carbon accounting will be complicated, Hezir said.

Tracking CO2 emissions is “different for crops than it is for forestry,” he said. “Forestry is … particularly challenging because forests sometimes are managed at a very macro level, where you might be planting in one area and harvesting in another, and then the question is how [do] you look at that whole landscape?”

Similarly, carbon accounting for agriculture will have to take into account fertilizers, irrigation and harvesting, Hezir said.

Roger Ballentine, president of Green Strategies, an industry consultant, said carbon accounting for BECCS should look at what the technology delivers “on a systemic basis,” rather than using a lifecycle analysis of individual BECCS facilities or feedstocks.

“What’s the decarbonization impact of providing [different] funding streams?” Ballentine said during a panel at the launch event. “You have energy production. You have carbon dioxide removal. You may have wildfire mitigation and waste management. So how do these opportunities and some of the challenges … compare to other pathways, especially carbon dioxide removal?”

The land use issue is another major challenge, pitting food production against “energy crops” used for fuel, said Virginia H. Dale, a corporate fellow at Oak Ridge National Laboratory. But, she said, “The U.S. has a large amount of nonfood crops, waste and forest residues that can provide biomass for this expanded BECCS deployment. … More than 300 million tons of biomass are readily available from currently unused agriculture and forestry waste, as well as including municipal waste. …

“We need to recognize that food and bioenergy … don’t need to compete for land. They could be integrated together to provide an appropriate resource for both of these if managed collectively. One thing we can do is develop flex crops, that is … resources that can be used for fuels as well as food, so that when there’s a food need, they can be adapted to that.”

Compared to direct air capture technologies, the economics of BECCS also requires a systemic approach that includes its potential to provide firm, dispatchable power to the electric power grid, said Sasha Mackler, executive director of the Energy Program at the Bipartisan Policy Center.

Direct air capture’s business model is simpler, he said. “You need to have a technology system that can effectively and efficiently capture carbon. We really have one product you’re selling: carbon removal.”

Widespread deployment of BECCS will require monetizing multiple value streams, such as power production, carbon removal and forest management for wildfire prevention, which will in turn depend on figuring out the carbon accounting, Mackler said.

“For product developers to actually get to the work of building out this business, they need to have clarity on what they’re able to monetize,” he said.

Ballentine also noted that the Inflation Reduction Act’s generous tax credits for carbon capture — up to $180/ton for direct air capture — do not specifically incentivize carbon-negative technologies. Further, he said, expanding biomass supply “doesn’t do you any good if there’s not demand.”

Will There be Demand?

Besides monetization, applications that build demand for BECCS could be the biggest roadblock to widespread deployment.

While supporting carbon removal technologies in general, the IEA cautions they should not be used as “an alternative to cutting emissions or an excuse for delayed action. But they can be part of the portfolio of technologies and measures needed in a comprehensive response to climate change.”

Hezir sees near-term applications for biofuels like renewable natural gas and sustainable aviation fuels, both areas where emerging demand exists among well-established industries, in this case, utilities and airlines. For example, the Renewable Natural Gas Coalition, an industry trade group, counts major utilities such as Consolidated Edison, National Grid, Dominion Energy, and Pacific Gas and Electric among its members.

Longer term, the EFI report sees much potential for BECCS, but also uncertainties that will require new policies and investments. “We’re now at a stage where we actually need to deploy more pilot projects, collect data and get more learning,” Hezir said. “Then use that to grow the industry.”

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Court Sends DOE Back to the Drawing Board on Boiler Efficiency Rule

A three-judge panel on the D.C. Circuit Court of Appeals on Friday vacated the U.S. Department of Energy’s proposed efficiency rule on commercial package boilers because of its failure to follow the Administrative Procedure Act (APA).

Such boilers are used to heat commercial and institutional buildings including schools, hotels, office and apartment buildings and hospitals. DOE estimated it would have saved 27 trillion BTU and $2 billion in customer spending, and cut carbon emissions by 16 million metric tons.

The American Public Gas Association and American Gas Association, which both represent natural gas utilities, and gas utility Spire had challenged the rule when it was proposed in 2020, and the court remanded it to DOE in 2022. The groups had challenged the department’s data and assumptions that it used to justify the more stringent standards.

When DOE issued a new rule last year, the groups argued that the department did not properly notice it and allow for comment, violations of the APA.

DOE has to periodically update efficiency standards for such equipment, with the law requiring it to at least adopt standards developed by the American Society of Heating, Refrigerating and Air-Conditioning Engineers (ASHRAE), which is a private professional association that writes standards and guidelines for the industry. If warranted, DOE can approve more stringent rules, and if ASHRAE fails to update them for six years, then it can update them on its own.

But even under the six-year rule, DOE must have clear and convincing evidence that its standard will result in significant conservation of energy, is technologically feasible and economically justified. The case stems from DOE’s use of that part of the law.

ASHRAE has not updated the standards since 2008, and DOE worked on its proposal for several years before publishing an initial final rule in 2020, which required more efficient boilers.

The initial rule was based on modeling from DOE in which it assigned random boilers to buildings. The petitioners argued that purchasers would make more rational decisions to choose the most effective boilers for their sites. They also questioned the natural gas prices that DOE used.

The court agreed, finding that DOE failed to provide a reasoned response to such arguments.

The gas groups said that DOE’s second attempt also failed to adequately explain its reasoning and that they were denied the opportunity to comment on the proposal as required in the APA. The court again agreed, as the rule on remand relied on new studies and documentation, which made it subject to comments under the APA.

DOE supported its use of random assignment with a more detailed explanation of market failures and behavioral biases that it said leads to irrational investments such as less efficient boilers. It also cited data showing boilers of varying efficiency levels are used in a variety of building types.

The department claimed that it did not need to put the rule on remand up for comment because the new data just advanced a hypothesis and provided some supporting explanation. That new data, however, did not address deficiencies in the pre-existing data, the court said, and were entirely new and critical to the department’s determination of life-cycle costs.

Petitioners on such APA issues do not face a high burden, so those objecting to an agency’s late reference to critical documents can show “prejudice” by claiming uncertainty as to whether their comments might have changed the outcome, the court ruled.

The petitioners also raised an issue with energy prices that DOE used from the Energy Information Administration, but the court sided with DOE there, saying the new rule provided a sufficient response to their concerns.

The department argued that the rule should not be vacated because it went into effect early this year and some manufacturers have started following it.

“However, none of the DOE’s arguments demonstrate that ‘the egg has been scrambled and there is no apparent way to restore the status quo ante,’ namely the state of affairs under the prior, less stringent standards,” the court said, quoting a case in which it found that the Department of Agriculture had violated the APA but declined to vacate the department’s action.

Vacating the rule would let manufacturers produce the more efficient boilers, along with those that comply with the pre-existing efficiency standard, the gas utilities argued.

The court found that because DOE failed to comply with the initial remand order, it made sense to vacate the rule. DOE will have to conduct additional proceedings to deal with the court’s concerns if it wants to implement a new standard, it ruled.

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Report: Planned OSW Fisheries Impact Studies Fall Short

Fisheries studies proposed by developers of the first wave of U.S. offshore wind projects would not fully replace federal monitoring that will be hindered by the wind farms, federal scientists report.

A recent article by three National Marine Fisheries Service (NMFS) scientists follows other reports citing scarce data about the impacts of wind power development off the U.S. coast.

The U.S. Bureau of Ocean Energy Management (BOEM), in its environmental assessments of individual wind farm proposals, has said some impact on nearby fisheries is likely as the facilities are built and operated, and that a collective impact is likely from the numerous wind farms planned along the New England and mid-Atlantic coasts.

This potential effect extends beyond target species to the rest of the ocean ecosystem, with a resulting effect of unknown severity on the people who harvest seafood. The fishing industry has been among the most vocal critics of the efforts by state and federal leaders to build an offshore wind power sector.

President Biden has set a goal of 30 GW by 2030. That is 29.958 GW more than is online today, but momentum is growing: Foundations are being placed in the water this summer for the first two utility-scale projects, which will provide a combined 935 MW to Massachusetts and New York. And BOEM on July 3 greenlighted the third project, which will supply 1.1 GW to New Jersey.

By 2025, BOEM expects to review at least 16 construction and operations plans for projects with a combined capacity of more than 27 GW.

Development is envisioned along most of the U.S. coastline, eventually, but initial efforts are focused on the Outer Continental Shelf from North Carolina to Maine, where more than two dozen projects are in some stage of development.

They would occupy more than 2.3 million acres of what NMFS calls one of the most productive fishing grounds in the world.

NMFS also considers those fishing grounds to be one of the best-understood marine ecosystems in the world, thanks to data gathered by hundreds of scientists and thousands of fishers over the past 60 years, at a cost of hundreds of millions of dollars.

And that’s where the scientists see problems arising.

Survey Says

During its environmental review, BOEM and NMFS in 2021 determined Vineyard Wind 1 would have major adverse impacts on fisheries surveys and agreed to develop a program to mitigate those impacts.

In December 2022, the two agencies released a strategy for doing this, but said it would be too late to implement that strategy in lease areas already in development off the coast from Massachusetts to New Jersey.

However, they said, the strategy would be useful in Northeast waters not yet leased. Also, the general framework, goals and objectives of the strategy could inform mitigation efforts in other regions of the country, even if specific actions would vary by region.

The issue is not academic: NMFS is steward of the nation’s marine resources, and in the face of scientific uncertainty, it generally takes a precautionary approach, such as lowering fishing quotas.

NMFS has tried to avoid this through extensive efforts to maintain year-to-year consistency in surveys begun anywhere from 1961 to 1998. It considers this especially important in the face of climate change, which is blamed for multiple impacts on marine ecosystems.

Dozens or hundreds of towering wind turbines spaced a nautical mile apart in a grid pattern across a wide area would create the inconsistency of data that NMFS tries to avoid.

They would hamper the use of surface vessels, aircraft and other platforms to perform surveys; they would affect the statistical design of surveys; and they would alter the characteristics of the ocean surface, the airspace above, the water below and the sea floor.

Plans Fall Short

More recently, three scientists at the NMFS Northeast Fisheries Science Center in Rhode Island and Massachusetts wrote that the surveys proposed by offshore wind developers would not serve to fill the data gaps that the wind farms are expected to create in 14 different surveys ranging from towed plankton recordings to sea scallop dredging to aerial seal counts.

NMFS did not specify when the paper was completed, but it is more recent than the strategy issued in December. It was published Thursday on the science platform Frontiers.

The authors identified 67 monitoring studies created by developers of nine offshore wind projects from Virginia to Massachusetts and found multiple shortcomings with them, including:

    • The majority offer no indication that quality-checked raw data will be shared or accessible.
    • None state that supplementing or calibrating to existing NMFS surveys is an objective.
    • All lack specificity about technique.
    • None include nighttime sampling.
    • All intend to address habitat change or biological response to wind development, but their design — such as a too-short baseline study duration — reduces the likelihood the studies will succeed in this.
    • Only two of the 67 plans — both involving drop-camera studies — have the potential to provide a sample that is functionally equivalent to the comparable NMFS study.
    • Most species-specific surveys would focus within an individual project area, and therefore not provide regional data comparable to NMFS surveys.

The authors conclude with a blunt assessment: “Project-level monitoring for offshore wind projects as currently designed for the [Northeast U.S. Continental Shelf] ecosystem will not yield information that can be integrated into NOAA Fisheries scientific survey time series, nor are they designed with that intention. Therefore, they cannot help to mitigate scientific survey impacts from offshore wind development.”

As a result: “The development of offshore wind will disrupt the collection of data for every NOAA Fisheries survey and will thus create spatial and temporal gaps in every data set it collects.”

Knowledge Gaps

Emissions-free offshore wind is being pursued as a climate-friendly alternative to fossil-fired power generation. But its effects are not fully understood.

Whales get a lot of attention, but for every whale that might be harmed or disoriented during construction of a wind farm, thousands of fish might avoid the local area, changing the local ecosystem, altering predator-prey dynamics and affecting commercial or recreational fishing operations.

When construction is complete, the dozens of tower foundations would provide a favorable underwater habitat for multiple species; would preclude use of certain commercial fishing equipment; and might make for better sport fishing opportunities.

BOEM and the Northeast Fisheries Science Center collaborated with a frequent adversary — the fishing industry group Responsible Offshore Development Alliance — to create a report earlier this year laying out what is known and not known about the interaction of offshore wind power with the fisheries.

In fact, one of the authors told NetZero Insider that the report apparently was the first to bring together in one place the body of knowledge, and lack of knowledge, about the ecological effects of offshore wind. (See Report Flags Gaps in Knowledge of OSW Effects.)

Because of the scarcity of data, the report made no predictions on fisheries impact. The authors also noted the window has closed to establish some of the baseline data.

Other nations have been developing offshore wind for much longer than the United States, but there, too, knowledge gaps persist. The International Council for Exploration of the Sea is working to better understand the interaction of fisheries and wind farms.

BOEM is the lead federal agency on U.S. offshore wind development. The National Marine Fisheries Service, informally known as NOAA Fisheries, is part of the National Ocean and Atmospheric Administration, which has a consulting role in the development of offshore wind.

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Counterflow: Competition Versus Monopoly

Steve Huntoon | Steve Huntoon

One would have thought this answered many times over the last 25 years. Most recently with the poster child of the Vogtle nuclear plant in Georgia that is seven years late and a mere $16 billion over budget.[1] And with regulatory capture resulting in regulated equity returns greatly exceeding the true cost of equity.[2] But every so often the utility monopolies manage to get the opposite proposition back on the public policy radar screen.

So it was with a New York Times story in January this year claiming that 35 states that deregulated some or all of their electric system tend to have higher rates than the other 15 states.[3] Where to begin?

What Matters

The sea change over the last 25 years has been the introduction of competition in the generation of electricity in some states — this is where the big money is and what warrants study. This should not be confused with the introduction of retail competition in some states — retail prices largely reflect generation (supply) prices. Or whether a state’s utilities are in an RTO — largely irrelevant to whether generation remains a monopoly. Or whether competition in transmission is a good thing — which, by the way, I have argued ad nauseum is yes.[4]

Reporting by RTO Insider revealed that the Times story relied on an analysis that defined as “deregulated” all states with utilities in RTOs — regardless of whether the utilities still had monopolies to supply customers with their rate-regulated generation.[5] This is, for example, generally the case with the states/utilities in SPP and MISO. So the Times story was way off base at the get-go.

The Energy Institute Rebuttal

Two weeks after the Times story came out professor James Bushnell at Berkeley’s Energy Institute posted a crushing rebuttal with these four insights:[6]

    1. Deregulation is best defined as the “the degree to which generation is compensated by market-based prices rather than cost-based regulation,” a proposition Bushnell and Berkley professor Severin Borenstein established in 2015.[7] A cogent statement of what I suggested above.
    2. Retail prices in states that deregulated generation were already very high. As Bushnell says, “That’s a big part of why they deregulated!” So the measure of success isn’t whether deregulated states’ rates are still higher than other states, it’s whether their rates are lower than they would have been if they hadn’t deregulated. This is a subject I will return to below.
    3. Prices in deregulated markets more closely follow the marginal cost of fuel, typically natural gas, so those prices are more volatile. When gas is expensive, deregulation can look bad. When gas is cheap, deregulation can look good. So when you measure makes a difference.
    4. Generation is at most half the retail price of electricity. California has adopted policies dramatically increasing retail prices, as I’ve discussed in past columns.[8] When Bushnell removed California from the “deregulated” group because of these policies, the data shows that the difference in price between the deregulated states and the regulated states has decreased over the years. As Bushnell says, “The gap between those two groups, in real terms, is now about half of what it was in 1998.” In this graphic it’s the bottom line (no pun intended) that matters.

Competition works!

Wait, There’s More

I could stop here, and rest the case on Bushnell’s insights and data. But I think there is another way to look at available data, based on the experience of the 13 PJM states.

We can divide the 13 PJM states into generation-deregulated states and generation-regulated states. For that I’ll adopt the Energy Institute’s division from a 2015 paper by Borenstein and Bushnell.[9] Deregulated states are Delaware, Illinois, Maryland, New Jersey, Ohio and Pennsylvania. Regulated states are Indiana, Kentucky, Michigan, North Carolina, Tennessee, Virginia and West Virginia.

According to EIA data,[10] the average retail price in the deregulated PJM states was 7.42 cents/kWh in 2001 and 10.98 cents/kWh in 2021, an increase of 3.56 cents/kWh or 48%. The average retail price in the regulated PJM states was 5.71 cents/kWh in 2001 and 9.93 cents/kWh in 2021, an increase of 4.22 cents/kWh or 74%. So the absolute price increase in the deregulated states, 3.56 cents/kWh versus 4.22 cents/kWh is less, and the relative price increase in the deregulated states, 48% versus 74%, is much less.

Is this proof positive that competition works? No. There are many factors and plenty of ways to slice and dice data. To paraphrase Ronald Coase, if you torture the data long enough it will confess to anything.[11] But it is one more data set that supports competition over monopoly.

And Relative Carbon Emissions

I’ve discussed before how generation competition in PJM has dramatically decreased carbon emissions, largely by market-driven natural gas displacing coal.[12]

I took a look at whether this might show up in relative carbon emissions of the deregulated states versus regulated states. According to Energy Information Administration data, average carbon emissions in the deregulated states went from 1,423 pounds/MWh in 2003 (first year of reported data) to 851 pounds/MWh in 2021, a 40% reduction. Average carbon emissions in the regulated states went from 1,641 pounds/MWh in 2003 to 1,214 pounds/MWh in 2021, a 26% reduction. Again, lots of factors, but I think this shifts the burden to those who claim that competition isn’t good for the climate.

Key Takeaways

Deregulation/competition in generation works. And it’s good for the climate. Win, win.

Columnist Steve Huntoon, principal of Energy Counsel LLP, and a former president of the Energy Bar Association, has been practicing energy law for more than 30 years.

[1] https://www.bloomberg.com/graphics/2023-vogtle-nuclear-largest-clean-energy-plant-in-us/#xj4y7vzkg.

[2] https://energy-counsel.com/wp-content/uploads/2022/10/Nice-Work-If-You-Can-Get-It-Take-2.pdf; https://www.energy-counsel.com/docs/Nice-Work-If-You-Can-Get-It-Fortnightly-August-2016.pdf.

[3] https://www.nytimes.com/2023/01/04/business/energy-environment/electricity-deregulation-energy-markets.html.

[4] https://www.energy-counsel.com/docs/FERC-Order-1000-Need-More-of-Good-Thing.pdf; please see also https://www.energy-counsel.com/docs/waste-not-what-not.pdf.

[5] https://www.rtoinsider.com/31452-a-deregulation-debate-by-the-numbers/ (“In our interview, McCullough said the analysis he provided the Times wasn’t really a comparison of retail electricity prices in deregulated versus regulated states, but between states operating inside and outside of organized markets.”)

[6] https://energyathaas.wordpress.com/2023/01/17/more-breaking-news-california-electricity-prices-are-still-high/

[7] http://bushnell.ucdavis.edu/uploads/7/6/9/5/76951361/electricityindustry.pdf.

[8] https://energy-counsel.com/wp-content/uploads/2023/06/How-Many-Deaths.pdf; https://www.energy-counsel.com/docs/No-Carb-California.pdf.

[9] http://bushnell.ucdavis.edu/uploads/7/6/9/5/76951361/electricityindustry.pdf, footnote 16.

[10] For 2001, https://www.eia.gov/electricity/state/archive/062901.pdf.  For 2021, https://www.eia.gov/electricity/state/. If you email me at huntoon@comcast.net I’ll gladly send you my compilation of the underlying data (albeit in handwritten scribbles).

[11] https://en.wiktionary.org/wiki/if_you_torture_the_data_long_enough,_it_will_confess_to_anything;  https://quoteinvestigator.com/2021/01/18/confess/.

[12] https://www.energy-counsel.com/docs/we-see-through-a-glass-darkly.pdf; https://www.energy-counsel.com/docs/NRDC-Prescribes-More-Carbon-Emissions.pdf; https://www.energy-counsel.com/docs/Scary-wrong.pdf.

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Canadian Wildfires Trigger ISO-NE Capacity Deficiency

Forest fires in Québec forced the shutdown of a Hydro-Québec transmission line during New England’s peak-demand evening hours Wednesday, leading to a capacity deficiency and requiring ISO-NE to take emergency actions to balance the grid.

The event marks just the third capacity deficiency event in New England since 2016; the most recent prior incident was on Dec. 24, 2022. ISO-NE was able to draw on operating reserves to avoid major issues.

“The transmission outage occurring in the midst of the evening peak meant that sufficient resources were not able to respond quickly enough to avoid the capacity deficiency,” ISO-NE wrote in a press release, noting that the transmission issue coincided with higher-than-expected peak evening demand.

While calling on the region’s reserve resources, ISO-NE declared an Energy Emergency Alert Level 1, the lowest of the RTO’s three alert levels. These actions helped mitigate the capacity deficiency within a half-hour, and ISO-NE did not ask the public to reduce its energy consumption.

“In and of themselves, capacity deficiencies are not always emergencies,” ISO-NE said. “They simply mean that ISO operators are taking additional actions to maintain system reliability.”

A Hydro-Québec spokesperson told RTO Insider in a statement that the transmission outage was the result of forest fires in the Baie-James region of Québec, which caused a temporary shutdown of the company’s Phase-2 line.

“Heat and smoke can trigger automated system protection mechanisms, which will essentially shut down the power line in order to protect it,” Hydro-Québec said. “Our bulk transmission infrastructure has not suffered any damage as a result of the forest fires. We remain in constant communication with our ISO partners, providing as much visibility as we can on the current fire situation.”

The company also highlighted the link between the accelerating consequences of manmade climate change and the massive early season wildfires in Québec.

“While forest fires are not a new phenomenon, the intensity and increased frequency of these events in North America are the result of climate change,” Hydro-Québec said. “The amplitude of this event should serve as a clear reminder that we need to accelerate every effort towards transitioning away from the burning of fossils fuels for electricity generation.”

The wildfires already have broken Canada’s record for most area burned in a single year, and government officials expect above-average fire conditions to continue through July and August in many regions of the country.

Kristina Dahl, principal climate scientist for the Climate & Energy program at the Union of Concerned Scientists, said that while a large range of factors have contributed to the massive Canadian wildfires, climate change is a major driver.

“There’s a very clear connection between climate change and worsening wildfires,” Dahl said. She noted that climate change exacerbates wildfire risks by increasing temperatures and drying out ecosystems, as well as enabling tree-killing insects to survive the winter, which creates additional fuel for wildfires.

“It’s really alarming what’s happened in Canada so far this wildfire season,” Dahl added. “Wildfires have burned over 20 million acres of land; that’s roughly an area the size of the state of Maine.”

In early June, ISO-NE reported that wildfire smoke had led to reduced solar generation across the region. It emphasized the difficulty in forecasting demand amid the effects of this smoke because of the lack of historical data. (See RTOs Report Diminished Solar Output, Loads as Wildfire Smoke Passes.)

ISO-NE also recently released the preliminary results of its joint study with the Electric Power Research Institute about the grid reliability impacts of extreme weather, looking at the summer of 2027. While the study found no energy shortfall risk, it did not analyze the risks posed by wildfires to the grid.

“We did not directly consider wildfire risks, as the assessment was focused on resource adequacy risks where wildfires would not be expected to impact enough supply resources simultaneously in the region to be a primary hazard to consider for resource adequacy risk,” Daniel Brooks, EPRI vice president of integrated grid and energy systems, said in a statement to RTO Insider. “Wildfire risks might be a contributing factor potentially during extreme heat scenarios in the future. One area we could add for future versions would be the import capability with wildfire impacting transmission from neighboring regions such as Québec.”

Susan Muller, senior energy analyst for UCS, said the reliability issues experienced last week highlight the need to rapidly transition away from fossil fuels and to recognize the reliability attributes of nonemitting resources.

For clean energy sources, “you’re getting power, but you are also reducing the likelihood of extreme weather because you’re no longer adding carbon to the atmosphere,” Muller said.

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CARB, Manufacturers Partner to Support Clean Truck Rules

As a court battle heats up over California’s zero-emission truck regulations, a group of truck manufacturers on Thursday committed to follow the ZEV rules even if they’re overturned.

The commitment came through the Clean Truck Partnership, an agreement between leading truck manufacturers and the California Air Resources Board (CARB).

In exchange for their pledge to transition to zero-emission vehicles and meet tailpipe emission standards, CARB agreed to give manufacturers more compliance flexibility. The agency also promised to provide a minimum of four years’ lead time before imposing new requirements and at least three years of regulatory stability.

CARB Chair Liane Randolph called the agreement an “unprecedented collaboration.”

“This agreement makes it clear that we have shared goals to tackle pollution and climate change and to ensure the success of the truck owners and operators who provide critical services to California’s economy,” Randolph said in a statement.

The Clean Truck Partnership includes CARB and the Truck and Engine Manufacturers Association (EMA), along with the following manufacturers:

    • Cummins Inc.
    • Daimler Truck North America
    • Ford Motor Co.
    • General Motors Co.
    • Hino Motors Limited Inc.
    • Isuzu Technical Center of America Inc.
    • Navistar Inc.
    • Stellantis N.V.
    • Volvo Group North America

ACT Targeted

The federal Clean Air Act allows California to request an EPA waiver to enforce its own emission standards for new motor vehicles. EPA granted a waiver for CARB’s Advanced Clean Trucks regulation in March. (See Groundbreaking California Clean Truck Rules Win EPA Waiver.)

The regulation, which CARB adopted in 2020, requires truck manufacturers to sell an increasing percentage of zero-emission medium- and heavy-duty trucks in the state from 2024 through 2035. In addition, CARB adopted in April the Advanced Clean Fleets regulation, which will ban the sale of diesel trucks in the state starting in 2036. (See CARB Adopts Clean Fleets Rule Despite Broad Skepticism.)

Other states may adopt California’s regulations rather than use federal standards. States that have adopted California’s ACT regulation include Colorado, Massachusetts, New Jersey, New York, Oregon, Vermont and Washington.

Under the Clean Truck Partnership agreement, truck manufacturers committed to selling as many zero-emission trucks as reasonably possible in every state that has adopted ACT. Those efforts will be “irrespective of the outcome of any litigation that has been filed or may be filed challenging the waivers or authorizations for those regulations or CARB’s or any state’s overall authority to implement those regulations.”

The EMA and the truck makers also agreed to be neutral when states are considering the adoption of ACT. But the parties can still comment on implementation issues, according to terms of the agreement.

On CARB’s end of the agreement, agency staff will propose giving manufacturers three years, rather than one year, to make up deficits in meeting ZEV requirements. CARB also committed to holding a workshop this year to discuss the concept of pooling ZEV credits and deficits across ACT states.

Also this year, CARB will hold a workshop “to discuss the appropriate role of hydrogen-fueled internal combustion engines” in meeting ZEV requirements.

In addition to ACT, the agreement addresses CARB’s so-called omnibus rules, which regulate truck tailpipe emissions. CARB has agreed to align its rules with EPA’s 2027 regulations for nitrogen oxide emissions and modify some parts of its 2024 NOx emission regulations.

“This alignment between California and the Environmental Protection Agency’s national standards for model year 2027 and beyond will help us get more clean trucks on the road across the country,” Cynthia Williams, global director of sustainability, homologation and compliance at Ford Motor Co., said in a statement.

Court Battle Waged

Last month, a coalition of 19 states, led by Iowa Attorney General Brenna Bird, petitioned a federal appellate court to review EPA’s approval of CARB’s Advanced Clean Trucks regulation.

Groups including the Western States Trucking Association and the Construction Industry Air Quality Coalition filed similar petitions.

Bird said in a release that ACT forces truckers to buy electric vehicles and “regulates trucking out of existence” through zero-emission standards.

Last week, California officials announced they were leading their own multi-state coalition seeking to intervene in the ACT lawsuits. Joining California in the motion to intervene were Colorado, Connecticut, Delaware, Hawaii, Illinois, Maine, Maryland, Massachusetts, Minnesota, New Jersey, New York, North Carolina, Oregon, Pennsylvania, Rhode Island, Vermont and Washington, the District of Columbia, and the cities of Los Angeles and New York.

The Environmental Defense Fund and three other environmental organizations also filed a motion to intervene last week.

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California Invests in Zero-emission Port Equipment

California Gov. Gavin Newsom announced $1.5 billion in port infrastructure upgrades Thursday, including $450 million to fund zero-emission locomotives, vessels and vehicles at some of the West Coast’s largest shipping container ports.

“No other state has a supply chain as critical to the national and global economy as California,” Newsom said in a statement. “These investments — unprecedented in scope and scale — will modernize our ports, reduce pollution, eliminate bottlenecks and create a more dynamic distribution network.”

The money will finance 28 projects that together will create an estimated 20,000 jobs, the statement said.

“The historic level of state funding also puts these projects in a stronger position to compete for significant federal infrastructure dollars from the Biden-Harris administration,” California Transportation Secretary Toks Omishakin said during an event announcing the awards Thursday at the Port of Long Beach.

The ports of Long Beach and Los Angeles — among the three busiest container shipping ports in the U.S., according to maritime information website Marine Insight — are trying to convert to zero-emission operations in coming years.

As part of the grants, the Port of Long Beach was awarded more than $383 million to help modernize its freight transport system at the port and in surrounding communities, the California State Transportation Agency said in its summary of the projects.

The funding will pay for the development of a battery plug-in tugboat and up to 12 long-haul and switching zero-emission locomotives. It also will finance nine hydrogen fuel cell “top handlers” to stack and move freight containers and 44 pieces of zero-emission equipment to replace diesel tractors, forklifts and other heavy equipment, the agency said.

A $46 million grant to the Port of Stockton will fund a zero-emission electric railcar mover. And more than $15 million will help expand Sierra Northern Railway’s efforts to develop and demonstrate hydrogen-powered switching locomotives to serve the Port of West Sacramento.

The Port of Oakland, the largest container port in Northern California, will receive more than $103 million for its modernization efforts. The money will help pay for battery-electric tractor rigs and charging stations, hydrogen fuel cell top handlers and a battery storage system.

“We look forward to our continued partnership with Secretary Omishakin in building an Oakland seaport for the next generation that uses clean, zero-emissions energy like electricity and hydrogen,” Port of Oakland Executive Director Danny Wan said in a statement.

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GOP Senators Call for FERC Conferences on EPA Power Plant Rule

Two key Republican senators want FERC to play a more active, public role in evaluating the potential impacts of the power plant emissions rules EPA proposed in May. (See EPA Proposes New Emissions Standards for Power Plants.)

Energy and Natural Resources (ENR) Committee Ranking Member Sen. John Barrasso (R-Wyo.) and Environment and Public Works Committee Ranking Member Sen. Shelley Moore Capito (R-W.Va.) sent a letter to the commission Wednesday urging it to hold a series of technical conferences on the rule.

“The proposal presents unjustifiable claims about the future availability of technologies — including carbon capture, clean hydrogen and the related infrastructure — used to power our electric grids,” Barrasso and Capito wrote in the letter. “In light of recent testimony before Congress and the projected impact of the Proposed Clean Power Plan 2.0, we ask you to convene as soon as possible a series of technical conferences to assess the potential impact of the proposed rule on electric reliability.”

The Federal Power Act requires FERC to protect electric reliability through mandatory standards and Congress more generally looks to the commission to safeguard the quality of interstate electric and natural gas service, the two wrote.

The ENR Committee recently held a pair of hearings on FERC oversight and reliability. During one of them, the commission’s two Republicans warned of a pending reliability crisis. (See Senators Praise Phillips, FERC’s Output at Oversight Hearing.) Commissioner James Danly warned of “an impending, but avoidable, reliability crisis,” and Commissioner Mark Christie said the crisis would occur if the rapid subtraction of dispatchable resources continued unabated.

Chairman Willie Phillips told the committee he was concerned about the pace of power plant retirements and said the commission needed to keep an eye on it. Similar concerns were echoed by the heads of NERC and PJM at a later hearing. (See Robb Warns of ‘Serious Disruptions’ from Grid Transition.)

“These witnesses expressed the critical, consistent concern that the premature retirement of dispatchable generation is frequently driven by government actions, including rulemakings from the EPA,” the letter said. “The Proposed Clean Power Plan 2.0 appears to pose a significant threat to the remaining dispatchable fleet when the nation can afford it least.”

Back when the original Clean Power Plan was finalized in 2015, President Obama’s EPA worked with FERC and the commission held a series of technical conferences on the plan’s potential impact on reliability, which all included testimony from EPA leadership, the letter said.

The letter said that without a similar effort from FERC to a build a record, the commission’s consultations with EPA on the rule “are likely to be ineffective.”

“EPA clearly lacks the expertise to project accurately the impact of its rulemaking on electric reliability without deeply informed and engaged participation from FERC and those subject to its jurisdiction that are charged with the obligation to generate and deliver electricity in order to meet continuous demand for electric service,” Barrasso and Capito wrote.

Behind the Scenes

While the letter argues for more public coordination between the two agencies, former FERC Chair Richard Glick said in an interview that the two closely coordinated on areas that implicated each other’s jurisdictions.

“Behind the scenes, FERC and EPA have conversations often,” Glick said. “FERC often provides technical assistance to agencies like the EPA, for instance, if there’s a concern about a particular upcoming rulemaking that EPA is looking at and what that impact might be on the reliability of the grid.”

Those kinds of conversations happened when Glick was at the agency, and he expects they have continued, though he acknowledged not having inside information about what has occurred since he left. It is ultimately up to Phillips whether he wants to go the more formal route of technical conferences as requested by the two senators, Glick said.

Any information shared between the agencies behind the scenes is going to be part of the public record anyway, Glick said.

The senators’ letter also complained about EPA’s decision to grant a brief extension for its comment deadline to Aug. 8, when many parties, including key trade associations and the ISO/RTO Council, had asked for an extension into the fall.

An EPA spokesman said the agency would respond to all comments in its final rule when it is issued. In the proposed rule itself, the EPA said it would coordinate with FERC and mentioned it signed a memorandum with the Department of Energy this spring that included consultation with the commission, NERC and state regulators. (See: DOE, EPA Team Up on Reliability Efforts.)

Electric Power Supply Association CEO Todd Snitchler said in a statement that trade group would support public coordination between FERC and EPA on the rule’s potential impacts, of which the group has been critical since it was released.

“While we support and our members actively contribute to the expansion of cost-effective clean energy, EPSA remains deeply concerned about the potential impact of the EPA’s proposed rules on critical natural gas power plants needed to provide reliable electric supply,” Snitchler said.

No existing commercial power plants in the country are using carbon capture and sequestration and no current technologies can meet 24/7 demand that can be “deployed quickly, cost effectively and at scale to fill the gap left by existing resources likely to be put out of business by the EPA’s aggressive new restrictions,” he added.

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FERC Accepts NERC Budget Update

FERC on Monday completed a back-and-forth on NERC’s 2023 Business Plan and Budget that it began last November with an order accepting the ERO’s clarification of the commission’s questions (RR22-4-002).

The commission said it was satisfied with NERC’s compliance filing, which the ERO submitted in January in response to FERC’s order accepting the budget in November. (See FERC Orders Clarification in ERO Budget Filing.) FERC also accepted the 2023 business plans and budgets of the regional entities and the Western Interconnection Regional Advisory Board in the same filing.

FERC had ordered the compliance filing to clear up a number of questions, some initially raised by the Edison Electric Institute, about how the funds in the budget were to be used. The commission said its oversight duties would be best served by “additional transparency” into costs relating to the Electricity Information Sharing and Analysis Center’s (E-ISAC) operations — particularly how NERC’s new Business Technology Department relates to the E-ISAC — in addition to the program’s relationship with outside partners and vendors.

The commission also demanded information on NERC’s fixed asset costs and allocation of its loan proceeds, and the inclusion of natural gas companies in the E-ISAC and the Cybersecurity Risk Information Sharing Program (CRISP).

In its filing, NERC explained that the Business Technology Department supports all of the ERO, including the E-ISAC. The organization told the commission that in its budget, costs directly assigned to a particular department may be reflected as indirect costs in each department that it supports; for example, the 2023 E-ISAC budget includes fixed asset additions of $1.1 million, $258,000 of which are directly assigned to the E-ISAC and $928,000 of which are allocated as indirect expenses from the administrative departments.

Explaining the $4 million loan proceeds, which the budget said would be used for software investments, NERC said the funds were specifically for the Align and Secure Evidence Locker projects. The ERO said budgeting this financing activity in its General and Administrative line item was “consistent with NERC’s historical practice” regarding software financing but acknowledged the commission’s “concern” about the lack of clarity this creates regarding where funds finally are to be spent.

NERC said future budgets would “allocate the budgeted capital financing activity … using weighted percentages of departments’ capital software spending.”

Regarding the E-ISAC vendor affiliate program, NERC said the program’s tiered structure — under which vendors may pay more for additional benefits such as access to networking sessions at the GridSecCon security conference — allows vendors of smaller sizes and resources to access the program that otherwise might not be able to join. The ERO also outlined its screening process for the program and asserted that the E-ISAC reviews the materials of vendors who will participate in its events to ensure they do not contain sales or promotional content, another concern raised by FERC.

Finally, NERC explained that the E-ISAC’s collaboration with the Downstream Natural Gas Information Sharing and Analysis Center provides the E-ISAC’s members with “increased insights into threats affecting a sector that has many overlaps” with their business through the sharing of informational bulletins. The ERO also said natural gas utilities that participate in CRISP pay for their access the same as any other participants.