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November 8, 2024

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EPA Coal Ash Enforcement Impacts Midwest Coal Plants

The EPA’s Tuesday announcement that it will crack down on coal-ash ponds has an outsized impact on Midwestern coal plants.

The EPA proposed that three coal plants in the region stop dumping waste into unlined ash ponds and denied the facilities extensions of an April 2021 deadline to initiate the ponds’ closure. Affected plants include the Indiana Kentucky Electric Corp.’s 1.3-GW Clifty Creek Power Station in southern Indiana; American Electric Power’s 2.6-GW Gavin Power Plant in southern Ohio; and Interstate Power and Light’s 726-MW Ottumwa Generating Station in southeastern Iowa.

The agency opened a 30-day comment period on its proposed determinations. It also said East Kentucky Power Cooperative’s 1.3-GW H.L. Spurlock Power Station might receive an extension until Nov. 30, provided it fixes groundwater monitoring problems.

The EPA’s actions represent the Biden administration’s first steps to enforce coal-ash disposal regulations enacted in 2015. The EPA’s Coal Combustion Residuals Rule required most of the country’s 500 unlined ash pits to stop receiving waste and to begin closure activities by April 2021.

Coal ash contains toxic materials that can seep into groundwater, including mercury, cadmium and arsenic.

“I’ve seen firsthand how coal-ash contamination can hurt people and communities. Coal ash surface impoundments and landfills must operate and close in a manner that protects public health and the environment,” EPA Administrator Michael S. Regan said in a Tuesday press release. “For too long, communities already disproportionately impacted by high levels of pollution have been burdened by improper coal ash disposal.”

4 MISO Plants Deemed Incomplete

The EPA also said four coal plants in MISO’s footprint submitted incomplete applications to postpone the closures of their ash ponds.

The agency said Ameren Missouri’s 1-GW Meramec Energy Center in St. Louis and its 1-GW Sioux Energy Center in West Alton, Mo., submitted inadequate information in their extension requests. It also singled out the City of Springfield, Ill.-owned 200-MW Dallman Power Station and the Lansing Board of Water & Light’s Erickson Power Plant in central Michigan for unfinished applications.

Ameren plans to retire the Meramec’s coal-fired units by the end of 2022 and to wind down operations at the Sioux Energy Center sometime in 2028.

The Lansing Board of Water & Light has said it will retire its Erickson Power Plant by 2025. Springfield retired an aging unit at Dallman last year following storm damage.

The EPA said it will make more decisions on extension applications for ash ponds or pit closure dates in the coming months. It said it has 48 more eligible applications to review from facilities that want to keep dumping waste into their unlined ash ponds.

The agency also said Tuesday that it will begin contacting facilities with coal ash ponds that have insufficient cleanup information or have poor monitoring records.

“As the transition from coal advances, it is also critical that we responsibly manage the legacy wastes that have been left from our historical reliance on coal,” Liesl Clark, director of the Michigan Department of Environment, Great Lakes, and Energy, said in a statement. “We support EPA’s ongoing efforts to provide clarity around the coal combustion residuals rules and to ensure that our world-class freshwater resources and the drinking water they provide are not impacted by these legacy wastes.”

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Omicron Forces NERC to Retreat from Hybrid Board Format

Citing “continued concerns about traveling and the growth of the Omicron” variant of COVID-19, NERC Board of Trustees Chair Ken DeFontes confirmed Wednesday that February’s meetings of the board and Member Representatives Committee (MRC) will be held virtually, rather than partially in person as originally planned.

Speaking at the MRC’s informational webinar this week — intended to preview the agenda and topics of discussion for next month’s meetings — DeFontes acknowledged that the news would bring “significant disappointment” and leave attendees “frustrated.” But in light of the recent return to rapid spread of the coronavirus, the chair said the decision to keep the meetings online-only was “the prudent thing to do.”

The number of daily cases of COVID-19 reported to the Centers for Disease Control and Prevention has spiked in recent months beyond any previous high points in the ongoing pandemic. More than 1.4 million cases were reported on Monday, the highest single-day figure since the novel coronavirus was first reported in the U.S. nearly two years ago. As of the same day, the seven-day moving average stood at more than 750,000 cases, with a total death count of more than 837,000.

A major driver of the recent explosive growth is the Omicron variant, first identified in November 2021 and “exponentially increasing in multiple countries,” according to the CDC. Omicron possesses both “increased transmissibility and the ability to evade immunity conferred by past infection or vaccination,” the agency said last month, meaning that even those who are protected against the original coronavirus or the Delta variant that emerged last year are still vulnerable to the new strain.

“Concerns about lower vaccine efficacy because of new variants have changed our understanding of the COVID-19 endgame, disabusing the world of the notion that global vaccination is by itself adequate for controlling SARS-CoV-2 infection,” according to a study published last month in The Lancet.

The study emphasized that while there is some evidence that the effects of Omicron may be less severe to individuals than previous variants — particularly for fully vaccinated people who have received booster shots — the speed of transmission means that “existing public health prevention measures” such as masking, social distancing and avoiding enclosed indoor spaces will be necessary to control the spread of the virus and prevent the health care system from becoming overloaded.

No Word on Rest of 2022

NERC’s board and MRC have not met in person since Feb. 6, 2020, when they gathered in Manhattan Beach, Calif. (See NERC Board of Trustees Briefs: Feb. 6, 2020.) The organization curtailed all of its in-person gatherings, including technical committee and standard drafting team meetings, the following month, after many participating bodies enacted travel restrictions in light of the pandemic.

February’s meetings were to have been the first step of relaxing these constraints: At the November 2021 meeting, DeFontes said the plan was for the board and MRC to gather in person at NERC’s Atlanta office while all other attendees joined virtually. (See “Hybrid Meetings to Start in February,” NERC Board of Trustees/MRC Briefs: Nov. 4, 2021.) The May and August meetings were tentatively planned to be held in-person in D.C. and Vancouver, Canada, respectively, while the November 2022 meeting would have likely been another hybrid gathering.

At November’s meeting, DeFontes emphasized that these plans had not been finalized. While he did not elaborate on the remaining meetings for 2022 in Wednesday’s call, it is probable that they will have to be revised as well.

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Cap-and-trade Projected to Provide Wash. $500M Annually

Cap-and-trade is expected to yield Washington $500 million a year in revenue, said the state agency charged with running the program.

Forty percent of that money will be targeted at disadvantaged communities that are especially vulnerable to climate change, and another 10% will go to the state’s tribes.

“It’s a simple fact that some communities are hit harder by pollution than others,” Kathy Taylor, Air Quality Program manager at the Washington Department of Ecology, said at a briefing of the state Senate Transportation Committee on Monday. 

The rest will be earmarked for other climate-oriented purposes; two-thirds aimed at funding transportation projects, which are expected to receive $1.4 billion in cap-and-trade funds between 2023 and 2027 and $5.16 billion by 2037. Transportation accounts for 45% of Washington’s greenhouse gases.

Passed last year, Washington’s cap-and-trade law — dubbed “cap-and-invest” — goes into effect on Jan. 1, 2023. This year state officials will focus on regulatory rulemaking as well as tweaking the 2021 law. On Monday and Tuesday, Department of Ecology officials briefed the Washington Senate Transportation Committee and a webinar of industry representatives on separate portions of the 2022 efforts.

Washington was the second state to adopt a cap-and-trade law after California, which is in a cap-and-trade pact with Quebec, with the auctions handled by the Western Climate Initiative. Washington recently entered a contract with WCI to administer its auctions. 

The cap-and-trade law calls for the Department of Ecology to develop proposed cap-and-trade regulations by this spring and to formally adopt the rules this fall.

At a Tuesday webinar, Ecology Department officials briefed industrial representatives on the state’s tentative plans. The industrial representatives limited their feedback to technical questions.

The agency’s plan calls for an undetermined number of emissions allowances to be auctioned four times a year to smokestack industries. The first two auctions are scheduled for the first half of 2023, and the state will set the number of “allowances” 60 days prior to the auctions.

Companies would bid on the allowances in clusters of 1,000 individual allowances. The number of allowances will be decreased over time to meet 2035 and 2050 decarbonization goals. Companies will be allowed to buy, sell and trade those allowances. If Washington chooses to join the California-Quebec pact, it would expand its purchase and trading territory to those two areas.

For each auction, a specific number of allowances would be made available to bidders. All bids must be above a certain price level set in advance by the state. 

The highest bidder would get first crack at the limited number of allowances, while the second highest bidder would get second crack, followed by additional iterations. The auction ends when the last of the designated number of allowances is bid upon. Then all the successful bidders pay the same clearing price set by the lowest successful bid.

Bidding companies are limited to acquiring 4 -10% of the total number of allowances, depending on various criteria. 

Rep. Joe Fitzgibbon (D), chair of the House Environment and Energy Committee, has introduced a bill (HB 1682) to tweak the 2021 cap-and-trade law by providing free allowances to “trade-exposed” state industries that compete with foreign entities that don’t have regulations decreasing their carbon outputs. Those free allowances would decrease by 6% annually from 2035 to 2050.

That bill has advanced to the Environment and Energy Committee, but no public hearing date has been set.

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Critical Minerals: America’s Achilles Heel?

The Biden administration’s emphasis on decarbonizing the U.S. economy may be more vulnerable to foreign influence than oil ever was.

That the administration is aware of this vulnerability is apparent in the U.S. Geological Survey’s proposed expansion of its list of minerals critical to U.S. supply chains, now expanded to 50 from the 35 in the previous administration.

It also is in favor of domestic mining these minerals, as detailed in the Infrastructure Investment and Jobs Act approved in November that called for the departments of the Interior and Agriculture to work on streamlining permitting for the mining of rare-earth minerals on federal land. (See Energy Groups Quick to Praise Infrastructure Bill Passage.)

The importance of minerals and the vulnerability created by not sourcing them at home or through companies located in friendly nations could become an issue slowing the effort to move away from carbon-intensive fuels.

But developing policies to promote domestic mining and mineral refining as well as global sourcing while not alienating competing interests or making decarbonization look impossible is a balancing act.

D.C.-based think tank OurEnergyPolicy presented a webinar on the issue Wednesday that focused on the underlying issues, including the politics, and the development of policies to make the nation less vulnerable. The webinar was part of the group’s Energy Leaders Webinar Series and will soon be publicly available online.

Sharon Burke (OurEnergyPolicy) Content.jpgSharon Burke, president of Ecospherics | OurEnergyPolicy

Sharon Burke, president of energy and environmental research group Ecospherics, moderated the discussion. She noted that the nation is more than 50% import-reliant on 31 of the 50 rare-earth minerals and 100% import-reliant on about a dozen of them.

Melanie Kenderdine, principal at the Energy Futures Initiative, said the politics surrounding the issue make it difficult for policymakers.

“It’s a little bit of an inconvenient truth,” she said. “There is a suggestion that ‘renewables’ that are free and everywhere are not necessarily as secure as we might think.”

Part of the problem, she suggested, is that the public and many policymakers “tend to think of energy security as fuel.”

“These are not fuels,” she said of rare-earth minerals. “They are capital costs. And so the lifespan of these technologies … that is what defines the draw on the metals and minerals that we are talking about here today. The lifespan of these technologies is defining the extent of the energy security problem we’re talking about here.”

Melanie Kenderdine (OurEnergyPolicy) Content.jpgMelanie Kenderdine, principal, Energy Futures Initiative | OurEnergyPolicy

Kenderdine suggested that the U.S. Department of Energy and Energy Information Administration begin keeping detailed statistics on strategic minerals and metals as they already do with natural gas, oil and refined products.

Morgan Bazilian, director of the Payne Institute at the Colorado School of Mines, agreed, but added that keeping track of metals and minerals “is not as simple in some ways as understanding the global oil market or the increasingly global natural gas market.”

“What we have in critical minerals is at least 35 and probably closer to 50, as you alluded to, and maybe even a little bit more of deeply fragmented, very small, poor price transparency and poor governance markets,” he said. “So it is much more difficult to group these things together because they are individually very different and so all of that combined, makes a very different problem.”

Asked to compare the Biden administration’s approach to minerals with that of the Trump administration, Aaron Thiele, legislative assistant for energy and natural resources to U.S. Sen. Lisa Murkowski (R-Alaska), said he thought that overall “there is a good level of continuity and urgency.”

Aaron Thiele (OurEnergyPolicy) Content.jpgAaron Thiele, legislative assistant to U.S. Senator Lisa Murkowski (R-Alaska) | OurEnergyPolicy

“I think the administration is kind of grappling with some of their constituencies, and the critical minerals debate always comes down to whether or not it’s going to increase domestic mining and that has its sticky points in politics,” he said.

Thiele said moving from fossil-based technologies to renewables involves tradeoffs and new resource requirements.

“The question is, if we are taking this rapid transition to renewable energy resources, to electric vehicles, where are we going to be in 10 years if we don’t have either domestic [mineral] or partner agreements with nations to lessen that impact? The demand for these minerals is going to be there. The question is, where are we going to source it? Are we going to be able to recycle it, or are we going to substitute it? There is going to need to be a supply side,” he said.

Kenderdine said developing recycling technologies will be important because alternative technologies are not ready for commercialization.

“Recycling and reuse becomes very important,” she said. “I would prioritize that first. And looking at alternatives for these metals and minerals. That’s going to take time and infrastructure.

“Domestic mining, I think, becomes very important,” she added. “But there are a lot of issues with that as well. So I would put recycling and reuse very high up on the agenda, and we should be requiring it.”

Burke asked Bazilian whether the priorities outlined by Kenderdine and Thiele are the right strategy.

Morgan Bazilian (OurEnergyPolicy) Content.jpgMorgan Bazilian, director of the Payne Institute, Colorado School of Mines | OurEnergyPolicy

“I think there has to be a bigger conversation about the balance between the kinds of things Aaron talked about, which is the domestic industry,” Bazilian said. “This is a big issue for developing economies; a lot of them take a lot of their GDP from extractive industries like mining. And focusing solely on our needs or the needs of one country, in general, is bad policy, right? It doesn’t work. We’re in a deeply interconnected world.

“I understand the politics of it, but it’s not the way to do something well. And so, you know, we have to really play a role in this international debate, and support some of these other countries and try to make a thoughtful balance between the domestic and the international,” Bazilian said.

“I recognize, however, that that sounds naive,” he quickly added. “In other words, that’s not how domestic politics go. The priority is clearly and always going to be on the domestic role for this and the jobs and those things at the state level. … [But] if you don’t look at this from a larger perspective, you’re going to make policies that are either inefficient or just bad.”

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Washington Bill Would Factor ‘Climate Resilience’ into Water Systems

The big question on a Washington bill to add “a climate resilience element” to regulating residential water systems was: What would that rule physically do?

Sen. Mark Schoesler (R) posed that question Wednesday at a public hearing on the bill held by the Washington Senate’s Environment, Energy and Technology Committee.

Introduced by Sen. Christine Rolfes (D), Senate Bill 5626 would order the Washington Department of Health to require public water systems serving 1,000 or more connections to include a “climate resilience element” as part of water system plans, beginning Jan. 1, 2024. Local governments would be required to study how climate change could affect their water systems and then take remedial measures.

The bill would allocate $10 million every two years to help with those measures. That was the part that stumped Schoesler.

“What are we going to buy for $10 million?” he asked.

Rolfes said she had not seen the committee staff’s $10 million estimate until just before the Wednesday morning hearing. “The $10 million is new to me,” she said. Meanwhile, committee staff members were also unsure about what the allocations would be used for, other than acting on potential problems identified by studies.

Committee member Sen. Liz Lovelett (D) then pointed to her hometown of Anacortes on Fidalgo Island, which is long and narrow, and juts westward like a peninsula into Puget Sound from northwestern Washington. A water channel converts the “peninsula” into an island.

Lovelett noted that rising water levels from Puget Sound had periodically flooded water lines in and around Anacortes, prompting the town to move its water lines to higher elevations. She cited that as a possible remedial action that could have used a grant from a $10 million state fund.

Five people testified in favor of Rolfes’ bill, including representatives from the Sierra Club, the Washington Public Utility Districts Association and the Climate Impacts Group at the University of Washington. No one testified against the bill.

All stressed the need for studies to pinpoint threats from flooding and wildfires, which they linked to global warming.

Amy Snover, director of the Climate Impacts Group, said a data clearinghouse is needed to help local governments find information to evaluate potential threats from flooding and wildfires. Geography and topography would be major factors in those evaluations, she said.

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BOEM to Auction Six New Lease Areas in NY Bight

Increasing its bet on offshore wind, the Biden administration announced Wednesday that it will auction six lease areas in the New York Bight on Feb. 23, enough to site at least 5.6 GW of generation.

The six leases in the Bureau of Ocean Energy Management’s (BOEM) sale notice are the most ever offered in a single auction, totaling 480,000 acres. BOEM had solicited commercial interest for 1.7 million acres in the Bight but excluded 72% of the area to reduce environmental impacts and avoid conflicts with the commercial fishing industry and other ocean users. BOEM issued its final environmental assessment on the lease areas in December. (See BOEM Issues Final Environmental Review of NY Bight.)

Interior Secretary Deb Haaland, who announced the auction in a press conference Wednesday with New York Gov. Kathy Hochul and New Jersey Gov. Phil Murphy, said the leases will include stipulations to encourage the use of union labor, building of a domestic supply chain and “planned” transmission.

The announcement of the new leases came the same day the Department of Energy issued a report identifying five strategic priorities for maximizing the value and reducing the costs of offshore wind. The Biden administration has set a goal of 30 GW of offshore wind by 2030; with states on the East Coast already committed to a pipeline of 39 GW by 2040, DOE said the country could deploy 110 GW by 2050 — equal to 6% of current demand.

Murphy said the Biden administration’s enthusiastic support for OSW was a marked change from the Trump administration. “I think the most charitable word I can use is [the Trump administration] slowed whatever progress we were making; [I] wouldn’t necessarily say they stood in the way,” Murphy said. “They started out [wanting] to drill for oil and gas offshore. … So this is just night and day.”

Supply Chain, Labor

Like state officials, the Biden administration has promoted the new generation as economic development projects.  

BOEM said it will require lessees to describe their plans for contributing to development of a domestic supply chain and will offer a 50% reduction in the “fee rate” for five years for lessees that “meaningfully and substantially” assemble or manufacture major components in the U.S. That would reduce the fee rate from 2% to 1%.

The operating fee will be based on a proxy for the wholesale market value of the power generated from each project. The proxy will assume a 40% capacity factor for the first six full years of commercial operations, with potential adjustments based on actual generation in future years. BOEM will use the simple hourly average of the spot price for NYISO’s Zone J in New York City. At a wholesale power price of $40/MWh, the annual 2% fee for a 1,028-MW facility, would be $2.9 million.

New York, which has targeted 9 GW of OSW by 2035, will base procurement of offshore wind renewable energy credits (ORECs) in part on economic benefits provided by the projects, including domestic supply chain and port infrastructure investments, benefits to disadvantaged communities and creation of jobs and workforce training programs.

New Jersey, with a goal of 7.5 GW, has approved $350 million in tax credits tied to capital investments in offshore wind-specific facilities in the state.

Officials from BOEM and the two states have created a supply chain working group that will meet quarterly to coordinate their efforts.  

“We are now going to have a very significant regional cluster between New York and New Jersey that will make it very compelling … for folks to not just install, but build the stuff here,” Murphy said.

“This opportunity we’re presented with today is absolutely transformative, not just for New York and New Jersey, but for our nation,” said Hochul.

BOEM also will require lessees to “make every reasonable effort” to sign contracts with labor unions for construction.

“We’ve been laser focused on offshore wind for several years because we think that this can be the sector that is the shining example of how the clean energy economy can create high-road, high-quality jobs,” said Liz Shuler, president of the American Federation of Labor and Congress of Industrial Organizations (AFL-CIO), who also took part in the press conference. “… I can speak from the perspective of workers in the energy industry. They’ve been skeptical of the transition, because [they] have not seen the same quality, stable careers in clean energy that they have in the industries that they’ve worked in in the past. And there hasn’t been a commitment historically to high-quality jobs in the clean energy economy. But it doesn’t have to be that way.”

Transmission Planning

BOEM’s sale notice urged strategic planning of transmission, saying the agency is considering “the use of cable corridors, regional transmission systems, meshed systems, and other mechanisms.” It said it may condition approval of construction and operations plans “on the incorporation of such methods where appropriate.”

The DOE report said “strong near-term efforts” are needed to plan transmission to incorporate OSW “without long delays or lost opportunities.

“There is a lack of sufficient onshore transmission capacity to transmit power from the strongest offshore wind resources to load centers,” DOE said. “…Creating incentives to plan and share transmission across multiple offshore wind projects, states, and transmission planning regions can encourage collaboration in infrastructure planning, cost allocation, and transmission system development that can benefit all states within and across regions.”

Sites

The sites to be leased will be 20-69 nautical miles from New York and 27 to 53 miles from New Jersey, with minimum depths of 31 to 50 meters and maximum depths of 46 to 63 meters. BOEM has established a minimum bid of $100 per acre for the leases, which the agency said could produce 5.6 GW based on 3 MW per square kilometer.

BOEM listed 25 companies eligible to bid in the auction, each of which posted a $5 million deposit. BOEM said it would limit each company to only one lease to maximize competition in future procurements and limit consolidation of the offshore wind market.

Before the auction, BOEM will hold its fifth and final meeting with the fisheries community on Jan. 19 to describe how it decided on the final lease areas.

The final sale notice reduced the area by 22% from the preliminary notice, reflecting concerns by the fishing industry, the U.S. Coast Guard, the National Marine Fisheries Service and the Department of Defense (DOD).

It excluded lease area OCS-A 0543 in response to issues raised by the fishing industry and DOD and to make room for the siting of a “fairway” proposed by the Coast Guard to accommodate traffic travelling across the NY Bight from the Delaware Bay area to east of Montauk.

It also eliminated several areas that overlap with both fishing activity and seafloor features sensitive to impacts from construction. No leases were offered within 2.5 nautical miles of the Mid-Atlantic Scallop Access Area. BOEM also removed areas to the west of OCS-A 0539 that are used by the Atlantic surf clam fishery.

DOE Priorities

In addition to calling for planned transmission, the DOE report listed four other priorities for the nation’s OSW plans:

  • Expanded federal incentives to increase demand for offshore wind energy and grow the domestic supply chain;
  • Technology innovation and adaptations to reduce costs. “New system designs are required for U.S. operating conditions, such as deep water in the Pacific, hurricanes in the Gulf of Mexico, and ice formation in the Great Lakes,” DOE said. “Accessing wind resources in deep-water areas (~60% of the U.S. offshore wind resource) will be key to reaching long-term deployment goals. The deployment of floating offshore wind platforms … will be critical to development in the Pacific, Gulf of Maine and other regions with deep waters.”
  • Increase the transparency and predictability of regulatory processes and auction new lease areas. “The number of lease areas will need to grow significantly over the next decade to meet state and federal deployment goals,” DOE said.
  • Invest in supply chain development, including customized offshore wind ports and vessels. “Building a domestic supply chain and growing the industry will require dozens of port upgrades, numerous Jones-Act compliant vessels, and new factories for component manufacturing and assembly,” DOE said.

Interest in Gulf of Mexico 

In comments posted by BOEM on Jan. 11, Ørsted and Shell New Energies U.S. (NYSE:RDS.A) expressed interest in bidding for potential OSW leases in the Gulf of Mexico.

ClearView Energy Partners said BOEM could offer leases in the Gulf as early as the first half of 2023.

“While existing energy infrastructure and supply chains in [Gulf of Mexico] coastal states may attract offshore wind project developers (indeed, commenters note that offshore wind generation could facilitate green hydrogen production), we emphasize other factors could dampen interest in comparison to the East Coast, including lower electricity prices, the lack of strong state-led decarbonization policies in the GOM area and higher risks of severe hurricanes,” ClearView said in a note to clients.

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DOE to Tackle Tx Siting, Financing, Permitting in Better Grid Initiative

The Department of Energy on Wednesday announced the launch of the Building a Better Grid (BBG) Initiative, aimed at attacking the many obstacles to building out the long-distance, high-voltage transmission network that the Biden administration sees as key to decarbonizing the U.S. electric system by 2035.

“The foundation of our climate and clean energy goals is a safe, reliable and resilient electric grid that is planned hand-in-hand with community partners and industry stakeholders,” Energy Secretary Jennifer Granholm said in a press release. Using federal dollars from the Infrastructure Investment and Jobs Act (IIJA), the initiative will “upgrade the nation’s grid, connect more Americans to clean electricity and broadband, and reliably move clean energy to where it’s needed most.”

Getting to President Biden’s goals of a decarbonized grid by 2035 and a net-zero economy by 2050 will require the grid to expand by 60% by 2030, according to DOE, and by three times its size by 2050. Large renewable projects in remote areas, as well as offshore wind, will need high-voltage transmission lines to efficiently bring power to urban demand centers.

But, according to the DOE, about 70% of the nation’s existing transmission lines and transformers are more than 25 years old. At the same time, hundreds of gigawatts of clean power projects sit in grid operators’ queues, unable to connect because of a lack of transmission capacity.

A 2021 study from the Lawrence Berkeley National Laboratory estimated that 750 GW of solar and wind and 200 GW of storage were backed up in U.S. interconnection queues at the end of 2020.

The need for grid flexibility and resilience has also been underlined by power outages caused by extreme weather or other catastrophic events, such as California’s wildfires, this summer’s extreme heat in the Northwest and the winter storm in Texas last February.

As detailed in a notice of intent released Wednesday, “DOE intends to launch a coordinated transmission deployment program to implement both IIJA and previously enacted authorities and funding.”

A transmission needs study will “identify where new or upgraded transmission facilities could relieve expected future constraints and congestion driven by [the] deployment of clean energy; … higher electric demand as a result of building and transportation electrification; and insufficient transfer capacity across regions.” Additional studies will look at viable pathways to a large-scale transmission system over the next 15 to 30 years, as well as transmission pathways for integrating offshore wind.

Provisions of the IIJA allow DOE to participate in public-private partnerships and to become an “anchor customer” for new and upgraded transmission lines, buying as much as 50% of a project’s planned capacity for a term of up to 40 years. The law also provides a $2.5 billion revolving fund to support the construction of new, replacement or upgraded high-capacity transmission lines, and another $3 billion in matching grants for grid-enhancing technologies, such as dynamic line ratings, flow control devices and network topology optimization.

The IIJA also gives DOE the authority to designate national transmission corridors in “any area experiencing or expected to experience electricity transmission capacity constraints or congestion that adversely affects consumers.” It also authorizes FERC to issue permits for the construction or upgrade of projects in such corridors. DOE intends to prioritize corridors that “overlap with or utilize existing highway, rail, utility and federal land rights of way.” It will also offer developers pre-application review of projects and coordinate with FERC on permitting.

‘Prioritize and Expedite’

The initiative was announced Wednesday by the Biden administration as part of a suite of energy initiatives.

Interior Secretary Deb Haaland kicked off the day with the announcement of next month’s auction of six offshore wind lease areas in the New York Bight, off the coasts of New York and New Jersey. The 480,000 acres in the six lease sites, the most ever offered in a single auction, could eventually generate 5.6 to 7 GW of power. The Bureau of Ocean Energy Management will hold the auction Feb. 23. (See related story, BOEM to Open Six New Lease Areas in NY Bight.)

The Interior Department also took the lead on the rollout of a new cross-agency effort to streamline reviews of wind, solar and geothermal projects on federal land. A memorandum of understanding signed by the Interior, Agriculture, Defense and Energy departments and EPA calls for the agencies to “prioritize and expedite” reviews of these projects. Interagency teams staffed with subject matter experts will help advance environmental reviews and “accelerate renewable energy decision making,” according to the MOU.

Making a Dent

All three initiatives drew praise from Democratic lawmakers and clean energy advocates, but reactions also included calls for the Senate to pass the Build Back Better Act, which includes tax credits for a range of renewable technologies and transmission.

While applauding BBG, Rep. Kathy Castor (D-Fla.), chair of the House Select Committee on the Climate Crisis, said, “I am determined to help communities lower costs with the transition to a resilient and clean energy economy, and I look forward to working with my Senate colleagues to ensure that the critical transmission investments in the Build Back Better Act reach President Biden’s desk, so he can sign them into law.” 

Gregory Wetstone, president and CEO of the American Council on Renewable Energy, said interagency efforts to streamline permitting “will ensure the American people benefit from the best solar and wind resources this country has to offer.” BBG will “unlock the potential of America’s clean energy economy by catalyzing the nationwide buildout of the long-distance, high-voltage transmission.”

Noting that China is investing 80 times more than the U.S. in transmission, Rob Gramlich, executive director of Americans for a Clean Energy Grid, said that BBG and the federal dollars in the IIJA “could make a big dent in the national transmission challenge.”

But he also cautioned that “the funding levels are nowhere near what is required for a national macrogrid. … Congress will also need to pass the Build Back Better Act with the tax credit for regionally significant transmission because there is no way to recover costs of large interstate lines presently.”

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Nevada PUC Rejects Mobile-only Payment Systems for EV Chargers

With more EV drivers using their smartphones to pay for vehicle charging, ChargePoint has asked Nevada regulators for flexibility to leave magnetic-stripe or chip credit-card readers off its public stations.

The request was made in connection with NV Energy’s $100 million EV infrastructure plan that the Public Utilities Commission of Nevada (PUCN) approved in November. (See NV Energy Gets Green Light for $100M EV Charger Plan.)

But PUCN voted 3-0 Tuesday to reject ChargePoint’s proposed changes to the charging station technical standards included in NV Energy’s plan. The plan says that stations “must accept a credit or debit card (magnetic stripe and chip card) without incurring any additional fees … in compliance with ISO 15118.”

The commission instead voted to reaffirm its Nov. 30 order approving NV Energy’s plan, but it made a grammatical change in the payment requirement. The requirement now says that charging stations “must accept a credit or debit card (magnetic stripe and chip card) without incurring any additional fees … and be in compliance with ISO 15118.”

The commission said that the technical requirements are minimum standards, and “other forms of payment may be offered and accepted in addition.”

“The commission reaffirms that more options for payment, rather than fewer options, will make it easier for customers to pay,” the order said.

In reaffirming its Nov. 30 order the commission also rejected a request from EVgo, another EV charging station provider. EVgo asked the commission to give third parties participating in NV Energy’s plan more flexibility to decide the number, type and capacity of chargers at a particular site.

EVgo also asked that the minimum power requirement for DC fast-charging stations installed as part of the plan be 100 kW, rather than 150 kW.

NV Energy’s plan, known as the Economic Recovery Transportation Electrification Plan (ERTEP), is a requirement of Senate Bill 448, a product of the legislature’s 2021 session.

The three-year plan, which starts this year, includes a network of electric vehicle charging sites throughout the state.

Paying With Smartphones

In a petition filed with PUCN last month, ChargePoint said that “real world evidence” indicates most EV drivers prefer to use a smartphone app or other mobile payment method to pay for charging.

The petition argued that requiring magnetic-stripe and chip card readers nearly doubles the lifetime cost of a Level 2 charging station, “with the predictable result that fewer charging stations will be deployed through the plan.”

Magnetic-stripe and chip readers are susceptible to fraud and are unreliable when used outdoors, the petition said.

“ChargePoint is concerned that the payment standards NV Energy has proposed drastically will limit the equipment and vendors that will be able to participate in the plan,” the petition said.

ChargePoint asked that the order be changed to require the stations to accept credit cards, but not specify the card-reader technology. Alternatively, the company suggested that charging-station hosts be allowed to ask for and receive a waiver of the magnetic-stripe and chip card reader requirement.

In a response to the petition, NV Energy said the technical requirements were a topic of “substantial debate” during proceedings leading up to the commission’s Nov. 30 order, and ChargePoint is simply rehashing those arguments.

During testimony, NV Energy officials shared concerns that EV drivers without a smartphone wouldn’t be able to use charging stations that lacked magnetic-stripe and chip readers.

Although ChargePoint said the requirements would limit the number of vendors that could participate in NV Energy’s plan, the utility responded that “the plan can be fully and effectively implemented with a limited number of … vendors willing and able to comply with the technical requirements.”

California Consistency

The Sierra Club and Nevadans for Clean Affordable Reliable Energy (NCARE) weighed in on ChargePoint’s petition, saying EV charging stations deployed as part of NV Energy’s plan should accept credit cards, debit cards and cash cards.

But NCARE questioned the need for magnetic-stripe readers, saying the technology is being phased out.

Many EV charging stations don’t directly accept credit, debit or cash cards and instead require use of a proprietary app or a call to an 800 number, NCARE representative Max Baumhefner testified in November. Prepaid debit cards are especially important to those who are “unbanked” or “underbanked,” he said.

In California, regulations require public charging stations to include a chip reader for credit, debit and cash cards, Baumhefner said, adding that Washington may soon follow suit.

“While contactless credit cards have gained market share in recent years, the debit and cash card market has not seen the adoption of contactless technology at the same rate,” Baumhefner said.

NCARE recommended that NV Energy’s plan mirror the California standards for payment at EV charging stations. Because California accounts for about half of the EV market in the U.S., makers of EV charging equipment will likely be basing designs on California standards, the group said.

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RI Asks Public: How Should We Define Net Zero by 2050?

Rhode Island’s climate council has begun the process of sorting out how it will define “net zero by 2050” for the upcoming update to the state’s 2016 Greenhouse Gas Emissions Reduction plan.

In a public session on Tuesday, the Rhode Island Executive Climate Change Coordinating Council (EC4) sought comments on which emissions to count in the plan, how to net those emissions and over what time frame to net them.

Under Rhode Island’s Act on Climate passed last year, the EC4 must submit a GHG emissions reduction plan update by January . The act sets an economy-wide, net-zero emission target for 2050.

In the current GHG inventory, the state tracks carbon dioxide, methane, nitrous oxide and fluorinated gases, summarized as CO2 equivalent and reported in million metric tons (MMT). While attendees were supportive of the four-GHG approach, there was some concern about the time frames used to calculate equivalencies.

“To combine the impacts of these very different kinds of gases, you need to come up with a way to figure out what one unit of methane means in terms of warming for the planet compared to carbon dioxide,” Timmons Roberts, Ittleson professor of environmental studies and sociology at Brown University, said during the session. That calculation, he added, depends on the time frame used.

Carbon dioxide, for example, stays in the atmosphere for hundreds of years, while methane has a short-term impact before breaking down. Their potential for warming the plant is calculated differently, depending on the time frame.

The New York Climate Action Council, in its draft scoping plan released in December, switched from a 100-year impact time frame to 20 years. For methane, Roberts said, that switch adjusts the impact from being “20 times worse than carbon dioxide per molecule to about 84 times worse.”

He suggested that Rhode Island consider the 20-year time frame for its accounting. “It looks like that’s the way the science is going,” he said.

The EC4 is considering different methods for the way it balances GHG emission from sources with sinks to find net emissions. Under the current inventory, Rhode Island takes all GHG sources and all GHG sinks, both summarized as MMTCO2e, and nets them, according to Carrie Gill, chief economic and policy analyst at the Rhode Island Office of Energy Resources.

As an alternative, she said, the accounting could net each GHG source and sink individually, then convert each GHG to MMTCO2e and add them together to find the final net measurement. A benefit of netting the GHGs separately, according to Gill, would be to target specific policies.

“If one of our policy objectives happens to be eliminating all [methane] leakage from the natural gas distribution system, then that would point us towards trying to get to a place where we can net each GHG first, because then it would meet additional policy objectives,” she said.

While attendees did not favor one accounting method over another, some suggested that netting through offsets or sinks should be a last resort, and Rhode Island should count emission sources outside of the state.

Rhode Island “should get to zero-carbon equivalent emissions” as quickly as possible, attendee Peter Trafton said. “Let’s start by 2030 and not be so focused on the arithmetic of how we add up to 2050 that we forget to get down as low as we can now.”

And while the state’s GHG inventory is consumption-based only for electricity, Roberts suggested it should be used for “everything.” That approach, however, has drawbacks.

“If we have natural gas-fired power plants, we should be including the emissions from the extraction and the transportation of that natural gas … because we know that Pennsylvania, New York and Connecticut, the states through which it’s traveling, are not counting those emissions,” Roberts said.

There’s no good way, however, to be certain of what other states are including in their own GHG inventory, he said.

The EC4 also is considering options for electricity sector accounting that changes the time frame for when emissions are released into the atmosphere.

“Our current practice aggregates these emissions based on averages over the entire year,” Gill said. Electric sector emissions change based on the fuel mix at the time that the electricity is pulled from the grid. Rhode Island, Gill said, counts them equally, whether it’s a renewables-heavy mix on a warm day or a fossil fuel-heavy mix on a cold day.

Future accounting options may allow the state to consider netting emissions over smaller time frames, but Gill said that would require some technological advances in accounting systems.

The EC4 will accept comments on how to define net zero by 2050 in the updated emissions-reduction plan through Jan. 28. In February, the council will discuss a draft of that definition during its regular meeting and release an update based on public input in March.

Another public comment session for the emissions-reduction plan in March will address the 1990 baseline against which emissions are measured.

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Washington Bill Takes Aim at Landfill Methane Emissions

A bill to regulate methane emissions from landfills drew praise and concerns during a hearing of the Washington House Environment and Energy Committee on Tuesday.

Questions surfaced about the costs and extent of House Bill 1663, introduced by Rep. Davina Duerr (D).

In its present form, the bill requires the owner or operator of a covered landfill with 450,000 tons or more of waste in place to calculate the quantity of gas generated by the landfill.

If that calculation exceeds 3 MMBtu per hour, the operator would have to install and operate a gas collection and control system. A collection system would also be required if methane emissions hit 500 parts per million (ppm), as determined by instantaneous surface emissions monitoring, or if an average methane concentration reaches 25 ppm based integrated surface emissions monitoring.

The bill does not apply to landfills that handle solely hazardous wastes or only inert waste or non-decomposable wastes.

California and Oregon already have similar landfill emissions rules in place. (See Oregon Adopts Nation’s Strictest Landfill Emissions Rules.)

Landfills contribute to climate change with their methane emissions. “Methane stays in place for 10 years instead of 100 years, but it has 100 times the impact of carbon emissions,” Duerr said at the hearing.

Methane emissions from the state’s landfills are estimated to equal those of roughly 320,000 cars, said Martha Hankins, a manager with the Washington Department of Ecology.

“Methane is one of the most impactful greenhouse gases,” said Deepa Sivarajan, Washington policy manager with Climate Solutions. Heather Trim, executive director of Zero Waste Washington, said, “This bill is way overdue.”

Methane accounted for 10% of the nation’s emissions in 2019, according to EPA estimates. EPA figures show that landfills account for 17% of the nation’s emitted methane, behind fuel production at 30% and livestock-related emissions at 27%.

Utilities and waste management officials voiced concerns about the unknown costs of implementing the bill and asked for more study on the subject. They also wanted a better grasp on which specific locations would have to comply with the bill’s requirements

“It is a significant unfunded mandate for municipal solid waste programs,” said Paul Jewell, policy director with the Washington State Association of Counties.