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October 30, 2024

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SERC: Cybersecurity Means Going Beyond CIP Standards

Presenters at a webinar hosted by SERC Reliability on Wednesday warned utilities that ransomware is a much bigger threat than many of them realize, and major efforts are still needed to make operational technology and information technology assets safe from infection.

“It’s a global thing. It just affects every industry and anyone who is connected to the internet from an enterprise perspective,” Etinnie Burnett, a Critical Infrastructure Protection (CIP) auditor at SERC, said in his presentation on ransomware at the regional entity’s 2023 CIP Spring Security Webinar. “Whether it be OT [or] IT, this affects you in the way we look at how we reduce that risk. It’s an overarching thing; it’s not just a piece of a pie; it’s the whole pie.”

Burnett cited recently released data from cybersecurity firm Dragos that it tracked 605 ransomware attacks against industrial organizations worldwide in 2022, nearly double what it saw the year before. About 41% of those incidents affected organizations in North America. (See Dragos: Cyber Landscape Remained Volatile in 2022.)

Ransomware-incidents-map-(Dragos)-Alt-FI.jpgCybersecurity firm Dragos recently announced that North America accounted for more ransomware incidents than any other region in 2022. | Dragos

 

While just 29 of last year’s ransomware attacks targeted the energy sector, Burnett said utilities should take the threat seriously, because even a single successful intrusion can cause major disruptions. He pointed to the Colonial Pipeline breach of 2021, which caused the nearly weeklong shutdown of a major fuel supply network and led to a regional emergency declaration affecting 17 states and D.C., saying the case illustrates that companies can suffer even when an intrusion only directly impacts a company’s IT network, rather than the OT environment that directly manipulates its physical tools. (See Biden Directs Federal Cybersecurity Overhaul.)

Burnett also highlighted the Black Basta cyber gang, a suspected offshoot of the Conti and REvil groups that breached Chicago-based construction and engineering firm Sargent & Lundy last October. Sargent & Lundy has significant interaction with the bulk power system; the description of its work on its website mentions “electrical grid modernization, renewable energy, energy storage, nuclear power and fossil fuels.”

The firm’s notification of the breach, released in December, said the hackers are known to have accessed the names and Social Security numbers of “over 6,900 individuals.” Burnett said this exposure could easily put business connections of the firm at risk, showing how “it’s not always the entity; it’s who the entity does business with. How are [they] protecting my data as well?”

Burnett then pointed to a paper from 2016 surveying electric utilities on the effect of NERC’s CIP standards. While the standards are intended to address cyber and physical security risks, Burnett noted that many respondents held an ambivalent view on them, citing concerns such as the difficulty of NERC’s deliberative standards development process keeping pace with the rapidly changing cybersecurity landscape.

While Burnett acknowledged these fears, he said they should serve as a catalyst to utilities to build cybersecurity programs that go beyond the bare minimum requirements of the CIP standards. He urged utility leadership to recognize that “there’s no [one] standard that I can speak to that is going to solve this problem.”

“Every standard is a key part of reducing the ransomware [threat], and cybersecurity [must be viewed] as a threat in the larger context,” Burnett said. “So we cannot be single-minded — we can’t think, ‘We’re just in our little bubble, and this is my part of the process, and this is their part of the process. The silo mentality, when it comes to ransomware, is risky, because … we won’t catch [those risks] until after the fact.”

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NYPA Leader Says Expansion not Threat to Private Sector

The head of the New York Power Authority said Tuesday that the utility’s proposed renewable energy development role is a necessary part of the state’s drive to clean energy.

Gov. Kathy Hochul is seeking to expand the state-owned utility’s capabilities as part of her state budget plan.

But energy developers and their legislative allies have said the private sector is capable and willing to do the work needed to decarbonize New York’s power grid, and NYPA should not be placed in competition.

Justin Driscoll (New York Power Authority) FI.jpgJustin Driscoll, acting president of the New York Power Authority | New York Power Authority

Acting NYPA President Justin Driscoll told the State Senate Energy and Telecommunications Committee on Tuesday that it is not an either-or proposition.

“Given the challenge we’re facing here, we need all the tools in the toolbox,” he said. “Government can play a role. Nobody is suggesting that government be the only tool. But just given the enormity of what we’re looking to achieve here, we think that NYPA and government can play an ancillary role in the energy transition.”

Driscoll explained that NYPA could take on smaller projects that the private sector might skip; collaborate with the private sector on larger renewable development; or provide siting for these projects on land it owns.

“So I think it’s just additive to what the industry is doing now,” he said.

Large-scale renewable projects that have been awarded contracts by the New York State Energy Research and Development Authority would get New York to 66% statewide renewable generation. This is close to the 70% mandate set for 2030, but Driscoll noted not every project will be built. So, more is needed.

“Can NYPA be additive to that private-sector work? I think so,” he said.

Some critics say Hochul’s proposal to expand NYPA’s responsibilities goes too far by creating potential competition with the private sector. Other critics say Hochul’s plan doesn’t go far enough, as it only authorizes, not requires, NYPA to undertake development and does not fold in provisions to boost organized labor. (See Hochul Proposes Expanded Clean Energy Role for NYPA.)

Driscoll earlier this month told a Senate budget hearing that NYPA needs discretion to pick and choose projects because of its finite resources and said he thinks there are sufficient labor protections in Hochul’s plans. (See NY Legislators Press Hochul Officials on Energy Transition.)

Nor, he said Tuesday, would NYPA’s status as a public agency enable it to sidestep regulations, oversight and local accountability on any projects it did undertake.

Senators asked Driscoll about nuclear fission and hydrogen combustion. While neither emits carbon dioxide, some climate activists say they should not be classified as clean energy.

“I can tell you around the country there’s a lot of interest in the deployment of small modular reactors,” Driscoll said. “We won’t be a leader, I don’t think, certainly at the Power Authority. Other states will potentially lead the way, and we’ll see what comes out of that in the way of efficiency [and] safety. Obviously nuclear is a huge piece of where we sit today in terms of our clean energy.”

Hydrogen, he said, is certainly going to play a big role in the energy transition.

“The big question for industry is, what’s the right role for hydrogen?”

NYPA undertook a pioneering test of fuel mixtures of up to 40% hydrogen at its natural gas-fired peaker plant east of New York City, Driscoll noted. (See NYPA Reports Successful Hydrogen Test at Natural Gas Power Plant.)

“We have no plans to utilize hydrogen in any of our power plants, but we thought it was important learning.”

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NYDPS Gives Go-Ahead to CHPE Construction

The New York Department of Public Service on Monday authorized the Champlain Hudson Power Express (CHPE) to begin construction on the line, which will deliver Canadian hydropower to New York City (10-T-0139).

DPS approved the CHPE’s revised Environmental Management and Construction Plan (EM&CP) for Segments 1 and 2 after determining they complied with the state’s conditions, including facility design and maintenance plans, environmental and agricultural controls, and construction coordination.

Segment 1 covers the installation of conduit and cables spanning approximately 7.4 miles from the western shore of Lake Champlain in Putnam Station along County Route 3 and Lake Road to its intersection with State Route 22, while Segment 2 covers approximately 10.2 miles starting at the end of Segment 1 and following Route 22 until arriving at Bellamy Street, where it will connect to Segment 3.

The entire 339-mile CHPE high voltage direct current (HVDC) 1,250-MW transmission line will deliver hydropower from Montreal, Quebec, to Astoria, Queens. (See Champlain Hudson Power Express Closes on Financing.)

CHPE Construction Schedule (CHA Consulting) Content.jpgAnticipated CHPE segment construction schedule | CHA Consulting

Both the CHPE and the Clean Path New York are Tier 4 transmission projects, intended to increase the penetration of renewable energy into New York City, which relies heavily on fossil fuels.

NYISO’s 2022 Reliability Needs Assessment highlighted the importance of completing Tier 4 projects like the CHPE noting significant delays could mean emissions-producing peaker plants may need to remain operational longer than expected to ensure resource adequacy margins and grid reliability are maintained. The project is four months behind the November 2022 construction start date presented in the EM&CP. (See NYISO RNA Raises Concerns over Timing of Peaker Unit Retirements.)

The New York State Energy Research and Development Authority, which issued the solicitation that resulted in the CHPE’s selection, told RTO Insider the agency “is excited to see the Champlain Hudson Power Express (CHPE) start construction efforts in earnest, after the groundbreaking last fall and the creation of laydown yards along initial portions of the route.”

Transmission Developers Inc. (TDI), which is developing the CHPE, called it “a unique and incredibly complex construction project resulting in an equally complex review process.”

Jennifer Laird-White, TDI’s vice president of external affairs, told RTO Insider that as the CHPE “advances and both the state regulatory agencies and the world-class CHPE construction team adjust, the EM&CP pace will quicken.”

“The CHPE team is aware of our importance in the state’s nation-leading Climate Act goals, and we look forward to helping New York meet them,” Laird-White said via email.

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NJ Regulators Seek ‘Proactive’ Grid Upgrade Plans from Utilities

With a goal of modernizing New Jersey’s grid, the Board of Public Utilities (BPU) is close to concluding a new rules package that includes a requirement that utilities regularly identify barriers to interconnecting renewable energy resources.

The rules, which are in the final stages of public input before enactment, would require utilities to file a Proactive System Upgrade Plan (PSUP) every six months for needed “proactive circuit and system upgrades aimed at expanding opportunities for customer-generator facilities.” The plans would have to include the costs and benefits of the upgrades.

The package is part of the BPU’s effort to incorporate utilities in a regular planning cycle that would “eventually help drive a more nimble, flexible and responsive grid that accurately telegraphs intended capacity improvements and produces the highest societal benefits” for distributed energy resources, according to a BPU presentation at a meeting Feb. 10.

The proposal is under evaluation as the state and its utilities, like those in other states, are wrestling with the issue of how to connect the rapidly growing number of renewables to an aging grid that in some areas can’t handle any new interconnections; those it can take are often subject to lengthy delays.

The plan, and five other rules and process proposals outlined at the Feb. 10 hearing to solicit public input, were drawn from a report by consultancy Guidehouse on how to modernize the grid and improve interconnection rules. (See NJ Solar Sector Calls for Speedy Grid Modernization Plan.)

Paul Heitmann, program manager of the BPU’s Clean Energy Division, who moderated the hearing, said the board’s goal is to reduce barriers to the adoption of DERs. That means “improving access to relevant information for applicants, managing the queue and reducing processing intervals where we can,” he said.

To that end, the BPU’s rules include:

  • a series of new definitions for parts of the interconnection process that would make it clearer how the process would proceed;
  • improvements to the application process to give applicants greater access to key information needed in the process, to better manage the queue and make the process more transparent and accountable;
  • an increase in the threshold of a project that requires more intense study before connection, so that more projects are considered smaller and allowed to proceed with a simpler study;
  • revisions to “more clearly define the expected intervals and actions” needed by all stakeholders to move applications forward in a predictable and timely manner; and
  • a requirement that utilities complete an annual hosting capacity analysis, which would identify locations with spare capacity. The analysis would include the compilation of data at both the circuit and substation level, and a requirement that updates to hosting capacity maps be done every three months.

Flagging Weak Links

The PSUP is intended to create a system that will enable utilities to easily detect and report “if they are seeing where things are really congested and closed, and not available for hosting,” Heitmann said.

Those kind of problems might emerge as utilities conduct routine studies for individual products or “cluster studies” for several projects, he said. If the analysis produces data that says, “‘Boy, if we can upgrade this substation at a reasonable cost; this should be a fast-track opportunity,’” then the PSUP will convey that information to the BPU, he said.

“We don’t have that mechanism right now,” BPU General Counsel Abe Silverman said. “But this opens up the channel for that to come in play.”

In response to a question from stakeholder on how the information would be used, Heitmann said the reports will provide a proactive look at “which segments of the distribution system have deficiencies, relative to hosting capacity and ability to connect.”

“When that’s filed, that is a reference point that we now have as useful information to see where new applications are coming in,” Heitmann said. “Does it align to this intent already? Does it support the deficiency?”

In some cases, the new process would mean the BPU allows a developer looking for an interconnection to “come in and request that the utility build the upgrade identified in the PSUP, and then pay their pro rata share of those costs,” Silverman said.

“This is a little bit of a departure from sort of normal business as usual,” he acknowledged, adding that the board is keen to get stakeholder thoughts on how the process should work.

Ensuring Equity in Upgrades

One attendee, who was identified only as Steve, encouraged the BPU to make decisions with the involvement of a consumer advocate who is focused on community equity and can provide a perspective that looks beyond a system in which upgrades are selected by the utilities “based on physics and best value.”

“We all know when people need to interpret results and make judgments, equity often suffers,” he said. “So, I just want to make sure that we’re not targeting upgrades and areas that are already benefiting from a lot of DER penetration and [that we are] keeping in mind communities that might not have benefited from it as of yet.”

Heitmann agreed, saying that the utility filings would have to “address that fairness and balance, as well as the physics.” He added that the governor’s Office of Equity would be involved in the process to make sure that happens.

Lyle Rawlings, president of the Mid-Atlantic Solar & Storage Industries Association, said the PSUPs will need to look beyond individual cases so that they can address issues from a broader view that includes taking into account the kind of problems that “can be anticipated to impact large sections of the grid.”

He cited the example of areas with a density of solar installations where it can be clearly expected that substations will need to be upgraded.

“It’s obvious that this is going to happen in areas where solar concentrates,” he said, explaining that “if it’s expected that many, many substations are going to need this,” the BPU should respond accordingly.

Silverman said that is precisely the kind of “fundamental” question that the BPU is looking to address, and he characterized it as asking, “How do we how do we advance distribution planning writ large?”

“I would think of this as an early attempt to identify those places, not necessarily as a replacement for a full integrated distribution planning proceeding,” which will have to take place later, he said. “Think of this as the first … baby toddler step towards accomplishing exactly what you’re saying.”

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MISO States Ramp Up ROFR Legislation

State legislatures in MISO’s footprint are undertaking a flurry of activity on right-of-first-refusal legislation as major transmission planning surges.

In Mississippi, ROFR legislation has cleared both houses of its legislature and is set to be signed by the governor later this month. Missouri and Kansas are currently mulling adding ROFRs for their utilities.

Eight MISO states already have ROFR laws, which give incumbent utilities first crack at transmission construction: Indiana, Iowa, Michigan, Minnesota, Montana, the Dakotas and Texas. Wisconsin lawmakers have considered one but haven’t passed it.

Montana had debated whether to revise its ROFR law to include lines constructed in a “federally recognized reliability organization” instead of a “midwest reliability organization,” as is currently worded. But on Wednesday, the state’s Senate Energy and Telecommunications Committee voted 11-1 to table the bill (SB 353).

Minnesota is looking into repealing its ROFR law. Had it not been for the legislation, MISO would have opened the $115 million, 50-mile, 345-kV Huntley-Wilmarth line to competitive bidding in 2016. Cost overruns related to a routing change pushed construction estimates beyond $150 million in 2020. (See Major MISO Tx Projects Face Various Hurdles.)

Indiana’s latest ROFR revision has cleared the House of Representatives and is before the Senate. The state currently maintains ROFRs for transmission projects within its utilities’ service territories. The new bill will extend that right to interregional projects as well, effectively overriding FERC Order 1000 (HB 1420).

An Indiana state representative recently said MISO has been involved in lawmakers’ proposal to re-establish a ROFR for interregional projects. During a Feb. 7 meeting of the Indiana House Utilities, Energy and Telecommunications Committee, Rep. Edmond Soliday (R) appeared to assert that MISO supported the legislation.

Soliday said he was “amazed” during a recent meeting with MISO executives how an unnamed vice president said, “We need this [ROFR] bill; we need this bill in Indiana.”

“So that’s why we brought it forward,” Soliday said during the hearing.

Soliday did not clarify his comments, nor identify who he was in conversation with after multiple requests from RTO Insider. MISO declined to identify the executive in question.

Through a spokesperson, the RTO reiterated that it is “not a policymaker and does not take positions on legislative matters.” However, Brandon Morris said, “MISO routinely has informational conversations with regulators and policymakers about the potential impacts of new rules or regulations.”

“We do not advocate for legislation, but we do outline the realities of complying with specific laws related to transmission planning and grid operations. We simply provide the facts so they can reach their own conclusions,” Morris said in an emailed statement to RTO Insider.

Indiana Rep. Matt Pierce (D) said his “no” vote on the bill’s advancement came down to his belief that having a “disinterested party like MISO manage the bid process would bring us more robust competition than we might see under this bill.”

The argument mirrors national trends in ROFR legislation. Critics say the laws restrict competition while supporters maintain that the projects are best left to the utilities that understand their systems best.

Ameren Missouri Vice President of Regulatory Affairs Warren Wood said recently in a company advocacy website that his utility supports the legislation because it “is crucial to ensuring Missouri electric utilities are the architects and builders of our state’s transmission projects moving forward.”

Last week, Oklahoma Senate Energy Chairman Lonnie Paxton announced he would not hear Oklahoma’s proposed ROFR legislation, calling it anticompetitive.

Industrial Energy Consumers of America President Paul Cicio said the bill’s failure is a win for consumers.

“Other states considering these anticompetitive and unconstitutional ‘right of first refusal’ bills such as Indiana, Mississippi, Kansas, Missouri and Montana should follow Oklahoma’s example and reject them,” he said in a statement. “With record investment into America’s electrical grid expected in the next few decades, it is vital that states find cost-effective ways to build transmission infrastructure while promoting innovation. Competition is the only way to achieve those goals. The interests of the consumer will win out.” At the time of Cicio’s statement, Montana’s ROFR bill was still being considered.

Cicio’s organization is part of a consumer alliance asking FERC to block MISO and other grid operators from applying “anticompetitive” ROFR laws to their regional transmission planning and cost-allocation processes (EL22-78). The complaint is pending at FERC. (See Consumer Groups File FERC Complaint Against MISO.)

The group said ROFR laws conflict with the commission’s rules on transmission competition and its obligation to establish just and reasonable transmission rates. It asked FERC to prohibit MISO from recognizing state ROFR laws in its $10.4 billion, 18-project, long-range transmission plan. Only about 10% of the portfolio is open to competitive solicitation.

The alliance also includes the Coalition of MISO Transmission Customers, the Wisconsin Industrial Energy Group, Resale Power Group of Iowa, Association of Businesses Advocating Tariff Equity and the Michigan Chemistry Council.

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Vistra Favors PCM’s Emphasis on Dispatchable Gen

Vistra (NYSE:VST) CEO Jim Burke took a wait-and-see approach Wednesday to ERCOT’s market redesign that is currently being debated by regulators, legislators and stakeholders, pointing out there are many details yet to be determined.

“I think there’s really a couple concepts we would want to make sure when we get through the stakeholder process,” he told financial analysts during Vistra’s year-end earnings call. “One is, is it material enough to attract investment? And is it enough to retain the generation that’s currently there?”

Attracting new generation and retaining new generation, primarily dispatchable, are the two goals behind the performance credit mechanism (PCM) that the Texas Public Utility Commission has offered up for vetting by the state’s legislature. The construct would reward generators — like Vistra’s Luminant subsidiary — in ERCOT’s energy-only market with credits based on their performance during a determined number of scarcity hours. (See Texas PUC’s Market Redesign Dominates ERCOT Market Summit.)

“I think it’s too early to say what the PCM is going to provide, obviously,” Burke said. “We believe in that dispatchable resource emphasis around PCM. We think that’s core to grid reliability. But there’s too many things to still work out in the stakeholder process.”

Vistra reported year-end adjusted EBITDA from ongoing operations of $3.12 billion, as compared to 2021’s performance of $2.03 billion. The February 2021 winter storm had a largely negative effect on the company’s earnings the year before.

For the quarter, ongoing operations adjusted EBITDA was $771 million, down from the year prior of $1.19 billion.

The company uses adjusted EBITDA as a performance measure because, it says, outside analysis of its business is improved by visibility into both net income prepared in accordance with GAAP and adjusted EBITDA.

While Vistra keeps a keen eye on the PCM and its possible benefit to thermal generation, it continues to transition its generation fleet to lower-carbon resources through investments in solar and battery energy storage developments. It added 418 MW of zero-carbon generation and storage in Texas and retired about 2.9 GW of fossil units in Ohio and Illinois.

The company plans to add 350 MW to its Moss Landing battery storage project in California. That will increase the facility’s capacity to 750 MW.

Vistra’s share price closed down 28 cents Wednesday at $21.71 after briefly reaching $22.41 following the earnings release.

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OurEnergyPolicy Examines Role of Competition in the Energy Transition

Electricity markets might need to change along with the shift to more renewables in the industry, but speakers on an OurEnergyPolicy webinar yesterday argued they were still the best way to make that transition reliable and affordable.

Some have claimed that the transition to markets has been difficult for the old monopoly utilities in the states that have opened their markets, but Emily Sanford Fisher, the Edison Electric Institute’s executive vice president for clean energy, is not among them.

“The answer is ‘no’; I think they’ve responded well,” Fisher said. “It’s been, you know, 20, maybe going on 30 years since some of these restructurings have occurred. But I think one of the interesting impacts that we haven’t focused on is the supplier-of-last-resort obligation.”

In every restructured state except for Texas, utilities are the provider of last resort, and significant shares of small, mass-market customers still take service from them. The utilities have to buy power to ensure that they can meet that demand, plus any customers who come back to their service from a competitive firm, Fisher said.

Texas has gone the farthest with restructuring, and its old utilities in the ERCOT market are effectively wires-only companies now, with the provider-of-last-resort obligation covered by competitive retailers.

“We are equal participants in these markets,” Fisher said. “Some of the discussion often sounds like we live in two worlds: There’s an [investor-owned utility] world, and then there’s a competitive market world. We’re all part of that same sort of ecosystem, but our ability to plan for and to make sure that we are able to provide power to customers is sometimes challenged by that construct.”

Restructured states generally do not allow utilities to directly own generation, but Fisher noted that has started to change in states like Massachusetts that want to see major investments in offshore wind. Utilities’ balance sheets are better able to handle those major, upfront investments, she added.

While utilities can help build massive infrastructure projects, the industry has many more options to supply customers than it used to in the past, said Robert Dillon, executive director of the Energy Choice Coalition.

“They place a bet on one technology, and the market is changing so rapidly, that a lot of times they’re betting on the wrong technology,” Dillon said.

The private sector is able to invest in a broad array of different technologies that can help improve flexibility and reliability, including the distributed technologies that customers are investing in themselves, he added.

“I think the existence of competition and generation makes sense,” Fisher said. “I think there’s a benefit that has allowed us to bring new technologies into the market.”

Renewables were probably going to grow anyways, but the combination of markets and state renewable portfolio standards has driven much of their deployment, Fisher said. Renewables are cheap to deploy now, but other technologies such as hydrogen or advanced, long-duration storage are going to be needed to get to a 100% emissions-free grid, and Fisher said utilities are in a good position to help them become commercially competitive.

Locking in too many decisions now could prove to be a bad bet for the future given that power plants are meant to last for decades, noted Conservative Coalition for Climate Solutions Vice President of Public Policy Nick Loris.

“We don’t necessarily know what the future generating sources that are most affordable, reliable and clean will be,” Loris said. “And the more that the government locks resources in unproductive places with specific tax subsidies to specific energy technologies, it makes it all that more difficult for them to compete in the marketplace.”

The Inflation Reduction Act’s clean energy tax incentives transition to just a “clean incentive” that is not technology specific starting in 2025, which should allow “all the flowers to bloom,” Fisher said.

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Washington House Calls for Dimming Turbine Lights

OLYMPIA, Wash. — The House voted 94-1 Monday to require wind turbine lights be turned off at night when not triggered by airplanes.

House Bill 1173, introduced by Rep. April Connors (R) now goes to the Senate. Connors represents the Kennewick area, where a 224-turbine wind farm proposed in the Horse Heaven Hills just south of the city has prompted pushback from residents upset that the project would clutter their views of a pristine-looking ridge line.

If enacted, the bill would require existing and future turbines to be fitted with an aircraft detection lighting system that would turn on the lights only when airplanes were in the vicinity. The proposed law would go into effect for existing turbines on Jan. 1, 2026.

Scout Clean Energy of Boulder, Colorado, has proposed building up to 224 wind turbines, each about 500 feet tall, on 112 square miles of mostly private land in the Horse Heaven Hills. About 294 acres of the Horse Heaven Clean Energy Center would also hold solar panels. The wind turbines and solar panels are projected to produce 1,150 MW. 

Horse Heaven Clean Energy Map (Scout Clean Energy) Alt FI.jpgThe Horse Heaven Clean Energy Center will generate up to 1,150 MW from solar panels and 224 wind turbines. | Scout Clean Energy

 

At a Jan. 16 hearing before the House Energy & Environment committee, Connors said the blinking lights on top of the 500-foot towers could be seen across an area with roughly 200,000 residents. “Those blinking lights at night, you can see them from hundreds and hundreds of miles away,” she said.

Germany has a similar law in effect, she said. Connors estimated that Washington already has 2,000 wind turbines.

While wind turbines provide needed electricity, “for many others, they are a disturbing eyesore,” said Kennewick resident Paul Krupin at the hearing. 

Peter Godlewski of the Association of Washington Business was concerned that the cost of adding an aircraft detection lighting system to each turbine would increase the cost of producing electricity, which would add to consumers’ bills.

Scout says it is developing visual simulations for numerous viewpoints in the surrounding area as required by the State Environmental Policy Act. “These simulations will provide a good representation of how the project will look once constructed and will be posted to the project website once completed,” the company said.

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Washington Holds First Cap-and-Trade Auction

Washington’s first cap-and-invest auction took place Tuesday, but initial results will not be released until March 7, when the state Department of Ecology will publish information about the auction prices and the number of sold allowances. Each allowance will equal a metric ton of greenhouse gases.

Ecology department spokesperson Claire Boyce-White said it will take a week to compile the initial data, and that the agency will release information on the amount of revenue raised on March 28.

Both the March 7 and end-of-March reports will be posted to the department’s Auctions and Trading webpage under the Market Information tab at the bottom of the page

“Today’s auction marks an important milestone in the implementation of the cap-and-invest program,” said Laura Watson, director of the Department of Ecology. “I am proud of our staff’s work to bring this historic greenhouse gas reduction program to life.”

In January, Washington officials told the Senate Transportation Committee that the cap-and-trade auctions could raise almost $1.5 billion through fiscal 2024.

Later this legislative session, the state Senate and House plan to allocate revenue from the first auction. The ecology department estimates $484 million in cap-and-trade revenue for fiscal 2023 (July 1 to June 30, 2024) and $957 million in fiscal 2024.

The revenue from the auctions is expected to shrink over time as the number of emission allowances is reduced. The department estimates $901 million in revenue for FY 2025, $730 million in FY 2026 and $592 million in FY 2027.

Emitting companies would bid on the allowances, which would be made available in batches of 1,000. The first auction will cover 6.185 million allowances, with a minimum allowed bid of $22.20/allowance.

The highest bidder would get first crack at the limited number of allowances, the second-highest bidder would get second crack, and so on. The auction ends when the last of the designated allowances is bid upon. Then all successful bidders will pay the same price per allowance as the lowest successful bid.

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Changes to Permitting Laws Face a Stark Partisan Divide

“Permitting reform” might be a legislative goal for some on both sides of the aisle in Congress this session, but the two parties are far apart on what that means, as evidenced by two hearings held by the House Natural Resources Committee on Tuesday.

The full committee held a hearing on the BUILDER Act, which would change the National Environmental Policy Act by requiring enhanced coordination among federal agencies, creating predictable timelines for project reviews and limiting litigation to lawsuits brought by parties involved in the agency review process. (See NRECA Endorses 2-Year Limit on NEPA Reviews.)

Earlier in the day, the committee’s Energy and Mineral Resources Subcommittee held a hearing on a pair of bills: the Transparency and Production of American Energy Act and the Permitting for Mining Needs Act of 2023. The first bill is focused on increasing leases for oil, gas and geothermal on federal lands, while the second would make similar changes for mining specifically.

Most people do not know the issues around permitting infrastructure and have never heard of NEPA, committee Chair Bruce Westerman (R-Ark.) said.

“But I do know that every single person in the U.S., regardless of their zip code, has relied on infrastructure, energy or other projects that underwent NEPA reviews,” Westerman said. “And all too often, I know that Americans have faced bureaucratic nightmares and decades-long delays in attempts to build roads and bridges in their communities, or access critical mineral resources.”

Without changes to NEPA, Westerman questioned how any of Democrats’ clean energy goals could be met.

Ranking Member Raúl Grijalva said the afternoon hearing was giving him a case of déjà vu, as his Republican colleagues had spent a previous hearing blaming all of the delays experienced by the oil industry on NEPA and the morning hearing had featured another two bills that he said would gut the law.

“Now we’re here again with yet another bill taking aim at NEPA,” Grijalva said. “And what is best for the public interest is secondary, if that. And, as I have in our other hearings, I feel obligated to point out how irresponsible it is to cut environmental review while we’re in the midst of the greatest environmental crisis of our time.”

Rep. Garret Graves (R-La.), who introduced the BUILDER Act, said he had met with Special Presidential Envoy for Climate John Kerry and Brian Deese, who recently stepped down as director of the National Economic Council. Both of them endorsed permitting reform to ensure that the billions of dollars set aside for clean energy in recent legislation actually leads to projects, he said.

Dairyland Power Cooperative is trying to build a couple of projects that it said would lead to cleaner electricity for its Wisconsin customers, but have been caught up in permitting-related delays for years, said its vice president of strategic growth, John Carr.

One is the Nemadji Trail Energy Center, a new gas plant that would replace coal and less efficient gas in the dispatch stack while helping to balance renewable power. Its permitting review process was done in 2021, but external groups asked the U.S. Rural Utilities Service to review its impact on climate change, and now Dairyland has been waiting more than five years for a final permit.

“Meanwhile, reliability concerns in the Midwest have led to postponement of previously announced coal plant retirements by other utilities in the region,” Carr said.

The other project is the Cardinal-Hickory Creek transmission line, which would bring wind power from Iowa to Wisconsin’s major cities.

“There are currently over 100 renewable energy projects depending on the construction of this line,” Carr said. “In this case, while the NEPA review was completed in a timely manner, delays due to litigation have increased the cost of the project.”

Port Arthur Community Action Network Founder and President John Beard, former mayor of the Texas city, had worked in a refinery for decades in a region that has been home to heavy industry for more than a century. The city has a poverty rate of 30% and more $80 billion of industrial development going on in an area that is already home to numerous heavy industry sites.

EPA has called Port Arthur an environmental justice “showcase community” because its residents have cancer at twice the national and state average, as well as higher rates of heart, lung and kidney diseases, Beard said. The main reason so many heavily polluting sites have been built there is it is the path of least resistance, as Port Arthur’s residents lack the resources of wealthier communities to challenge such developments, Beard said.

“So, when you talk to me about restricting access to the legal system, which is a foundation of our country, then you’re telling me exactly that you are not going to give their voice to be heard,” Beard said.

FERC oversees some of the infrastructure in Port Arthur, notably LNG export terminals, and Beard recalled a commissioner highlighting how such projects were often delayed.

“The permits were not held up because of government inefficiency, but because the permits were incomplete,” he added.

The Inflation Reduction Act included $1 billion to increase agency staff and resources to process permits more efficiently, several Democrats said, including Rep. Debbie Dingell (D-Mich.). She is open to more changes to permitting laws, but not at the expense of gutting environmental protection.

“I know we got to modernize our laws, but we’ve got to do it in a way that protects original intent, but also makes it better,” Dingell said. “These don’t. And I’m serious about working with you on real legislation that would do that. Unfortunately, I don’t think these are serious proposals.”