Category: Environmental Law

Reinventing the American Road Trip: What the Inflation Reduction Act Means for Electric Vehicle Infrastructure

The Inflation Reduction Act of 2022 (“IRA”) signifies a turning point in domestic efforts to tackle climate change. Within the multibillion-dollar package are robust investments in climate mitigation initiatives, such as production tax credits, investment tax credits for battery and solar cell manufacturers, tax credits for new and used electric vehicles (“EV”)1, automaker facility transition grants, and additional financing for the construction of new electric vehicle manufacturing facilities.2 One thing is abundantly clear, the IRA’s focus on stimulating domestic production of electric vehicles means that the marketplace for electric vehicles will see a dramatic change. The Biden Administration has set an ambitious target of 50% of EV sale shares in the U.S. by 2030. However, if electric vehicles are going to achieve mass market adoption, a central question remains — where is the infrastructure to support them?

Addressing gaps in EV Supply and EV Infrastructure

As it stands, the shortage of charging infrastructure is a substantial barrier in the push for mass consumer adoption of EVs.3 Experts estimate that in order to meet the Biden Administration’s EV sale target by 2030, America would require 1.2 million public EV chargers and 28 million private EV chargers by that year.4 Department of Energy data shows that approximately 50,000 EV public charging sites are currently operational in the United States.5 In comparison, gasoline fueling stations total more than 145,000.6 However, federal legislation such as the Bipartisan Infrastructure Law (“BIL”) passed earlier this year signifies a clear commitment to remedying this disparity. The BIL establishes a National Electric Vehicle Infrastructure Formula Program (“NEVI”) to provide funding to States and private entities to deploy EV-charging infrastructure and to establish an interconnected network to facilitate “data collection, access and reliability.”7 The Federal Highway Administration, the federal agency charged with implementing NEVI, proposed minimum standards and requirements that states must meet to spend NEVI funds:

  • Installation, operation and maintenance by qualified technicians of EV infrastructure

  • Interoperability of EV charging infrastructure

  • Network connectivity of EV charging infrastructure

  • Data collection pertaining to pricing, real-time availability and accessibility8

The goal of the proposed rule is to secure EV charging infrastructure that works seamlessly for industrial, commercial and consumer drivers. Combining the historic investments in clean energy and climate infrastructure in the BIL and IRA, the federal government has jumpstarted what will be a fundamental shift in how consumers use transportation. Earlier this week, the Biden Administration announced more than two-thirds of EV Infrastructure Deployment Plans from States, the District of Columbia and Puerto Rico have been approved ahead of schedule under NEVI.9 With this early approval, these states can now unlock more than $900 million in NEVI funding from FY22 and FY23 to help build EV chargers across highways throughout the country.10

Section 13404’s Alternative Fuel Refueling Property Credit

Building up the U.S. capacity to build EVs, and then ensuring people can use said vehicles more easily by shoring up EV infrastructure is a crucial facet of the Inflation Reduction Act. Section 13404 of the IRA provides an Alternative Fuel Refueling Property Credit that targets the accelerated installation of EV charging infrastructure and assets.11 Section 13404 extends existing alternative fuel vehicle refueling property credit through 2032, and significantly restructures the credit by allowing taxpayers to claim a base credit of 6% for expenses up to $100,000 (for each piece refueling property located at a given facility) so long as the property is placed in service before Jan. 1, 2033.12 However, the alternative fuel property must be manufactured for use on public streets, roads and highways, but only if they are (1) intended for general public use, or (2) intended for exclusive use by government or commercial vehicles and (3) must be located in a qualifying census tract (i.e., low-income communities or non-urban areas).13 From a job creation standpoint, the IRA also provides an alternative bonus credit for taxpayers that meet certain wage requirements during the construction phase.14

The Future of EV Infrastructure

EV stations in city streets, parking garages and gas stations will become a prominent part of the nation’s infrastructure as it moves towards a green future. The effort will require coordination among municipal, state and federal policymakers. Even more, electric utilities must ensure that local infrastructure can support the additional strain on the grid. Utilities also have a direct interest in a cleaner, efficient, and less overburdened grid. Federal tax incentives, like the IRA, and subsides from states and local ordinances are integral to the implementation and construction of these networks. The private sector has already taken steps to do its part. In a recent study conducted by consulting company AlixPartners, as of June 2022, automakers and suppliers expect to invest at least $526 billion to fund the transition from gasoline powered vehicles to EVs through 2026.15 This is double the five-year EV investment forecast of $234 billion from 2020-2024.16 Even more, according to Bloomberg, not including deals that have disclosed financials, more than $4.8 billion has already been invested in the EV charging industry this year in the form of debt financing and acquisitions.17 Driven by fast growth and robust availability of government funds, financiers and large companies seeking to acquire EV charging companies, sense immense opportunity.18

FOOTNOTES

1“Electric Vehicle” is used interchangeably with the acronym “EV” throughout this article.

2 Isaacs-Thomas, I. (2022, August 11). What the Inflation Reduction act does for green energy. PBS. https://www.pbs.org/newshour/science/what-the-inflation-reduction-act-do…

3 Consumer Reports (2022, April). Breakthrough Energy: A Nationally Representative Multi-Mode Survey. https://article.images.consumerreports.org/prod/content/dam/surveys/Cons…

4 Kampshoff, P., Kumar, A., Peloquin, S., & Sahdev, S. (2022, August 31). Building the electric-vehicle charging infrastructure America needs. McKinsey & Company. https://www.mckinsey.com/industries/public-and-social-sector/our-insight…

5 U.S Department of Energy. (2022). Alternative Fueling Station Locator. Alternative Fuels Data Center: Alternative Fueling Station Locator. https://afdc.energy.gov/stations/#/find/nearest?fuel=ELEC&ev_levels=all&…

6 American Petroleum Institute. (n.d.). Service station FAQs. Energy API. https://www.api.org/oil-and-natural-gas/consumer-information/consumer-re…

7 U.S. Department of Transportation/Federal Highway Administration. (n.d.). Bipartisan Infrastructure Law – National Electric Vehicle Infrastructure (NEVI) formula program fact sheet: Federal Highway Administration. U.S. Department of Transportation/Federal Highway Administration. https://www.fhwa.dot.gov/bipartisan-infrastructure-law/nevi_formula_prog…

8 The Office of the Federal Register of the National Archives and Records Administration and the U.S. Government Publishing Office. (2022, June 22). National Electric Vehicle Infrastructure Formula Program. Federal Register. https://www.federalregister.gov/documents/2022/06/22/2022-12704/national…

9 United States Department of Transportation. (2022, September 14). Biden-Harris Administration announces approval of First 35 state plans to build out EV charging infrastructure across 53,000 miles of Highways. United States Department of Transportation. https://highways.dot.gov/newsroom/biden-harris-administration-announces-…

10 See Id.

11 As a note, “refueling property” is property used for the storage or dispensing of clean-burning fuel or electricity into the vehicle fuel tank or battery.  Clean-burning fuels include CNG, LNG, electricity, and hydrogen.

12 Inflation Reduction Act of 2022, H.R. 5376, 117th Cong. § 13404 (2022); See also Wells Hall III, C., Holloway, M. D., Wagner, T., & Baldwin, E. (2022, August 10). Nelson Mullins tax report–Senate passes Inflation Reduction Act. Nelson Mullins Riley & Scarborough LLP. https://www.nelsonmullins.com/idea_exchange/alerts/additional_nelson_mul…

13  Id.

14  Id.

15 AlixPartners, LLP. (2022, June 22). 2022 Alixpartners global automotive outlook. AlixPartners. https://www.alixpartners.com/media-center/press-releases/2022-alixpartne… See also Lienert, P. (2022, June 22). Electric vehicles could take 33% of global sales by 2028. Reuters. https://www.reuters.com/business/autos-transportation/electric-vehicles-…

16 Id.

17 Fisher, R. (2022, August 16). Electric car-charging investment soars driven by EV Growth, government funds. Bloomberg. https://www.bloomberg.com/news/articles/2022-08-16/car-charging-investme…

18 Id.

Article By Lawrence L. Ostema and Jeffrey E. Joseph of Nelson Mullins

For more utilities and transportation legal news, click here to visit the National Law Review.

Copyright ©2022 Nelson Mullins Riley & Scarborough LLP

Draft SEC Five-Year Strategic Plan Emphasizes Importance of Climate Disclosures

Recently, the SEC issued its five-year strategic plan for public comment.  This strategic plan covers a wide variety of topics, ranging from adapting to new technology to plans for increasing internal SEC workforce diversity.  Significantly, this draft strategic plan stated that “the SEC must update its disclosure framework,” and highlighted three areas in which it should do so: “issuers’ climate risks, cybersecurity hygiene policies, and their most important asset: their people.”

The SEC has already undertaken steps to enact these proposed updates to its disclosure requirements for public companies.  Notably, this past March it proposed draft climate disclosure rules, which provoked a significant response from the public–including widespread criticism from many companies (as well as praise from environmental organizations).  The fact that the SEC chose to highlight these rules in its (draft) five-year strategic plan indicates the depth of the commitment it has made to these draft climate disclosures, and further suggests that the final form of the climate disclosures is unlikely to be significantly altered in substance from what the SEC has already proposed.  This statement reinforces the commitment of Chairman Gensler’s SEC and the Biden Administration to financial disclosures as a method to combat climate change.

“The markets have begun to embrace the necessity of providing a greater level of disclosure to investors. From time to time, the SEC must update its disclosure framework to reflect investor demand. Today, investors increasingly seek information related to, among other things, issuers’ climate risks, cybersecurity hygiene policies, and their most important asset: their people. In order to catch up to that reality, the agency should continue to update the disclosure framework to address these areas of investor demand, as well as continue to take concrete steps to modernize the systems that support the disclosure framework, to make public disclosures easier to access and analyze and thus more decision-useful to investors. . . . Across the agency, the SEC must continually reassess its risks, including in new areas such as climate risk, and document necessary controls.”

Article By Jacob H. Hupart of Mintz

For more environmental legal news, click here to visit the National Law Review.

©1994-2022 Mintz, Levin, Cohn, Ferris, Glovsky and Popeo, P.C. All Rights Reserved.

The Inflation Reduction Act: How Do Tribal Communities Benefit?

On August 16, 2022, President Biden signed into law the Inflation Reduction Act of 2022 (“IRA”), ushering in substantial changes for tax law, climate resilience, healthcare, and more in the United States. According to the Biden administration’s press release, the new $750 billion legislation aims to lower everyday costs for families, insist that corporations pay their fair share, and combat the climate crisis. During the signing ceremony, President Biden stated, “With this law, the American people won and the special interests lost […] For a while people doubted whether any of that was going to happen, but we are in a season of substance.”

Notably, the legislation provides significant provisions for tribal communities and the Bureau of Indian Affairs. Once the funding is appropriated by Congress, it will be directed toward drought mitigation programs, fish hatcheries, modernization of electric systems, and more for Native communities, including ones in Alaska and Hawaii.

How the Inflation Reduction Act of 2022 Supports the Environment and Tribal Communities

The Inflation Reduction Act of 2022 contains an array of provisions, including the reduction of drug prices, the lowering of energy costs, and, notably, federal infrastructure investments that benefit Native communities. Andrew M. VanderJack and Laura Jones, Co-Coordinators of Van Ness Feldman’s Native Affairs Practice, highlight the most significant facets of the bill: “This legislation provides some opportunities specifically for tribes and tribal entities, including programs related to climate resiliency and adaptation, electrification, and drought relief. For example, the Emergency Drought Relief program for Tribes extends direct financial assistance to tribal governments to address drinking water shortages and to mitigate the loss of tribal trust resources.”

Pilar Thomas, Partner in Quarles & Brady’s Energy, Environment & Natural Resources Practice Group, expanded on the most significant inclusions for Tribes: “[…] the creation of a Direct Pay tax credit payment program that allows Tribes to receive a payment equal to the clean energy technology tax credits – especially for solar, wind, storage, geothermal and EV charging stations; […] direct funding for electrification and climate resiliency through DOI and USDA; […] access to the greenhouse gas reduction fund, environmental and climate justice grants; and expanded energy efficiency tax benefits and rebates for tribes and tribal members.”

“Tribal governments are also eligible to apply for other programs such as the Clean Vehicle Credit program, the Energy Efficient Commercial Buildings Deduction, and the State and Private Forestry Conservation Programs,” noted Mr. VanderJack and Ms. Jones.

How the 2022 Inflation Reduction Act Has Been Received by Tribal Communities

The 2022 Inflation Reduction Act has received a warm reception from groups such as the National Indian Health Board and Native Organizers Alliance, who laud the bill’s potential to improve environmental, medical, and economic conditions for tribal communities, some of whom still lack access to electricity or clean water. The increase in funding will allow tribes to use green energy technology to increase climate resilience and decrease individual energy costs, while reducing the effects of environmental racism with risk assessments for drinking water and climate hazards. These infrastructural changes will stimulate economic development by creating new jobs. “With critical investments in the Inflation Reduction Act, we’re making sure the federal government steps up to support Native-driven climate resilience, advance tribal energy development, and fulfill its trust responsibility to Native communities,” said Senator and Senate Committee on Indian Affairs Chairman Brian Schatz.

“This legislation will result in hundreds of millions of funding available for Tribes, and non-profits that work with tribes and tribal communities to support the clean energy transition for tribal communities, reduce energy costs for tribal members, and create jobs,” said Ms. Thomas of Quarles & Brady. “The IRA will provide a substantial down payment for every tribe to take advantage of clean energy technologies, energy efficiency and energy savings, and climate resilient solutions for their communities and tribal members individually.  The new projects, technology implementation and economic development opportunities are substantial and will create long term community and economic development sustainable improvements in tribal communities.”

Some groups feel that the new legislation does not go far enough. In an open letter to President Biden, Senate Majority Leader Chuck Schumer, and House Speaker Nancy Pelosi, Indigenous-led advocacy organization NDN Collective argued that Congress’ hesitance to fully reject fossil fuels undermines the stated goals of addressing climate change, a misstep that could disproportionately affect tribal communities at the frontlines of the environmental crisis. “We believe that moving away from investments in the fossil fuel and other extractive industries and reallocating the funding to further research and development will help us find the solutions we need for true decarbonization and large-scale equitable carbon emissions reductions,” the collective stated. “We are already aware of innovative, Indigenous-led solutions that just need the proper funding and support to be scaled and replicated.”

Challenges in Getting the 2022 Inflation Reduction Act Passed

Up to this point, the Inflation Reduction Act has faced significant challenges in Congress. The legislation is the product of extensive compromise over the Build Back Better Act within the Democratic party. The Build Back Better Bill was initially estimated to cost over $3 trillion, and ultimately, the Inflation Reduction Act was passed with a budget of $750 billion. Senator Joe Manchin of West Virginia held back his support of the bill until late July, and Republicans successfully blocked an aspect of the bill that would have capped the price of insulin for Americans with private health insurance. When presented to Congress, the vote was split by party lines with every Republican voting against the bill. Biden has criticized Republicans for this decision, saying at the signing of the Inflation Reduction Act, “every single Republican in the Congress sided with the special interests in this vote — every single one.”

Challenges for tribal governments remain as well, specifically concerning the IRA’s implementation. “Despite the incredible opportunity for tribes, major barriers remain including tribal internal capacity and capabilities, [and] federal regulatory hurdles (such as BIA leasing and easement approvals),” said Ms. Thomas.

“[…] Navigating the complexities of each program and actually obtaining funding is always the challenge,” said Mr. VanderJack and Ms. Jones of Van Ness Feldman. “Tribes and tribal entities should engage directly, whenever possible, with the grant funding agencies to make sure proposals are tailored to fit both program requirements and community needs.”

Early Assessment of How the IRA will Impact Tribal Communities

The Inflation Reduction Act, ultimately, provides meaningful resources and investments for tribal communities in a variety of ways. While the provisions are not as significant as COVID-19 relief and infrastructure funding that tribal governments have received in previous years, the new legislation is nonetheless beneficial. “While the federal grant funding is relatively small, the potential major impact is the ability to access funding through tax credit payments and rebates,” said Ms. Thomas. “This mechanism is critical as it is simplifies tribes’ access to funding (rather than, for example, seeking to obtain funding through the competitive grant programs).”

Article By Chandler Ford, Casey Karthaus, Crissonna Tennison, and Shelby Garrett of The National Law Review / The National Law Forum LLC.

For more tribal law / indigenous peoples legal news, click here to visit the National Law Review.

Copyright ©2022 National Law Forum, LLC

CERCLA PFAS Designation Major Step Forward

On January 10, 2022, the EPA submitted a plan for a PFAS Superfund designation to the White House Office of Management and Budget (OMB) when it indicated an intent to designate two legacy PFAS – PFOA and PFOS – as “hazardous substances” under the Comprehensive Environmental Response, Compensation & Liability Act (CERCLA, also known as the Superfund law). The EPA previously stated its intent to make the proposed designation by March 2022 when it introduced its PFAS Roadmap in October 2021. Under the Roadmap, the EPA planned to issue its proposed CERCLA designation in the spring of 2022. On Friday, a CERCLA PFAS designation took a significant step forward when the OMB approved the EPA’s plan for PFOA and PFOS designation. This step opens the door for the EPA to put forth its proposed designation of PFOA and PFOS under CERCLA and engage in the required public comment period.

Any PFAS designation will have enormous financial impacts on companies with any sort of legacy or current PFOA and PFOS pollution concerns. Corporations, insurers, investment firms, and private equity alike must pay attention to this change in law when considering risk issues.

Opposition to CERCLA Designation

Since the EPA’s submission of its intent to designate PFOA and PFOS as hazardous substance to the OMB, the EPA has been met with industry pushback on the proposal. Three industries met with the OMB earlier in 2022 to explain the enormity of regulatory and cleanup costs that the industries would face with a CERCLA designation of PFOA and PFOS – water utilities, waste management companies, and the International Liquid Terminals Association. These industries in particular are concerned about bearing the burden of enormous cleanup costs for pollution that third parties are responsible for. Industries are urging the OMB and EPA to consider other ways to achieve regulatory and remediation goals aside from a CERCLA designation.

During an April 5, 2022 meeting of the Environmental Council of the States (ECOS), several states also expressed concerns regarding the impact that a CERCLA designation for PFAS types would have in their states and on their constituent companies. The state environmental leaders discussed with EPA representatives how the EPA would view companies in their states that fall into categories such as waste management and water utilities, who are already facing uphill battles in disposing of waste or sludge that contains PFAS.

Realizing that the EPA is likely set on its path to designate at least two PFAS as “hazardous substances”, though, industries are asking the EPA to consider PFAS CERCLA exemptions for certain industries, which would exempt certain industry types from liability under CERCLA. Industries are also pushing the EPA, OMB and the U.S. Chamber of Commerce to conduct a robust risk analysis to fully vet the impact that the designation will have on companies financially. The EPA is statutorily required to conduct a risk analysis as part of its CERCLA designation process, so it is likely that the EPA’s delay in issuing a proposed hazardous substance designation until it feels that adequate time has passed for its designation to survive the likely legal challenges that will likely follow the designation.

CERCLA PFAS Designation: Impact On Businesses

Once a substance is classified as a “hazardous substance” under CERCLA, the EPA can force parties that it deems to be polluters to either cleanup the polluted site or reimburse the EPA for the full remediation of the contaminated site. Without a PFAS Superfund designation, the EPA can merely attribute blame to parties that it feels contributed to the pollution, but it has no authority to force the parties to remediate or pay costs. The designation also triggers considerable reporting requirements for companies. Currently, those reporting requirements with respect to PFAS do not exist, but they would apply to industries well beyond just PFAS manufacturers.

The downstream effects of a PFOA and PFOS designation would be massive. Companies that utilized PFOA and PFOS in their industrial or manufacturing processes and sent the PFOA/PFOS waste to landfills or otherwise discharged the chemicals into the environment will be at immediate risk for enforcement action by the EPA given the EPA’s stated intent to hold all PFAS polluters of any kind accountable. Waste management companies should be especially concerned given the large swaths of land that are utilized for landfills and the likely PFAS pollution that can be found in most landfills due to the chemicals’ prevalence in consumer goods. These site owners may be the first targeted when the PFOA/PFOS designation is made, which will lead to lawsuits filed against any company that sent waste to the landfills for contribution to the cost of cleanup that the waste management company or its insured will bear.

Also of concern to companies are the re-opener possibilities that a CERCLA designation would result in. Sites that are or were previously designated as Superfund sites will be subject to additional review for PFOA/PFOS concerns. Sites found to have PFOA/PFOS pollution can be re-opened by the EPA for investigation and remediation cost attribution to parties that the EPA finds to be responsible parties for the pollution. Whether through direct enforcement action, re-opener remediation actions, or lawsuits for contribution, the costs for site cleanup could amount to tens of millions of dollars, of course depending on the scope of pollution.

Conclusion

Now more than ever, the EPA is clearly on a path to regulate PFAS contamination in the country’s water, land and air. The EPA has also for the first time publicly stated when they expect such regulations to be enacted. These regulations will require states to act, as well (and some states may still enact stronger regulations than the EPA). Both the federal and the state level regulations will impact businesses and industries of many kinds, even if their contribution to drinking water contamination issues may seem on the surface to be de minimus. In states that already have PFAS drinking water standards enacted, businesses and property owners have already seen local environmental agencies scrutinize possible sources of PFAS pollution much more closely than ever before, which has resulted in unexpected costs. Beyond drinking water, though, the EPA PFAS plan shows the EPA’s desire to take regulatory action well beyond just drinking water, and companies absolutely must begin preparing now for regulatory actions that will have significant financial impacts down the road.

Article By John Gardella of CMBG3 Law

For more energy and environmental legal news, click here to visit the National Law Review.

©2022 CMBG3 Law, LLC. All rights reserved.

Relief Arrives for Renewable Energy Industry – Inflation Reduction Act of 2022

On August 12, 2022, Congress passed the Inflation Reduction Act of 2022 (“Act” or “IRA”), a $400 billion legislative package containing significant tax and other governmental incentives for the energy industry, in particular the renewable energy industry. The bill will have an immediate impact on the wind and solar industries, along with other clean energy projects and businesses.

SUMMARY

The IRA is a slimmed down substitute for the Build Back Better bill resulting from a compromise with Senator Joe Manchin (D-WV), whose support was necessary for the bill to pass the Senate.

The IRA comes as welcome news to the renewable energy industry as important tax incentives for wind, solar and other renewable energy resources are set to expire or wind down. Existing law also did not provide any federal tax incentives for the rapidly growing stand-alone energy storage and clean hydrogen industries.

The IRA fixes that, and more. The Act extends the investment tax credit (ITC) for solar, geothermal, biogas, fuel cells, waste energy recovery, combined heat and power, small wind property, and microturbine and microgrid property for projects beginning construction before January 1, 2025. It also extends the production tax credit (PTC) for wind, biomass, geothermal, solar (which previously expired at the end of 2005), landfill gas, municipal solid waste, qualified hydropower, and marine and hydrokinetic resources for projects beginning construction before January 1, 2025. The IRA also allows taxpayers to include their interconnection costs as part of their eligible basis for the ITC.

The Act now allows the ITC to be taken for stand-alone energy storage (previously storage was only allowed an ITC if it was part of another project, e.g., solar). Other technologies are also benefitted from the IRA, including carbon capture and sequestration (CCS) (tax credit extended and modified), clean hydrogen (a new credit of up to $3.00 per kilogram of clean hydrogen produced), nuclear power (a new credit of up to 1.5c/kWh) and biofuel (existing credit extended).

The ITC and PTC now come with strings attached. To qualify for the restored 30% ITC and the 2.6c/kWh PTC (adjusted for inflation), projects must pay prevailing wages during construction and the first five years (in the case of the ITC) and 10 years (in the case of the PTC) of operation, while also meeting registered apprenticeship requirements. Projects that fail to satisfy the prevailing wage and apprenticeship requirements will only receive an ITC of 6% or a PTC of .3c/kWh (adjusted for inflation). The prevailing wage and apprenticeship requirements apply to employees of contractors and subcontractors as well as the company. These requirements are effective for projects that begin construction 60 days after the IRS issues additional guidance on this issue. Certain exceptions apply, including for certain small (less than 1 MW) facilities.

On the flip side, the Act includes enhancements that, in the case of the ITC, can increase the credit percentage if a project satisfies certain additional criteria. Bonuses are available for projects that (1) satisfy certain U.S. domestic content requirements (10%) or (2) are located in an “energy community” (10%) or an “environmental justice” area (10% or 20%). An “energy community” is defined as a brownfield site, an area which has or had significant employment related to oil, gas, or coal activities, or a census tract or any adjoining tract in which a coal mine closed after December 31, 1999, or in which a coal-fired electric power plant was retired after December 31, 2009. An “environmental justice” area is a low-income community or Native American land (defined in the Energy Policy Act of 1992) (10%) or a low-income residential building or qualified low-income economic benefit project (20%).

The Act also creates two new methods for monetizing the ITC, PTC, and certain other credits. Tax-exempt organizations will be permitted to elect a “direct pay” option in lieu of a tax credit. In a dramatic change that may have substantial impacts on renewable project finance, the Act permits most taxpayers to transfer the ITC, PTC, and certain other tax credits for cash.

For the first time, the Act includes a tax credit, known as the Advanced Manufacturing Production Credit, for companies manufacturing clean energy equipment in the U.S. such as PV cells, PV wafers, solar grade polysilicon, solar modules, wind energy components, torque tubes, structural fasteners, electrode active materials, battery cells, battery modules, and critical minerals.

The Act also contains major tax incentives, in the form of credits and enhanced deductions to spur electric and hydrogen-fueled vehicles, alternative fuel refueling stations, nuclear power, energy efficiency, biofuels, carbon sequestration and clean hydrogen. Additional grants are available for interregional and offshore wind and electricity transmission projects, including for interconnecting offshore wind farms to the transmission grid.

Additional detail regarding these provisions follow below.

KEY ENERGY PROVISIONS OF THE INFLATION REDUCTION ACT OF 2022

Investment Tax Credit (ITC)

The ITC is extended for projects beginning construction prior to January 1, 2025. The ITC starts at a base rate of 6%. The ITC increases to 30% if a project (1) pays prevailing wages during the construction phase and for the first five years of operation and (2) meets registered apprenticeship requirements. The ITC applies to solar, fuel cells, waste energy recovery, geothermal, combined heat and power, and small wind property, and is now expanded to include stand-alone energy storage projects (including thermal energy storage), qualified biogas projects such as landfill gas, electrochromic glass, and microgrid controllers. For microturbine property the base rate is 2%, which increases to 10% if the prevailing wage and apprenticeship requirements are met.

Projects under one megawatt (AC) and projects that begin construction prior to 60 days after the Secretary of the Treasury publishes guidance on the wage and registered apprenticeship requirements do not have to meet the prevailing wage and apprenticeship requirements to qualify for the 30% ITC.

PREVAILING WAGE REQUIREMENT

The new prevailing wage requirement is intended to ensure that laborers and mechanics employed by the project company and its contractors and subcontractors for the construction, alteration or repair of qualifying projects are paid no less than prevailing rates for similar work in the locality where the facility is located. The prevailing rate will be determined by the most recent rates published by the U. S. Secretary of Labor. Prevailing wages for the area must be paid during construction and for the first five years of operation for repairs or alterations once the project is placed in service. Failure to satisfy the standard will result in a significant penalty, including an 80% reduction in the ITC (i.e., an ITC of 6%), remittance of the wage shortfall to the underpaid employee(s) and a $5,000 penalty per failure. For intentional disregard of the requirement the penalty increases to three times the wage shortfall and $10,000 penalty per employee.

The prevailing wage requirement takes effect for projects that begin construction after December 31, 2022, but not before 60 days after the Secretary publishes its guidance. Projects under 1 MW (AC) are exempt from the requirement.

APPRENTICESHIP REQUIREMENT

For projects with four or more employees, work on the project by contractors and subcontractors must be performed by qualified apprentices for the “applicable percentage” of the total number of labor hours. A qualified apprentice is an employee who participates in an apprenticeship program under the National Apprenticeship Act. The applicable percentage of labor hours phases in and is equal to 10% of the total labor hours for projects that begin construction in 2022, 12.5% for projects beginning construction in 2023, and 15% thereafter. Similar penalties to the prevailing wage penalties apply for failure to satisfy the apprenticeship requirement. A “good faith” exception applies where an employer attempts but cannot find apprentices in the project’s locality.

The apprenticeship requirement takes effect for projects that begin construction after December 31, 2022, but not before 60 days after the Secretary publishes its relevant guidance. Projects under 1 MW (AC) are exempt from the requirement.

Credit Enhancements

Domestic Content. Assuming a project meets the prevailing wage and apprenticeship requirements, a qualifying project can earn a 10% ITC bonus (i.e., bringing the ITC to 40%), if it satisfies the domestic content requirement. To satisfy the domestic content requirement a project must use 100% U.S. steel and iron, and an “adjusted percentage” of the total costs of its manufactured components with products that are mined, produced or manufactured in the U.S. The applicable percentage for projects other than for offshore wind facilities initially is set at 40%, increasing to 45% in 2025, 50% in 2026, and 55% in 2027. For offshore wind facilities the adjusted percentage initially is 20%, and phases up to 27.5% in 2025, 35% in 2026, 45% in 2027, and 55% in 2028 and after. The initial domestic content bonus for projects failing to meet the prevailing wage and apprenticeship requirement is 2%, which percentage similarly phases up.

Two exceptions exist to the domestic content requirement: (1) if the facility is less than 1 MW (AC) and (2) if satisfying the requirement will increase the overall cost of construction by more than 25 percent, or if the relevant products are not produced in the U.S. in sufficient and reasonably available quantities or quality. Under these circumstances, the unavailability of the product is counted 100% against the adjusted percentage, that is, the adjusted percentage is calculated as if 100% U.S. content was supplied for the unavailable items.

The domestic content bonus is only available for projects placed in service after December 31, 2022.

Energy Community Bonus. A project can earn an additional 10% ITC bonus if it is built in an energy community. An energy community is defined as (a) a brownfield site (as defined under CERCLA), (b) an area that has or had significant employment related to the coal, oil, or gas industry and has an unemployment rate at or above the national average, or (c) a census tract or adjoining tract in which a coal mine closed after December 31, 1999 or a coal-fired electric power plant was retired after December 31, 2009.

The Energy Community Bonus is only available for projects placed in service after January 1, 2023.

Environmental Justice. An additional 10% and, in some cases, 20% ITC bonus, is available for solar and wind projects of 5 MW AC or less where the project is located in, or services, a low-income community. The environmental justice bonus is limited to a maximum of 1.8 gigawatts of solar and wind capacity in each of calendar years 2023 and 2024, for which a project must receive an allocation from the U.S. Treasury Secretary. The 10% bonus is for projects located in a low-income community or on Native American land (defined in the Energy Policy Act of 1992). The 20% bonus is available for projects that are part of a qualified low-income residential building project or a qualified low-income economic benefit project. A qualified low-income residential project is a residential rental building that participates in a housing program such as those covered under the Violence Against Women Act of 1994, a housing assistance program administered by the Department of Agriculture under the Housing Act of 1949, a housing program administered under the Native American Housing Assistance and Self-Determination Act of 1996, or similar affordable housing programs. A qualified low-income economic benefit project is one where at least 50% of the households have income at less than 200% of the poverty line or at less than 80% of the area’s median gross income.

Storage projects installed in connection with a solar project also qualify for the environmental justice bonus, but not stand-alone storage projects. A project receiving an allocation for the environmental justice credit must be placed in service within four years of the date it receives the allocation.

Stand-Alone Storage. The Act now provides a tax credit for stand-alone energy storage projects. To qualify, the storage project must be capable of receiving, storing and delivering electrical energy and have a nameplate capacity of at least 5 kWh. Thermal storage projects and hydrogen storage projects qualify under the new provision. Like the ITC for other technologies, the base ITC for stand-alone storage is 6%, and increases to 30% for projects that satisfy the prevailing wage and apprenticeship requirements or if they are placed into service prior to 60 days after the Treasury Secretary issues guidance on prevailing wage and apprenticeship standards.

Interconnection Equipment. Qualifying projects under 5 MW (AC) now may claim an ITC on their interconnection costs. The credit applies even if the interconnection facilities are owned by the interconnecting utility, so long as they were paid for by the taxpayer. This is not a stand-alone tax credit, but rather an additional cost added to a project’s basis eligible for the ITC.

Production Tax Credit (PTC)

The Act extends the production tax credit (PTC) for projects beginning construction before January 1, 2025. The PTC is set at an initial Base Rate of .3c/kwh. Like the ITC, the credit increases to 1.5c/kwh for projects satisfying the prevailing wage and apprenticeship requirements. The 1.5 c/kWh, with the inflationary adjustment provided for the PTC, brings the PTC up to 2.6c/kWh in 2022. In addition to wind projects, the PTC is available to solar, closed-loop and open-loop biomass, geothermal, landfill gas, municipal solid waste, qualifying hydropower, and marine and hydrokinetic facilities. Thus, solar projects may now choose either the PTC or the ITC. They cannot receive both.

CREDIT ENHANCEMENTS

Like the ITC, a project can receive an enhanced PTC similar in degree to those under the ITC for satisfying the domestic content, energy community and/or environmental justice requirements. For projects meeting the prevailing wage and apprenticeship requirements the increase for each applicable bonus is generally 10% of the underlying credit and, for projects failing to satisfy those requirements, 2%.

Clean Electricity Investment Tax Credit

The Act creates a new clean electricity tax credit (ITC and PTC) that replaces the existing ITC and PTC once they phase out at the end of 2024. The successor ITC/PTC is technology neutral. Any project producing electricity can qualify for the tax credit if its greenhouse gas emissions rate is not greater than zero. The successor ITC is 30% and the PTC is 1.5c/kWh, escalated annually with inflation. The Clean Energy ITC/PTC will phase out the later of 2032 or when emission targets are achieved (i.e., the electric power sector emits 75% less carbon than 2022 levels). Once the target is reached, facilities will be able to claim a credit at 100% value in the first year, then 75%, then 50%, and then 0%.

Clean Hydrogen Production Credit

This Act for the first time provides a tax credit for qualifying clean hydrogen projects. The credit is available for clean hydrogen produced at a qualifying facility during the facility’s first 10 years of operation. The base credit amount is $0.60 per kilogram (kg) times the “applicable percentage,” adjusted annually for inflation. For projects meeting the prevailing wage and apprenticeship requirements the credit amount is five times that base amount, or $3.00/kg times the applicable percentage, adjusted annually for inflation.

The applicable percentage for hydrogen projects achieving a lifecycle greenhouse gas emissions rate of less than 0.45 kilograms of carbon dioxide equivalent (CO2e) per kg is 100%. The applicable percentage falls to 33.4% for hydrogen projects with an emissions rate between .45kg and 1.5kg, and to 25% for hydrogen projects with an emissions rate between 1.5 kg and 2.5 kg. For hydrogen projects with a lifecycle greenhouse gas emissions rate between 4 kg and 2.5 kg of CO2e per kg, the applicable percentage is 20%.

To qualify for the credit, the facility must begin construction before January 1, 2033. Facilities existing before January 1, 2023 can qualify for a credit based on the date that modifications to their facility required to produce clean hydrogen are placed into service. Taxpayers may also claim the PTC for electricity produced from renewable resources by the taxpayer if the electricity is used at a clean hydrogen facility to produce qualified clean hydrogen. The Direct Pay option, discussed below, is available for clean hydrogen projects.

Taxpayers can elect to claim the ITC in lieu of the clean hydrogen production credit. However, taxpayers claiming the clean hydrogen credit cannot also claim a tax credit for carbon capture under Section 45Q, and vice versa.

Carbon Capture and Sequestration (CCS) Credit

Under prior law, industrial carbon capture or direct air capture (DAC) facilities that began construction by December 31, 2025, could qualify for the Section 45Q tax credit for carbon oxide sequestration. This credit could be claimed for carbon oxide captured during the 12-year period following the facility being placed in service. The per metric ton tax credit for geologically sequestered carbon oxide was set to increase to $50 per ton by 2026 ($35 per ton for carbon oxide that is reused, such as for enhanced oil recovery) and adjusted for inflation thereafter.

The Act extends the deadline for construction to January 1, 2033 and increases the credit amount. The base credit amount for CCS is $17 per metric ton for carbon oxide that is captured and geologically sequestered, and $12 per metric ton for carbon oxide that is reused. For facilities that meet the prevailing wage and apprenticeship requirements during construction and for the first 12 years of operation, the credit amounts are $85 per ton and $60 per ton, respectively.

The credit amount for carbon oxide captured using DAC and geologically sequestered is also increased under the Act to a base rate of $36 per metric ton, and to $180 per metric ton for projects that meet prevailing wage and apprenticeship requirements. The rates are indexed for inflation beginning in 2026.

The Act reduces the minimum plant size required to qualify for the credit:  from 100,000 to 1,000 tons per year for DAC; from 500,000 to 18,750 metric tons per year for electric generating facilities paired with qualifying CCS equipment, and from 25,000 to 12,500 metric tons per year for any other facility. A CCS project paired with an electric generating unit will be required to capture at least 75% of unit (not facility) CO2 production.

Advanced Energy Project Credit

The Act provides a 30% credit for investments in projects that re-equip, expend, or establish certain domestic manufacturing or industrial facilities to support the production or recycling of renewable energy property. Examples of such facilities include those producing or recycling components for:

  • Energy storage systems and components;
  • Grid modernization equipment or components;
  • Equipment designed to remove, use, or sequester carbon oxide emissions;
  • Equipment designed to refine, electrolyze, or blend any fuel, chemical, or product which is renewable or low-carbon and low-emission;
  • Property designed to produce energy conservation technologies (residential, commercial and industrial);
  • Electric or fuel-cell vehicles, including for charging and refueling infrastructure;
  • Hybrid vehicles weighing less than 14,000 pounds and associated technologies, components, or materials;
  • Re-equipping industrial and manufacturing facilities to reduce their greenhouse gas emissions by at least 20%;
  • Re-equipping, expanding, or establishing an industrial facility for the processing, refining or recycling of critical materials.

Projects not satisfying the prevailing wage and apprenticeship requirements will only receive the base ITC credit of 6%.

The Act makes $10 billion available for qualifying advanced energy projects. Of that amount, at least $4 billion must be allocated to projects located in energy communities. The Treasury Secretary will establish a program to award credits to qualifying advanced energy projects. Applicants awarded credits will have two years to place the property in service. The provision goes into effect on January 1, 2023.

Advanced Manufacturing Production

The Act creates a new production tax credit that can be claimed for the domestic production and sale of qualifying solar and wind components, such as inverters, battery components and critical minerals needed to produce these components.

Credits for solar components include:

  • for thin film photovoltaic cell or crystalline photovoltaic cell, 4 cents per DC watt of capacity;
  • for photovoltaic wafers, $12 per square meter;
  • for solar grade polysilicon, $3 per kilogram;
  • for polymeric backsheet, 40 cents per square meter; and
  • for solar modules, 7 cents per DC watt of capacity.

For wind energy components, if the component is an offshore wind vessel, the credit is equal to 10% of the sales price of the vessel. Otherwise, the credits for various wind components vary as set forth below, which amount is multiplied by the total rated capacity of the completed wind turbine on a per watt basis for which the component is designed.

The applicable amounts for wind energy components are:

  • 2 cents for blades
  • 5 cents for nacelles
  • 3 cents for towers
  • 2 cents for fixed platform offshore wind foundations
  • 4 cents for floating platform offshore wind foundations
  • for torque tubes and longitudinal purlin, $0.87 per kg
  • for structural fasteners, $2.28 per kg
  • for inverters, the credit is an amount multiplied by the inverter’s AC capacity, with different types of inverters eligible for specified credit amounts ranging from 1.5 cents to 11 cents per watt
  • for electrode active materials, the credit is 10% of the production cost
  • for battery cells the credit is $35 per kilowatt hour of battery cell capacity. Battery modules qualify for a credit of $10 per kilowatt hour of capacity (or $45 in the case of a battery module which does not use battery cells).

A 10% credit is also available for the production of critical minerals. Critical minerals include aluminum, antimony, barite, beryllium, cerium, cesium, chromium, cobalt, dysprosium, europium, fluorspar, gadolinium, germanium, graphite, indium, lithium, manganese, neodymium, nickel, niobium, tellurium, tin, tungsten, vanadium and yttrium.

For purposes of the credits for battery cells and modules, to qualify the capacity-to-power ratio cannot exceed 100:1. The term ‘capacity-to-power ratio’ means the ratio of the capacity of the cell or module to the maximum discharge amount of the cell or module.

The advanced manufacturing credit phases out for components sold after December 31, 2029. Components sold in 2030 are eligible for 75% of the full credit amount. Components sold in 2031 and 2032 are eligible for 50% and 25% of the full credit amount, respectively. No credit is available for components sold after December 31, 2032. The phase-out does not apply to the production of critical minerals.

DIRECT PAY

The Act contains a valuable cash payment option that allows certain organizations to treat certain tax credit amounts including, among others, the ITC, PTC, clean hydrogen, and carbon capture credits, as payments of tax and then receive a refund for that tax that is deemed paid. Under the so-called “direct pay” option, in lieu of receiving a tax credit, an eligible entity will be treated as if it had paid taxes in the amount of the credit, for which it can then receive a cash refund. Entities eligible for the direct pay option include tax-exempt organizations, state and local governments, Indian tribes (as defined in the Act), the Tennessee Valley Authority, and any Alaska Native Corporation. The direct pay option is subject to an annual election and must be claimed by a partnership or S corporation rather than its partners or S corporation shareholders. Refunds under the direct pay provisions are treated the same as tax credits for purposes of basis reduction, depreciation rules, and recapture.

For qualifying facilities electing direct pay that do not meet the domestic content requirements, a reduction applies for projects beginning construction in 2024 (90%) and 2025 (85%). Thereafter, the direct pay option will not be available for projects that do not satisfy the domestic content requirement.

TRANSFERRABLE CREDITS

The IRA allows eligible taxpayers that do not elect the direct pay option to transfer certain credits to unrelated taxpayers including, among others, the ITC, PTC, clean hydrogen, and carbon capture credits. The transferred credit must be exchanged for cash. Credits may only be transferred once. Carryforwards or carrybacks are not transferable. Payments made to the transferor of the credit are not taxable to the transferor, nor is the payment by the transferee to the transferor deductible to the transferee.

The credit period for transferred credits is 23 years (including three years for carrybacks). The credit must be used in earliest possible year of transferee. A 20% penalty may apply for both direct payments and transfers where excessive payments have occurred.

Zero Emission Nuclear Power Production Credit

The Act includes a new PTC for the production of electricity from an existing nuclear facility that was placed in service before the date of enactment of the Act. To qualify, the electricity from the facility must be produced and sold to an unrelated person after December 31, 2023. The credit terminates on December 31, 2032. The base PTC amount is 3 cents per kWh, but is increased five times if wage and apprenticeship requirements are met (to 1.5 cents per kWh), in each case adjusted annually for inflation and reduced by a reduction amount to the extent electricity from the plant is sold at a price over $0.025/kWh.

Electric Vehicles and Hydrogen-Fueled Cars

The Act includes a $7,500 credit for taxpayers purchasing new electric vehicles and a $4,500 tax credit for used ones. The Act eliminates the previous “per-manufacturer” limits that applied to the new vehicle credit, but imposes new domestic content and assembly requirements, as well as caps on the retail price of new vehicles, and the income of the taxpayers purchasing the vehicle.

The Act also sets aside financing and credits to promote electric vehicle manufacturing. It calls for $2 billion in grants to help convert existing auto manufacturing factories into ones that make electric vehicles and $20 billion of loans for new clean vehicle manufacturing facilities. The Act extends the credits to hydrogen-fueled cars in addition to EVs.

Alternative Fuel Refueling Property Credit

The Act revives the expired credit for alternative fuel refueling property (i.e., electric vehicle chargers), allowing it for property placed in service before December 31, 2032. The base credit is 6% of the cost of property, and is increased to 30% if wage and apprenticeship requirements are met. The previous $30,000 cap is also increased to $100,000.

OFFSHORE WIND

The IRA puts in place a 10-year window in which a lease for offshore wind development cannot be issued unless an oil and gas lease sale has also been held in the year prior and is not less than 60 million acres. The Act also withdraws the Trump administration’s moratorium on offshore wind leasing in the southeastern U.S. and eastern Gulf of Mexico.

GREEN BANK

The Act includes $27 billion toward a clean energy technology accelerator to support deployment of emission-reduction technologies, especially in disadvantaged communities. The EPA Administrator would be permitted to disburse $20 billion to “eligible recipients,” which are defined as non-profit green banks that “provide capital, including by leveraging private capital, and other forms of financial assistance for the rapid deployment of low- and zero-emission products, technologies, and services.

Clean Fuel Production Credit

The Act creates a new tax credit for domestic clean fuel production starting in 2025 and expires for transportation fuels sold after December 31, 2027. The tax credit is calculated as the applicable amount multiplied by the emissions factor of the fuel. The base credit is $0.20 per gallon of transportation fuel produced at a qualified facility and sold, which increases to $1.00 if prevailing wage requirements are met. The base credit is $0.35/gallon for sustainable aviation fuel, $1.75 if labor and wage requirements are satisfied. The emissions factor of the fuel may reduce the credit amount. The credits are adjusted for inflation. The credit cannot be claimed if other clean fuel credits are claimed, including clean hydrogen production.

Article By Kris J. Eimicke and Merrill Kramer of Pierce Atwood LLP

For more energy and environmental legal news, click here to visit the National Law Review.

©2022 Pierce Atwood LLP. All rights reserved.

EPA Updates Safer Chemical Ingredients List, Adding 22 Chemicals and Changing the Status of One Chemical

The U.S. Environmental Protection Agency (EPA) announced on August 11, 2022, that it updated the Safer Chemical Ingredients List (SCIL), “a living list of chemicals by functional-use class that EPA’s Safer Choice program has evaluated and determined meet the Safer Choice Standard.” EPA added 22 chemicals to the SCIL. EPA states that to expand the number of chemicals and functional-use categories on the SCIL, it encourages manufacturers to submit their safer chemicals for review and listing on the SCIL. In support of the Biden Administration’s goals, the addition of chemicals to the SCIL “incentivizes further innovation in safer chemistry, which can promote environmental justice, bolster resilience to the impacts of climate change, and improve water quality.” According to EPA, chemicals on the SCIL “are among the safest for their functional use.”

EPA also changed the status for one chemical on the SCIL and will remove the chemical from the list in one year “because of a growing understanding of the potential health and environmental effects.” According to EPA, the chemical was originally listed on the SCIL based on data from a closely related substance that EPA marked with a grey square earlier this year. EPA’s process for removing a chemical from the SCIL is first to mark the chemical with a grey square on the SCIL web page to provide notice to chemical and product manufacturers that the chemical may no longer be acceptable for use in Safer Choice-certified products. A grey square notation on the SCIL means that the chemical may not be allowed for use in products that are candidates for the Safer Choice label, and any current Safer Choice-certified products that contain this chemical must be reformulated unless relevant health and safety data are provided to justify continuing to list the chemical on the SCIL. EPA states that the data required are determined on a case-by-case basis. In general, data useful for making such a determination provide evidence of low concern for human health and environmental impacts. Unless information provided to EPA adequately justifies continued listing, EPA then removes the chemical from the SCIL 12 months after the grey square designation.

According to EPA, after this update is made, there will be 1,055 chemicals listed on the SCIL. EPA is committed to updating the SCIL with safer chemicals on a regular basis. EPA states that the SCIL is a resource that can help many different stakeholders:

  • Product manufacturers use the SCIL to help make high-functioning products that contain safer ingredients;
  • Chemical manufacturers use the SCIL to promote the safer chemicals they manufacture;
  • Retailers use the SCIL to help shape their sustainability programs; and
  • Environmental and health advocates use the SCIL to support their work with industry to encourage the use of the safest possible chemistry.

EPA’s Safer Choice program certifies products containing ingredients that have met the program’s rigorous human health and environmental safety criteria. The Safer Choice program allows companies to use its label on products that meet the Safer Choice Standard. The EPA website contains a complete list of Safer Choice-certified products.

Article By Lynn L. Bergeson and Carla N. Hutton of Bergeson & Campbell, P.C.

For more environmental legal news, click here to visit the National Law Review.

©2022 Bergeson & Campbell, P.C.

GAO Publishes Report on Technologies for PFAS Assessment, Detection, and Treatment

The U.S. Government Accountability Office (GAO) published a report on July 28, 2022, entitled Persistent Chemicals: Technologies for PFAS Assessment, Detection, and Treatment. GAO was asked to conduct a technology assessment on per- and polyfluoroalkyl substances (PFAS) assessment, detection, and treatment. The report examines the technologies for more efficient assessments of the adverse health effects of PFAS and alternative substances; the benefits and challenges of current and emerging technologies for PFAS detection and treatment; and policy options that could help enhance benefits and mitigate challenges associated with these technologies. GAO assessed relevant technologies; surveyed PFAS subject matter experts; interviewed stakeholder groups, including government, non-governmental organizations (NGO), industry, and academia; and reviewed key reports. GAO identified three challenges associated with PFAS assessment, detection, and treatment technologies:

  • PFAS chemical structures are diverse and difficult to analyze for health risks, and machine learning requires extensive training data that may not be available;
  • Researchers lack analytical standards for many PFAS, limiting the development of effective detection methods; and
  • The effectiveness and availability of disposal and destruction options for PFAS are uncertain because of a lack of data, monitoring, and guidance.

GAO developed the following three policy options that could help mitigate these challenges:

  • Promote research: Policymakers could support development of technologies and methods to more efficiently research PFAS health risks. This policy option could help address the challenge of limited information on the large number and diversity of PFAS, as well as a lack of standardized data sets for machine learning;
  • Expand method development: Policymakers could collaborate to improve access to standard reference samples of PFAS and increase the pace of method and reference sample development for PFAS detection. This policy option could help address the challenges of a lack of validated methods in media other than water, lack of analytical standards, and cost, which all affect researchers’ ability to develop new detection technologies; and
  • Support full-scale treatment: Policymakers could encourage the development and evaluation of full-scale technologies and methods to dispose of or destroy PFAS. This policy option could help address the challenges of cost and efficiency of disposal and destruction technologies and a lack of guidance from regulators.

GAO notes that these policy options involve possible actions by policymakers, which may include Congress, federal agencies, state and local governments, academia, and industry.

Article By Lynn L. Bergeson and Carla N. Hutton of Bergeson & Campbell, P.C.

For more environmental legal news, click here to visit the National Law Review.

©2022 Bergeson & Campbell, P.C.

PFAS Health Advisories Under Legal Attack…Again

On June 15, 2022, the EPA issued Health Advisories (HAs) for five specific PFAS, including PFOA and PFOS. On July 29, 2022, the American Chemistry Council filed a petition in the Court of Appeals for the District of Columbia challenging the validity of the EPA’s PFOA and PFOS HAs. The group alleges that the EPA did not follow proper procedure in setting the HAs and that the EPA’s determinations were scientifically flawed. The petition follows closely on the heels of a similar challenge to the EPA’s HA for GenX PFAS. Industries that will be impacted by upcoming EPA PFAS regulations will closely follow the petition as it makes its way through court, as it may provide predictive indicators of arguments that will unfold as the EPA’s PFAS regulations increase.

PFAS Health Advisories

In October 2021, the EPA released its PFAS Roadmap, which stated explicit goals and deadlines for over twenty action items specific to PFAS. As part of the Roadmap, the EPA pledged to re-assess the existing Health Advisories (HAs) for PFOA and PFOS, as well as establish HAs for PFBS and GenX chemicals. In June 2022, the EPA fulfilled its promise on all fronts when it set HAs for PFOA (interim), PFOS (interim), PFBS (final) and GenX (final). While not enforceable levels for PFAS in drinking water, the EPA’s PFAS Health Advisories are nevertheless incredibly significant for a variety of reasons, including influence on future federal and state drinking water limits, as well as potential impacts on future PFAS litigation.

The levels set by the EPA’s PFAS Health Advisories were as follows:

PFOA

.004 ppt

PFOS

.02 ppt

GenX

10 ppt

PFBS

2,000 ppt

Legal Challenge To PFAS Health Advisories

On July 13, 2022, The Chemours Company filed a petition challenging the validity of the EPA’s GenX HA. On July 29, 2022, the American Chemistry Council (ACC) followed suit and petitioned to have the EPA’s HAs for PFOA and PFOS vacated. In the petition, the ACC argues that the EPA circumvented procedural requirements in the Safe Drinking Water Act by setting interim HAs for PFOA and PFOS and that the EPA is improperly attempting to create enforcement standards for drinking water that are unattainable. While the HAs themselves are not enforceable, the ACC argues that the HAs are relied upon by states when they set their own drinking water standards and signal an EPA intent to set unachievably low levels of enforceable PFAS standards at the federal level. The ACC points to recent findings by the Science Advisory Board (SAB) that criticized the EPA’s reliance on the same studies and scientific articles upon which the HAs were based.

Conclusion

Now more than ever, the EPA is clearly on a path to regulate PFAS contamination in the country’s water, land and air. The EPA has also for the first time publicly stated when they expect such regulations to be enacted. These regulations will require states to act, as well (and some states may still enact stronger regulations than the EPA). Both the federal and the state level regulations will impact businesses and industries of many kinds, even if their contribution to drinking water contamination issues may seem on the surface to be de minimus. In states that already have PFAS drinking water standards enacted, businesses and property owners have already seen local environmental agencies scrutinize possible sources of PFAS pollution much more closely than ever before, which has resulted in unexpected costs. Beyond drinking water, though, the EPA PFAS Roadmap shows the EPA’s desire to take regulatory action well beyond just drinking water, and companies absolutely must begin preparing now for regulatory actions that will have significant financial impacts down the road.

Article By John Gardella of CMBG3 Law

For more environmental legal news, click here to visit the National Law Review.

©2022 CMBG3 Law, LLC. All rights reserved.

After EPA Rule Changes, Which ASTM Phase I ESA Standard Should You Use?

On November 1, 2021, ASTM International released its revised standard for Phase I Environmental Site Assessments. On March 14, 2022, the U.S. Environmental Protection Agency (the “EPA”) published a Direct Final Rule that confirmed the new ASTM standard, ASTM E1527-21, could be used to satisfy the EPA’s All Appropriate Inquiry (“AAI”) regulations. That, in turn, would mean that satisfying the ASTM E1527-21 standard could help a potential buyer of contaminated property satisfy some of the EPA’s requirements to qualify as a Bona Fide Prospective Purchaser, which may lead to being protected from liability under the federal Superfund statute.

However, on May 2, 2022, EPA withdrew the Final Rule it had published on March 14, 2022, and indicated it would address the comments it received concerning the previously Final Rule in a subsequent final action.

Why the change and, more importantly, which ASTM standard should a potential purchaser of contaminated property use when having a Phase I Site Assessment prepared?

EPA withdrew its Direct Final Rule in response to the negative comments it received concerning that rule. EPA had planned to allow both the November 2021 ASTM standard and its predecessor from 2013 (the ASTM E1527-13 standard) to be used to satisfy certain AAI requirements. Those commenting said that approach would lead to confusion in the marketplace, and would allow reports that did not meet the ASTM E1527-21 standard to be considered adequate, even though the 2021 ASTM standard represented what the real estate and environmental community had determined to be good commercial and customary practice. In other words, because the 2021 standard required a more rigorous approach to the relevant environmental due diligence work needed to prepare a Phase I Environmental Site Assessment, EPA’s approach would have meant that less thorough reports could have been deemed sufficient.  As noted in the comment letter submitted to the EPA by the Environmental Bankers Association, “ASTM E1527-21 includes important updates that will reduce the risk of Users [of the ESA report] failing to identify conditions indicative of hazardous substance releases, potentially jeopardizing landowner [and prospective purchaser] liability protections to [potential] CERCLA [liability].” All of that makes sense: the better the environmental due diligence, the less risk of unpleasant surprises later.

But, where does that leave potential purchasers of contaminated real estate? Should they have their consultants prepare their Phase I Site Assessment reports based on the 2021 ASTM standard, or its 2013 predecessor, or both?

Contaminated real estate buyers, and any other parties involved in the transaction, such as lenders and equity investors, should require their environmental consultants to prepare their Phase I Environmental Site Assessment in conformance with the ASTM E1527-13 standard, because that is the ASTM standard that is currently referenced in EPA’s AAI regulations. It is necessary to do so, at least for now, in order to be able to qualify for Bona Fide Prospective Purchaser protection from CERCLA liability.

Those parties should also consider having their environmental consultants prepare the same Phase I Environmental Site Assessment in conformance with the updated ATSM E1527-21 standard. While some additional cost may be involved, nonetheless it may be worthwhile in order to meet what ASTM sees as the current standard of practice regarding these reports.

Another important consideration in the preparation of these reports is whether additional issues that are not formally included in the scope of either the ASTM E1527-13 or the ASTM E1527-21 standard should be addressed. For example, as noted in an appendix to the E1527-21 standard, petroleum products are within the scope of the practice “because they are of concern with respect to commercial real estate, and current custom and usage is to include an inquiry into the [past or present] presence of petroleum products when doing an environmental site assessment of commercial real estate.” That is so even though petroleum products generally do not lead to liability under CERCLA.

The non-scope issues appendix to the ASTM E1527-21 standard also addresses “substances not defined as hazardous substances” and does a good job addressing why a user of an ASTM-compliant report should at least consider whether to include certain emerging contaminants such as per- and polyfluoroalkyl substances, also known as PFAS, within its scope. The point is to think about whether to evaluate potential environmental liability for PFAS on a case-by-case basis in light of state law considerations, even though PFAS compounds have not yet been designated “hazardous substances” under CERCLA.

EPA’s recent rule-making activities have not provided clear guidance for potential purchasers of contaminated property regarding which ASTM standard should be used in preparing environmental site assessment reports that comply with EPA’s AAI regulations. At the moment, what seems to make the most sense is to have these reports prepared so that they comply with the ASTM E1527-13 standard and to consider whether to comply with the E1527-21 standard in addition. The user should also carefully evaluate whether certain considerations, such as potential PFAS contamination, should be included within the scope of the report.

Article By Ned Abelson and Justin Rheingold of Goulston & Storrs

For more environmental legal news, click here to visit the National Law Review.

2022 Goulston & Storrs PC.

Supreme Court Signals Move Away from Judicial Deference to Administrative Agencies

KEY TAKEAWAYS

In a unanimous decision on June 15, 2022, the Court in American Hospital Association v. Becerra[2] examined a Medicare reimbursement formula reduction that affected certain hospitals. While rejecting the DHHS agency interpretation of the reimbursement statute, the Court made no mention of Chevron deference even though the parties extensively briefed this doctrine. Instead, the Court focused solely on the relevant language of the statute. In particular, the Court held that the “text and structure” of the statute demonstrated that the Medicare reimbursement cut was not consistent with the statute.

In a 5-4 decision a few weeks later, the Court in Becerra v. Empire Health Foundation[3] again made no mention of Chevron deference even though the majority noted that the underlying statute’s “ordinary meaning … [did] not exactly leap off the page.” Despite its initial conclusion that the ordinary meaning of the statutory language was unclear, the Court continued its recent pattern of (a) choosing to not apply Chevron deference directly and (b) instead performing textural and structural analysis of its own. Based on this statutory analysis, the Court in Empire Health concluded that the statute was “surprisingly clear” if read as technical provisions for specialists and that the language of the statute supported the agency’s implementing regulation.

Finally, in West Virginia v. EPA,[4] the Supreme Court in a 6-3 decision again refused to give any deference to the EPA’s interpretation of a Clean Air Act provision which the EPA claimed as the statutory basis to regulate greenhouse gas emissions by power plants. The Court concluded that the EPA had violated the “Major Questions” Doctrine when the EPA used this provision to regulate carbon emissions. Under the “Major Questions” Doctrine, an agency cannot make decisions of vast economic and political significance without Congress expressly giving the agency the power to do so. Since the EPA’s effort to regulate greenhouse gases by making industry-wide changes was a decision of “vast economic and political significance,” the Court concluded that the EPA lacked the authority to do so in light of the overall nature and structure of the statute. Thus, even though there was some textual support for the EPA’s position, the Court again refused to defer to the agency and its interpretation of a statute.

Read together, these three decisions show an increased skepticism by the Court of agency interpretations of statutes and signal that going forward, the federal courts will more closely scrutinize administrative agency decisions in general. Businesses that have, to date, relied on an administrative agency interpretation may need to reassess their reliance if the interpretation relies on a broad or strained reading of a statute. Conversely, businesses currently restrained by agency interpretations which were shown deference by courts may now have an opening to challenge those interpretations.

FOOTNOTES

[1] Chevron, U.S.A., Inc. v. Nat. Res. Def. Council, Inc., 467 U.S. 837 (1984).

[2] Am. Hosp. Ass’n v. Becerra, 142 S. Ct. 1896 (2022).

[3] Becerra v. Empire Health Found., for Valley Hosp. Med. Ctr., 142 S. Ct. 2354 (2022).

[4] W. Virginia v. Env’t Prot. Agency, 142 S. Ct. 2587 (2022).

Article By Andrew T. Blum, Matthew J. Greenberg, and Larry J. Saylor of Miller Canfield

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