Category: Congress

Key Developments in Environmental Law and Policy in 2023, and What’s Ahead in 2024 [PODCAST]

On this episode of the Bracewell Environmental Law Monitor, we look back at the significant developments in environmental and natural resources law and policy in 2023, as well as look ahead to what’s to come in 2024. Co-hosts Daniel Pope and Taylor Stuart talk with Ann Navaro and Tim Wilkins, partners in Bracewell’s environment, lands and resources practice, about a range of topics, such as climate and environmental justice, renewable energy advancements, regulatory developments and much more.

 

EPISODE HIGHLIGHTS

[01:44] Big Developments in 2023: The Biden administration’s top priorities have been climate and environmental justice. The big development of 2023 on the climate front has been on the methane side rather than the carbon dioxide side. Regarding environmental justice, the Biden administration and NGOs have been really pushing to apply justice factors in enforcement, in cleanups, new rulemaking, permitting, issuance of grants and loans, and the like.

[06:59] A Significant Year for Jurisdiction Under the Clean Water Act: Almost a year ago, the Biden administration issued its definition of “Waters of the United States.” Subsequently, the Supreme Court issued another decision interpreting Waters of the United States in the Sackett case and essentially eviscerated one of the bases for the Biden administration’s Waters of the US rulemaking. Litigation is ongoing.

[09:33] Congress Amended the National Environmental Policy Act and the Fiscal Responsibility Act: This was enormous, as core provisions had never seen substantive amendments. There are mixed reviews of what that amendment to NEPA accomplished.

[13:41] Renewable Energy: There’s been advancement in renewable energy projects and trying to permit those projects and an emphasis on promoting renewable energy. For example, for offshore wind, in this year and in prior years of the Biden administration, there’s been a lot of advancement on leasing.

[21:57] On the Horizon in Environmental Law in 2024: Ann shares that the US Army Corps of Engineers could revise Nationwide Permit 12. Tim shares that the White House is reviewing EPA’s CERCLA hazardous substance listing for two of the leading PFAS chemicals, and the listing will go final sometime early in 2024. In addition, the SEC’s semi-annual rulemaking agenda for April 2024 promises to include proposed climate disclosure rules for publicly traded companies.

© 2023 Bracewell LLP
For more news on Upcoming Environmental Law in 2024, visit the NLR Environmental, Energy & Resources section.

Permitting Reform Package Passes as Part of Debt Ceiling Deal

The past year’s long wrangling between Republicans, Democrats, and the White House on permitting reform finally made progress this month when Congress enacted significant reforms to the National Environmental Policy Act (“NEPA”) as part of the legislation to increase the debt ceiling. Prior to this legislation, the core statutory framework of NEPA had remained relatively unchanged for 50 years. Building from Rep. Garrett Graves’ (R-LA., 6th Dist.) “Building United States Infrastructure through Limited Delays and Efficient Reviews” (“BUILDER”) Act of 2023, the permitting reform title of the Fiscal Responsibility Act of 2023 (“FRA” or “legislation”) tackles four key areas:

(1) reforming NEPA to make the federal environmental review process simpler and quicker;

(2) directing a study of the existing capacity of our transmission grid to reliably transfer electric energy between distinct regions and subsequent recommendations to improve interregional transfer capabilities within the grid;

(3) streamlining permitting for energy storage projects; and

(4) congressional ratification of the Mountain Valley Pipeline.

Several of the reforms to NEPA codify changes to the Council on Environmental Quality (“CEQ”) NEPA implementing regulations made during the Trump Administration.

While these provisions are intended to yield significant benefits for projects requiring federal approvals or funding, the actual impact will depend substantially on how the reforms are implemented, and there remains considerable interest in other aspects of permitting and siting reform making further legislative action likely.

Key NEPA Reforms

The FRA includes numerous changes to NEPA. We have highlighted several key changes here.

Narrowing the Scope of “Major Federal Action”

The term “major Federal action” is the trigger for requiring environmental review under NEPA – federal actions that qualify as a “major Federal action” must be considered under NEPA. The new legislation narrows the definition of what constitutes a “major Federal action” by limiting the term to actions that the lead agency deems are “subject to substantial Federal control and responsibility.” The legislation does not define this phrase, leaving substantial room for agency interpretation. Building on this general concept, the amendments codify the regulatory definition of a “major Federal action,” with modifications. As now defined, certain federal actions will be excluded from the scope of a major federal action, including:

  • non-federal actions (i.e., private or state actions) “with no or minimal Federal funding”;
  • non-federal actions (i.e., private or state actions) “with no or minimal Federal involvement where a Federal agency cannot control the outcome of the project”;
  • funding assistance consisting exclusively of general revenue sharing funds, where the federal agency does not have “compliance or enforcement responsibility” over the use of those funds;
  • “loans, loan guarantees, or other forms of financial assistance where a Federal agency does not exercise sufficient control and responsibility over the subsequent use of such financial assistance or the effect of the action”;
  • Small Business Act business loan guarantees under section 7(a) or (b) of the Small Business Act or title V of the Small Business Investment Act of 1958;
  • federal agency activities or decisions with effects located entirely outside of the jurisdiction of the United States; and
  • non-discretionary activities or decisions that are made in accordance with the agency’s statutory authority.

The meaning and application of these exclusions to specific actions will be subject to interpretation and likely litigation going forward. For example, what constitutes minimal funding—a threshold dollar amount or a percentage of the federal funding contribution in relation to overall project cost—is not clearly identified under the revisions. Resolution of this question will be critical to determining what actions are subject to NEPA review going forward. Given the recent dramatic increase in federal funding opportunities from the Inflation Reduction Act and Infrastructure Investment and Jobs Act, determining what actions are subject to NEPA review based on the level of federal funds involved is likely to become a more frequent and important question.

Scope of Review

When an agency action constitutes a “major Federal action,” the FRA also focuses and limits the scope of the NEPA review in two key ways.

First, the legislation modifies the statute’s existing, broad language requiring that “major Federal actions” significantly affecting the quality of the human environment include a detailed statement on the “environmental impact of the proposed action.” The revised language statutorily limits environmental review of environmental effects to those that are “reasonably foreseeable.” This change follows from a provision of the Trump Administration’s 2020 NEPA rule—later removed by the Biden Administration—which sought to eliminate long-used concepts of direct, indirect, and cumulative effects and instead focus on effects that are reasonably foreseeable and that have “a reasonably close causal relationship to” the proposed action or alternatives. Although the new statutory language does not go as far as the Trump Administration’s rule, which required a “close causal relationship,” it does follow the trend in case law to only require evaluation of reasonably foreseeable impacts. What project-specific impacts are “reasonably foreseeable” is still likely to be the subject of litigation.

Second, the FRA also makes changes regarding the alternatives analysis, often considered the heart of NEPA review. The legislation clarifies that agencies are to consider a “reasonable range” of alternatives to the proposed agency action, and that such alternatives must both be “technically and economically feasible” and “meet the purpose and need of the proposal.” This seems to codify long-standing guidance from CEQ contained in its 40 Most Asked Questions Concerning CEQ’s NEPA Regulations. In addition, it directs that, in assessing the no action alternative, agencies must include an analysis of any negative environmental impacts of not implementing the proposed action. Whether an agency has met its obligations under NEPA to consider “alternatives to the proposed action” is a frequent source of controversy and litigation, particularly for the authorization of large infrastructure and energy projects.

These changes should both help focus environmental reviews and reduce costs and delays associated with challenges to agencies’ alternative analyses and emphasize the importance of properly defining the “purpose and need” of a proposed action.

Data Standards and Requirements

The FRA includes several provisions related to data. First, it clarifies that in making a determination on the appropriate level of review (Environmental Impact Statement (“EIS”), Environmental Assessment (“EA”), or categorical exclusion), the lead agency can make use of any reliable data source—and that “new scientific or technical research [is not required] unless the new scientific or technical research is essential to a reasoned choice among alternatives, and the overall costs and time frame of obtaining it are not unreasonable.” It is unclear whether this will be applied beyond the determination of what level of review is required. This change has the potential to limit delays due to agencies undertaking or requesting additional studies from project proponents. What is deemed “essential” and what costs and timeframe are “not unreasonable,” however, remain undefined.

Second, the legislation requires that the action agency “ensure the professional integrity, including scientific integrity, of the discussion and analysis in an environmental document.” The practical implications and scope of this scientific integrity mandate are unclear—and is likely to be a subject of agency guidance and, potentially, future litigation.

Efficiency Measures

The FRA further codifies several less controversial changes from the Trump Administration 2020 NEPA rule, which the recent Biden rulemaking had left in place. These changes include expressly recognizing and establishing regulations for EAs. Additionally, these changes include setting page limits for EISs—150 pages generally and 300 pages for agency actions “of extraordinary complexity”—and EAs—75 pages—excluding citations and appendices. Additionally, the changes codify the regulatory presumptive deadlines for completion of NEPA reviews—two years for EISs and one year for EAs. The legislation goes beyond existing regulations by creating the right to judicial review when an agency fails to meet a deadline. Under the new legislation, if an agency misses the deadline, the delayed project’s sponsor may seek a court order requiring the agency to act as soon as practicable, which is not to exceed 90 days from the date on which the order was issued unless the court determines that additional time is needed to comply with applicable law.

Further, the legislation clarifies the role of the NEPA lead agency, specifying that the lead agency must develop a schedule, in cooperation with each cooperating agency, the applicant, and other appropriate entities, for the completion of the environmental review and any permit or authorization required to carry out the proposed agency action. This mirrors provisions previously adopted as part of Title 41 of the Fixing America’s Surface Transportation Act (“FAST-41”) in 2015, which has demonstrated success in requiring coordination and improving the permitting and authorization processes for certain large infrastructure projects. Although the FRA expressly contemplates extensions to the schedule, just having a schedule in place can be a helpful tool in the timely completion of NEPA reviews.

In addition, the legislation authorizes project applicants to hire independent consultants to prepare EISs and EAs, subject to the independent review of the lead agency. This provision can provide project applicants with a path to minimize delays caused by a lack of staff and resources at federal agencies.

Programmatic Reviews and Categorical Exclusions

The FRA also codifies the current agency practice of preparing and relying on programmatic environmental documents to streamline the review process for subsequent actions that implement the evaluated program. The legislation provides that programmatic review can be relied on for five years without additional review, and after five years if the agency reevaluates the analysis. Although this change promotes further use of programmatic reviews, the five-year period presumption and reevaluation process could present challenges in certain cases given the extensive resources and time required to undertake a programmatic review and tiered reviews.

The FRA also seeks to facilitate the use of categorical exclusions in the NEPA process by authorizing agencies to adopt a categorical exclusion established by another agency. The legislation lays out a process for consulting with the agency that established the exclusion to determine whether adoption is appropriate, notifying the public of the plan to use the categorical exclusion, and documenting adoption of the categorical exclusion. Though dependent upon agencies taking advantage of this new flexibility, this could have the effect of enabling some types of projects to forgo detailed environmental review.

Other Provisions

In addition to the NEPA reforms, the FRA includes several other important permitting provisions. The legislation seeks to streamline and accelerate permitting for “energy storage” projects by adding energy storage to the list of “covered projects” under FAST-41.

Additionally, the legislation provides a clear path for the completion of the much-delayed Mountain Valley Pipeline project. The legislation finds the timely completion of the project is in the national interest, and congressionally approves and ratifies the various federal authorizations required for the project. Further, the legislation bars judicial review of federal agency actions with respect to the project.

Finally, the legislation requires the North American Electric Reliability Corporation (“NERC,” the entity responsible for setting reliability standards for the nation’s electric grid) to undertake a study within a year and a half on whether more transfer capacity is needed between existing transmission planning regions—including recommendations on measures to increase the amount of energy that can be reliably moved between the studied regions. The Federal Energy Regulatory Commission will thereafter have a year to seek and consider public comments on the study and file a report with Congress detailing any recommendations for statutory changes. This study provision was in lieu of a larger set of transmission-related actions that are of key interest to Democratic lawmakers that will be the subject of future legislative efforts.

Implications

Although the provisions in FRA are not a silver bullet to solve every NEPA woe experienced by project applicants, it is a significant step in the right direction. The codification of key concepts within the NEPA statute itself (rather than regulation, guidance, or case law) will have a durable, long-lasting impact on implementation of environmental reviews because it limits the regulation issuance/withdrawal cycle that we have witnessed with the recent administration changes.

Looking forward, we can expect a rulemaking by CEQ to align the existing regulations with the revised statutory language, as well as additional rulemakings by other agencies to harmonize their NEPA implementing regulations with the revised law. For the last year, we have awaited the Phase 2 NEPA rulemaking from CEQ, as explained in our previous alert. With this new legislation, it seems likely that CEQ will pause and further revise its proposed regulations to capture these new reforms before issuing additional regulations. We can also expect future guidance—and eventual litigation—on several ambiguous provisions in the new legislation as agencies begin to implement them.

While the intention behind the legislation is to speed and ease what has become a very lengthy, expensive, and perilous environmental review process—far exceeding the original intent of NEPA—whether these goals are achieved will depend on whether federal agencies embrace them or look for ways to interpret the reforms to continue “business as usual.”

For example, to meet the new timelines, it is possible that federal agencies will require applicants to provide all documentation needed for the environmental review before starting the clock. This approach would have the effect of undermining the statutory timeframes as well as the efficacy of the public engagement process. Similarly, while the legislation seeks to curtail the extent of the analysis through page limits, it is foreseeable that relatively short EISs and EAs could be weighed down with thousands of pages of analysis contained in the appendices.

It also remains to be seen how courts will interpret these reforms. The “hard look” standard developed by courts to evaluate the adequacy of environmental review documents may have the effect of ballooning the analyses again despite Congress’ intent to streamline the process.

Finally, while these reforms are substantial, Congress continues to discuss and debate additional reforms to address unresolved federal siting and permitting concerns—particularly with respect to energy infrastructure projects. Notably absent from the legislation was transmission permitting reform language of interest to Democratic lawmakers as well as provisions to support oil and gas leasing on federal lands and to facilitate the siting and permitting of mining projects to boost domestic supplies of critical minerals essential for existing and developing clean energy technologies.

© 2023 Van Ness Feldman LLP

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

As White House Loses House Majority, what is Next for H-1B Visa Program?

The H-1B is a popular and highly-sought-after visa category for skilled foreign workers seeking to work in the United States. It has been the subject of much debate and controversy over the years, and recent changes in the political landscape have added new uncertainties and challenges to the H-1B visa process. This blog post explores the impact of the Biden administration on changes to the H-1B visa, as well as the role of the new Republican majority in the House of Representatives in shaping the future of the H-1B visa program.

What is the H-1B Visa?

The H-1B is a temporary, nonimmigrant visa category that allows employers to petition on behalf of highly-educated foreign professionals who work in specialty occupations that require at least a bachelor’s degree. These jobs are generally in the fields of science, technology, engineering, and mathematics (“STEM”), enhancing American competitiveness in the global economy. In fact, in an effort to be even more competitive, the Biden administration recently expanded eligible fields of study that qualify under the program, as described in greater detail on this blog.

The H-1B visa allows U.S. employers to fill critically important jobs in the United States with foreign workers.  While many critics of the H-1B argue that it potentially limits job opportunities for U.S. workers, many others suggest that H-1B workers offer critical support to the U.S. economy. In fact, according to the American Immigration Counsel, H-1B recipients provided critical assistance during the COVID-19 pandemic, with many doctors, scientists, and nurses present in the U.S. on the H-1B visa, including individuals who assisted with the development of vaccines.

Biden Administration and its Relationship with Immigration Reform

One of the key priorities of the Biden administration has been to modernize and improve the U.S. immigration system, including the H-1B visa program. To this end, the Biden administration has taken steps to make the H-1B visa process more accessible and efficient for skilled foreign workers, including increasing the number of visas available, increasing transparency and consistency in the lottery process, and streamlining the application process.

According to a recent article by Forbes, Senator Richard Durbin (D-IL) and Senator Alex Padilla (D-CA) are expected to return as Senate Judiciary Committee chair and immigration subcommittee chair, respectively. It is expected that Sen. Chuck Grassley (R-IA) will no longer be ranking member on the Senate Judiciary; Sen. Lindsey Graham (R-SC) likely will hold that position. Just last year, Senator Grassley blocked an exemption from green card limits for certain foreign nationals with PhDs in STEM fields – a move that frustrated employers and universities alike.

Although Democrats hold the majority in the Senate, the House now features a Republican majority, which may complicate immigration reform efforts on Capitol Hill.

Republicans on Capitol Hill Seek to Counter Democratic Efforts on Immigration

The new Republican majority in the House of Representatives may pose a challenge to the Biden administration’s efforts to reform the H-1B visa program. Republicans have traditionally been more critical program and have pushed for reforms that would restrict the number of visas available and make it more difficult for foreign workers to come to the United States.

Sen. Tom Cotton (R-AR) has been a vocal critic of the H-1B program, stating that it is used to hire cheap foreign labor at the expense of American workers. Similarly, Sen. Grassley has expressed concerns about the impact of the program on American workers, claiming that while the visa was intended to help American businesses recruit the best and brightest talent from around the world, it’s too often been used to import cheaper foreign labor and displace American workers.

Given these differing perspectives, the future of the H-1B visa program will likely continue to be a source of political debate and controversy in the United States. However, it is clear that both sides of the political aisle agree that it needs to be reformed in some way, whether to make it more accessible and efficient for skilled foreign workers, or to better protect the interests of American workers.

Currently, the H-1B process in the United States is in a state of flux, with the Biden administration taking steps to modernize and improve the program, while the new Republican majority in the House of Representatives raises concerns about its impact on American workers. Whether the program will ultimately be reformed to better serve the interests of foreign workers, American workers, or both remains to be seen, but clearly this issue will continue to be a major source of political debate and controversy in the United States for the foreseeable future.

Article By Raymond G. Lahoud of Norris McLaughlin P.A.

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

©2023 Norris McLaughlin P.A., All Rights Reserved

SECURE 2.0 Act Brings Slate of Changes to Employer-Sponsored Retirement Plans

In December, the SECURE 2.0 Act of 2022 (“SECURE 2.0”) was passed, a package of retirement provisions providing comprehensive updates and changes to the SECURE Act of 2019. The legislation includes some key changes that affect employer-sponsored defined contribution plans, such as profit-sharing plans, 401(k) plans, 403(b) plans and stock bonus plans. While some of the changes are effective immediately upon the law’s enactment, most required changes are not effective before the plan year beginning on or after January 1, 2024, so employer sponsors have time to prepare for compliance.

Required Changes

Mandatory automatic enrollment in new plans.

Plan sponsors are currently allowed to provide for automatic enrollment and automatic escalation in 401(k) and 403(b) plans. SECURE 2.0 requires new 401(k) and 403(b) plans to automatically enroll participants at a new default rate, and to escalate participants’ deferral rate each year, up to a maximum of 15%, with some exceptions for new and small businesses. This provision applies to new plans with initial plan years beginning after December 31, 2024.

Changes to long-term part-time employee participation requirements.

The Act currently requires 401(k) plans to permit participation in the deferral part of the plan only by an employee who worked at least 500 hours (but less than 1000 hours) per year for three consecutive years. SECURE 2.0 changes this participation requirement by long-term part-time employees working more than 500, but less than 1000, hours per year to two consecutive years instead of three. However, this two-year provision does not take effect until January 1, 2025, which means the original SECURE Act three-year provision still applies for 2024. Employers should start tracking hours for part-time employees to determine whether they will be eligible in 2024 or 2025 under this provision. For vesting purposes, pre-2021 service is disregarded, just as service is disregarded for eligibility purposes. This provision is applicable to 401(k) plans and 403(b) plans that are subject to ERISA and does not apply to collectively bargained plans. This provision applies to plan years beginning after December 31, 2024.

Changes to catch-up contributions limits.

If a defined contribution plan permits participants who have attained age 50 to make catch-up contributions, the catch-up contributions are now required to be made on a Roth basis for participants who earn at least $145,000 (indexed after 2024) or more in the prior year. This provision is effective for taxable years beginning after December 31, 2023.

Changes to the required minimum distribution (RMD) age.

Currently, required minimum distributions must begin at age 72 for participants who have terminated employment. SECURE 2.0 increases the age to age 73 starting on January 1, 2023, and to age 75 starting on January 1, 2033. This means that participants who turn 72 in 2023 are not required to take an RMD for 2023; instead, they will be required to start taking RMDs for calendar year 2024, the year in which they turn 73. This provision is effective for distributions made after December 31, 2022, for individuals who turn 72 after that date.

Early withdrawal tax exemption for emergency withdrawal expenses.

SECURE 2.0 provides for an exception from the 10% early withdrawal tax on emergency expenses, defined as certain unforeseeable or immediate financial needs, on a limited basis (once per year, up to $1000). Plans may allow an optional three-year payback period, and participants are restricted from taking another emergency withdrawal within three years of any unpaid amount on a previous withdrawal. This provision is effective for plan years beginning on or after January 1, 2024.

Changes to automatic enrollment for new plans.

Almost all new defined contribution plans will be required to auto-enroll employees upon hire (existing plans are exempt from this provision). This provision is applicable for plan years beginning on or after January 1, 2025.

Optional Changes

Additional catch-up contribution opportunities.

Currently, the catch-up contribution limits for certain plans are indexed for inflation and apply to employees who have reached the age of 50. SECURE 2.0 increases catch-up contribution limits for individuals aged 60-63 to the greater of: (1) $10,000 (indexed for inflation), or (2) 50% more than the regular catch-up amount in effect for 2024. This provision is effective for plan years beginning on or after January 1, 2025.

Additional employer contributions to SIMPLE IRA plans.

Current law requires employers with SIMPLE IRA plans to make employer contributions to employees of either 2% of compensation or 3% of employee elective deferral contributions. SECURE 2.0 allows employers to make additional contributions to each employee of a SIMPLE plan in a uniform manner, provided the contribution does not exceed the lesser of up to 10 percent of compensation or $5,000 (indexed). This provision is effective for taxable years beginning after December 31, 2023.

Replacing SIMPLE IRA plans with safe harbor 401(k) plans.

The new law also permits an employer to elect to replace a SIMPLE IRA plan with a safe harbor 401(k) plan at any time during the year, provided certain criteria are met. The current law prohibits the replacement of a SIMPLE IRA plan with a 401(k) plan mid-year. This provision also includes a waiver of the two-year rollover limitation in SIMPLE IRAs converting to a 401(k) or 403(b) plan. This change is effective for plan years beginning after December 31, 2023.

Increasing involuntary cash-out threshold.

Currently plans may automatically cash-out a vested participant’s benefit that is between $1,000 and $5,000 and roll this amount over to an IRA. SECURE 2.0 allows plans to increase the $5,000 involuntary cash-out limit amount to $7,000. This provision of the law is effective for distributions made after December 31, 2023.

Relaxation of discretionary amendment deadline.

Under current law, a discretionary plan amendment must be adopted by the end of the plan year in which it is effective. SECURE 2.0 allows plans to make discretionary plan amendments to increase benefits until the employer’s tax filing deadline for the immediately preceding taxable year in which the amendment is effective. This applies to stock bonus, pension, profit-sharing or annuity plans to increase benefits for the preceding plan year. This provision is effective for plan years beginning after December 31, 2023.

Elimination of unnecessary plan notices to unenrolled participants.

SECURE 2.0 eases the administrative burden on plan sponsors by eliminating unnecessary plan notices to unenrolled participants. Under the amended law, plan sponsor notices to unenrolled participants may consist solely of an annual notice of eligibility to participate during the annual enrollment period, as opposed to numerous notices from the plan sponsor. This provision is effective for plan years beginning after December 31, 2022.

Crediting of student loan payments as elective deferrals for purposes of matching contributions.

Under SECURE 2.0, student loan payments may be treated as elective deferrals for the purposes of matching contributions to a retirement plan. This provision is available for plan years beginning on or after January 1, 2024.

Matching contributions designated as Roth contributions.

Previously, employer matching contributions could not be made as Roth contributions. Effective on the date of the enactment of SECURE 2.0, 401(a), 403(b), or governmental 457(b) plans may allow employees the option to designate matching contributions as Roth contributions.

Expansion of the Employee Plans Compliance Resolution System (EPCRS).

Currently, EPCRS contains procedures to self-correct certain limited, operational failures that are insignificant and corrected within a three-year period. SECURE 2.0 expands this, generally permitting any inadvertent failure to be self-corrected under EPCRS within a reasonable period after the failure is identified, without a submission to the IRS, subject to some exceptions. This provision went into effect on the date of enactment.

Recoupment of overpayments.

Currently, fiduciaries for plans that have mistakenly overpaid a participant must take reasonable steps to recoup the overpayment (for example, by collecting it from the participant or employer) to maintain the tax-qualified status of the plan and comply with ERISA. Under SECURE 2.0, 401(a), 403(a), 403(b), and governmental plans (not including 457(b) plans) will not lose tax qualification merely because the plan fails to recover an “inadvertent benefit overpayment” or otherwise amends the plan to permit this increased benefit. In certain cases, the overpayment is also treated as an eligible rollover distribution. This provision became effective upon enactment with certain retroactive relief for prior good faith interpretations of existing guidance.

Simplified plan designs for “starter” 401(k) and 403(b) plans.

Effective for plan years beginning after December 31, 2023, SECURE 2.0 creates two new plan designs for employers who do not sponsor a retirement plan: a “starter 401(k) deferral-only arrangement” and a “safe harbor 403(b) plan.” These plans would generally require that all employees be enrolled in the plan with a deferral rate of three percent to 15 percent of compensation.

Financial incentives for contributions.

SECURE 2.0 allows participants to receive de minimis financial incentives (not paid for with plan assets) for contributing to a 401(k) or 403(b) plan. Previously, plans were prohibited from offering financial incentives (other than matching contributions) to employees for contributing to a plan. This provision became effective for plan years starting after the date of enactment.

When do employers need to amend their plans for the SECURE Act, CARES Act, and SECURE 2.0 (“the Acts”)?

If a retirement plan operates in accordance with the Acts, plan amendments must be made by the end of the 2025 plan year (or 2027 for governmental and collectively bargained plans). (The amendment deadlines for SECURE and CARES were extended late last year.)

Article By John D. Arendshorst, Andrea M. Gumushian, and Kristy L. De Vos of Varnum LLP

For more labor and employment legal news, click here to visit the National Law Review.

© 2023 Varnum LLP

Washington’s Focus on the Electric Vehicle Supply Chain in 2023

If a picture is worth a thousand words, the “photo-op” of the president test driving Ford’s new electric F-150 in May of 2021 was the burning image that foretold the US policy direction for the electric mobility industry.

In 2022, the president and US Congress solidified their support of the industry by passing sweeping legislation aimed at funding and incentivizing US electric mobility manufacturing for the next decade and beyond.

Looking ahead to 2023, the Administration will be writing the rules to implement that support. This will take the form of rulemaking for key statutes such as the Infrastructure Investment and Jobs Act (IIJA), the CHIPS Act, and the more recent Inflation Reduction Act of 2022 (IRA). On the non-tariff front, Congress passed, and the president signed, the 2021 Uyghur Forced Labor Prevention Act.

Background

  • The IIJA authorized $18.6 billion to fund new and existing electric vehicle (EV)-related programs, including a nationwide network of 500,000 EV charging stations and monies for publicly accessible alternative fuel infrastructure. Also, the law injected $10.9 billion in funding for transitioning school buses, transit buses, and passenger ferries to low- and/or zero-emissions alternatives.
  • The CHIPS Act allocated $11 billion in support of advanced semiconductor manufacturing research and set up a $2 billion fund to support technology transfers from laboratory to applications.
  • The IRA, perhaps the most significant development from Washington, DC, injected billions of dollars in tax credits and other incentives to spur US domestic manufacturing of electric vehicles.
  • In December 2022, news came that a United States-Mexico-Canada Agreement (USMCA) Dispute Settlement Panel had completed its findings on a complaint by Mexico and supported by Canada that the United States has been misinterpreting the product origin calculations for “core parts” for USMCA vehicle qualification. In January of 2023, that ruling was made public. See Long Awaited USMCA Panel Decision on Automotive “Core Parts” – What Happened and What’s Next.
  • In June 2022, the Administration published its “Strategy to Prevent the Importation of Goods Mined, Produced, or Manufacture with Forced Labor.” Customs and Border Protection (CBP) has launched a vigorous and highly intrusive enforcement strategy for a number of key sectors, including the automotive industry.

What to Know

Based on the legislative developments from the last year, the EV industry should expect:

  • Import Enforcement. If 2022 was the year of federal infusion of funding and policy development, 2023 will be the year of import enforcement and accountability. Supply chains will be scrutinized, and compliance will have to be demonstrated. In addition, claims of tariff preferences under US trade agreements will be closely monitored to guard against fraudulent product descriptions or county of origin. In terms of US forced labor legislation, a January 2023 article in a well-read trade media reported on a meeting with US Trade Representative Katherine Tai at which the Ambassador “suggested that auto or auto parts imported from China could be in CBP crosshairs.” (International Trade Today, January 6, 2023 Vol 39, No 4).
  • Accountability. With the massive funding from Congress and the White House, federal agencies will be scrutinizing how monies have been spent, particularly whether they have been spent to meet the goals to incentive US domestic production. Global supply chains will come under the microscope. A December 2022 Treasury Department publication can be read here.
  • Corporate Readiness. Companies that engage in the global marketplace dread the unknown. There is no crystal ball. But what corporate executives can do to mitigate the risk of potentially bad news on the trade front is to monitor developments, conduct self-assessments, and, where possible, build in flexibilities.
  • Know Your Customer. Know Your Suppliers. Know Your Suppliers’ Suppliers. A common thread weaving throughout these developments on the trade front is Washington’s not so subtle objective of determining the essential source of imported products. That effort will shift the onus onto the private sector, with companies having to provide far more transparency into their product’s life span.

For product development and marketing executives in the electric mobility sector, 2023 is potentially a very good news story. But for general counsels and corporate compliance and procurement officers, the uncertainties of regulatory change will require extra attention. In the interim, company officials are taking a fresh look at the current legal and regulatory exposures of their supply chains to be best prepared for the trade policy changes ahead. The adage “when in uncertain times, start with what you know” is particularly relevant today.

To that end, the USMCA can play a critical “bridge” for many companies with strategic business interests in the US market.

Article By Birgit Matthiesen, David R. Hamill, Antonio J. Rivera, and James Kim of ArentFox Schiff LLP

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

© 2023 ArentFox Schiff LLP

Complying With New Federal Pregnant Workers Fairness Act, PUMP for Nursing Mothers Act

The new Pregnant Workers Fairness Act (PWFA) and the Providing Urgent Maternal Protections for Nursing Mothers Act (PUMP For Nursing Mothers Act) were adopted when President Joe Biden signed the Consolidated Appropriations Act, 2023 on Dec. 29, 2022.

PWFA: Pregnancy Finally Given Disability-Like Protection

The PWFA applies to employers with at least 15 employees and becomes effective on June 27, 2023.

Like the Americans with Disabilities Act (ADA), the PWFA includes the obligation to provide reasonable accommodations so long as they do not impose an undue hardship. Many courts have determined that pregnancy alone was not a disability entitled to accommodation under the ADA. Under the PWFA, employers will be required to provide reasonable accommodations to employees and applicants with known temporary limitations on their ability to perform the essential functions of their jobs based on a physical or mental condition related to pregnancy, childbirth, and related medical conditions.

The PWFA adopts the same meaning of “reasonable accommodation” and “undue hardship” as used in the ADA, including the interactive process that will typically be used to determine an appropriate reasonable accommodation.

The PWFA provides that an employee or their representative can make the employer aware of the employee’s limitations. It also provides that an employer cannot require an employee to take a paid or unpaid leave of absence if another reasonable accommodation can be provided. Of course, that does not mean the employee gets the accommodation of their choice. The statute provides a defense to damages for employers that, in good faith, work with employees to identify alternative accommodations that are equally effective and do not cause an undue hardship.

Practical Advice for PWFA Compliance

  1. Employers do not have to have a policy for every rule or practice that applies in the workplace. However, if an employer has a reasonable accommodations policy, that policy should be reviewed and updated, as necessary.
  2. Human resources professionals are not the only ones who need training. If managers are not trained as well, they may unwittingly say something in response to an employee’s question that is inconsistent with your policies and practices.
  3. Create a process to follow when employees request an accommodation due to pregnancy-related limitations. The process should be similar to the ADA process, including requesting supporting documentation from the treating healthcare provider. Have employees in states or cities that have adopted versions of the pregnant workers fairness law or other similar laws that are more generous than the federal PWFA? The federal PWFA does not preempt more generous state and local laws. Therefore, any policy, practice, or form may need to be modified depending on where employees are located. As an example, some city and state laws, except in specific circumstances, prohibit employers from requesting medical documentation to confirm an employee’s pregnancy, childbirth, or related medical conditions as part of the accommodation process.
  4. Like under the ADA, when an employee requests an accommodation under the PWFA, Human resources professionals should think about how to make this work, not this will never work. This simple shift in approach makes finding a reasonable accommodation that does not impose an undue hardship on operations more likely.

PUMP for Nursing Mothers Act

The PUMP for Nursing Mothers Act expands existing employer obligations under the Fair Labor Standards Act (FLSA) to provide an employee with reasonable break time to express breast milk for the employee’s nursing child for one year after the child’s birth. The employer obligation to provide a place to express milk shielded from view and intrusion from coworkers and the public (other than a bathroom) continues.

Except for changes to available remedies, the amendment to the FLSA took effect on December 29, 2022. The changes to remedies will take effect on April 28, 2023.

What Changed Under PUMP for Nursing Mothers Act

The PUMP for Nursing Mothers Act covers all employees, not just non-exempt workers. The break time may be unpaid unless otherwise required by federal or state law or municipal ordinance. Employers should ensure that non-exempt nursing employees are paid if they express breast milk during an otherwise paid break period or if they are not completely relieved of duty for the entire break period. Exempt employees should be paid their full weekly salary as required by federal, state, and local law, regardless of whether they take breaks to express breast milk.

With some exceptions, the law requires employees to provide notice of an alleged violation to the employer and give the employer a 10-day cure period before filing a suit.

Employers with fewer than 50 employees can still rely on the small employer exemption, if compliance with the law would cause undue hardship because of significant difficulty or expense. Crewmembers of air carriers are exempted from the law. Rail carriers and motorcoach services operators are covered by the law, but there are exceptions and delayed effective dates for certain employees. No similar exemption is provided for other transportation industry employers.

Practical Advice for PUMP for Nursing Mothers Act Compliance

  1. Educate the HR team and front-line managers on the update to the law and refresh them on the process for providing break time and private spaces to express breast milk.
  2. Like the PWFA, the law does not preempt state law or municipal ordinances that provide greater protection than provided by the PUMP for Nursing Mothers Act. Depending on where employees are located, policies, practices, and the private space provided to express breast milk may need to be modified.
  3. Creativity is the key to being able to come up with staffing solutions and private spaces for nursing mothers to express breast milk. Nothing in the law requires employers to maintain a permanent, dedicated space for nursing mothers. A space temporarily created or converted into a space for expressing breast milk and made available when needed by a nursing mother is sufficient if the space is shielded from view and free from intrusion from coworkers and the public. In other words, allowing an employee to use an office with a door that locks would be convenient, but not practical for many worksites. Depending on the workplace settings, privacy screens, curtains, signage, portable pumping stations, and partnerships with other employers to provide private spaces for nursing mothers are all possibilities.

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Jackson Lewis P.C. © 2023

Newly Enacted Federal “Speak Out Act” Limits Use of Some Sexual Harassment NDAs

President Biden has signed into law the federal “Speak Out Act” limiting the enforceability of pre–dispute non-disclosure and non-disparagement clauses covering sexual assault and sexual harassment disputes.  The Act takes effect immediately.

The Act places restrictions on the enforceability of pre-dispute:

  • “non-disclosure clauses,” meaning “a provision in a contract or agreement that requires the parties to the contract or agreement not to disclose or discuss conduct, the existence of a settlement involving conduct, or information covered by the terms and conditions of the contract or agreement.”
  •  “non-disparagement clauses,” defined as “a provision in a contract or agreement that requires 1 or more parties to the contract or agreement not to make a negative statement about another party that relates to the contract, agreement, claim, or case.”

Such clauses entered into before a sexual assault or sexual harassment dispute arises are rendered unenforceable.  The Act defines covered “sexual assault disputes” as disputes “involving a nonconsensual sexual act or sexual contact, as such terms are defined in section 2246 of title 18, United States Code, or similar applicable Tribal or State law, including when the victim lacks capacity to consent.” Covered “sexual harassment disputes” are defined as disputes “relating to conduct that is alleged to constitute sexual harassment under applicable Federal, Tribal, or State law.”

A few notes about the Act’s scope and implications:

  • Critically, the Act may have limited implications for many employers for one key reason – the Act only applies to non-disclosure and non-disparagement clauses in pre-dispute agreements, meaning that any non-disclosure/non-disparagement clauses in agreements entered into by employers/employees concerning sexual assault or sexual harassment issues after a dispute has arisen are not impacted by the Act.  Because of this, the Act’s protections would not apply to non-disclosure/non-disparagement clauses in separation or settlement agreements executed after sexual harassment or sexual assault allegations are made, but may be subject, of course, to any applicable state or local laws.
  • The Act explicitly excludes from coverage any efforts by employers to protect trade secrets and proprietary information via non-disclosure or non-disparagement provisions.
  • While the Act does apply to non-disclosure/non-disparagement clauses in agreements entered into before December 7, 2022 (the Effective Date), it would not impact clauses entered into before a dispute arose, but where that dispute was active before the Act’s December 7th effective date.
  • Given the above, employers utilizing non-disclosure/non-disparagement agreements at the outset of employment or during the employment lifecycle should consider creating proper carve-outs for sexual assault and sexual harassment issues given the new Act.

Employers should also be aware of other recent developments in this area.  The Speak Out Act also follows the enactment of the Ending Forced Arbitration of Sexual Assault and Sexual Harassment Act, which took effect earlier this year (our post on the law can be found here).  That federal law prohibits employers from compelling arbitration of sexual harassment or sexual assault claims and provides employees the option to pursue those claims in other forums.  Employers should also remain aware that, despite the seemingly narrow implications of this new federal law, several states – including California, Illinois, New Jersey, and New York – have enacted laws in recent years that grant employees broader protections when it comes to certain sexual harassment and discrimination claims, enhancing employees’ abilities to speak out about alleged misconduct.

Article By Corbin Carter and Michael S. Arnold of Mintz

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

Congress Votes to Impose Bargaining Agreement to Avoid Nationwide Railroad Strike

Both the House and Senate have passed legislation under the Railway Labor Act to avoid a railroad strike by imposing the bargaining agreement brokered by President Joe Biden in September 2022.

The House already voted in favor of the legislation. (For details of the bill, see our article, President Biden Calls on Congress to Avoid Mass Railroad Strike.) With the Senate also voting to pass the main bill, by an 80-15 vote, the threat of a strike has been averted. The legislation moves to the president for his signature. Biden has indicated he will sign the bill.

While the House voted in favor of the separate, additional piece of legislation that would have added seven paid sick leave days annually for the rail workers, the Senate did not have enough votes to pass that bill. President Biden vowed in a separate statement to seek paid leave in the future not just for rail workers, but for all workers.

What was passed by Congress in its joint resolution was short and succinct. The three-page joint resolution stated that all tentative agreements entered into by the rail carriers and the unions were considered in effect as if they had been ratified. The exact terms of each collective bargaining agreement vary by union and were not part of the bill that was passed. This is a result of the special powers given to Congress under the Railway Labor Act.

All contracts contained generous wage increases: roughly 24 percent over four to five years with one extra day of leave. However, the other detailed terms will vary across the dozen national craft unions.

Article By Jonathan J. Spitz, Richard F. Vitarelli, James M. Stone, and James Verdi of Jackson Lewis P.C.

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Jackson Lewis P.C. © 2022

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.

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Copyright ©2022 National Law Forum, LLC

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

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