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Client Alert

Bank Regulatory Reform Arrives – Gingerly

May 31, 2018

by Joseph Lynyak and Nicholas A.J. Vlietstra

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On May 24, 2018, President Trump signed the Economic Growth, Regulatory Relief and Consumer Protection Act (the “Reform Act”).1

The bulk of reform in the Reform Act consists of the elimination of many technical and regulatory-overreach problems caused by the Dodd-Frank Act of eight years ago. The Reform Act is striking for what it does not do – it passes on dismantling the Consumer Financial Protection Bureau’s reach. Perhaps the most significant reform is that the Act prospectively raises the so-called “SIFI” (systemically important financial institution) level for enhanced prudential regulation from $50 billion to $100 billion immediately, and from $100 billion to $250 billion in 18 months. This change will reduce compliance costs for a large number of banks, and will likely inspire a wave of bank consolidation where such consolidation does not create SIFI status.

The Reform Act also provides a statutory exemption for small banks from the Volcker Rule. (With that statutory exemption in place, on May 30th the federal banking agencies issued a proposal to amend the Volcker Rule.) The Reform Act may pave the way for a great deal of regulatory relief through the administrative process.

This Alert provides: (a) a short history of the legislative process leading up to the Reform Act; (b) a summary by category of the Reform Act’s most significant provisions; and (c) an analysis of how financial regulatory reform may proceed over the next 12-month period.2 

A. Short History

From an historical perspective, whenever Congress has adopted comprehensive financial legislation intended both to respond to and contain a financial crisis, numerous legislative drafting mistakes are made that require repair in subsequent legislation. This typically occurs two or three years after the comprehensive financial legislation becomes effective—and is usually deemed to be consensus legislation on the part of both the House and Senate and the two parties.

In the case of the Reform Act, however, corrective legislation did not meet this time-frame because of the fear (possibly justified) on the part of Democrats that the Republican-controlled Congress would eviscerate the Consumer Financial Protection Bureau (the “CFPB”). Those fears were confirmed by the House when it adopted Chairman Hensarling’s Choice Act, which rolled back many of the prudential regulatory standards of the Dodd-Frank Act, and emphasized wholesale dismantling of the consumer protection authority of the CFPB (leaving it arguably less effective than its older cousin, the FTC).

Following the passage of the Choice Act in the House, Senate Democrats indicated that the Choice Act was a non-starter in that chamber.  In response, Republican Senator Mike Crapo, the Chairman of the Senate Committee on Banking, Housing and Urban Affairs, negotiated a small, moderate list of consensus Dodd-Frank Act corrective measures acceptable to the Democratic minority, which notably sidestepped dismemberment of the CFPB. 

Subject to only one provision directed at assisting large banks, Senator Crapo was able to convince several moderate Senate Democrats to support the Reform Act by emphasizing regulatory relief aimed at smaller community banks. Notwithstanding the House view that more aggressive reform measures should be considered, the House leadership adopted the Senate version of the legislation and sent the enrolled bill to the President for his signature (thus avoiding the necessity of a conference committee).

B. The Reform Act as Adopted

As noted above, the Reform Act was carefully negotiated by Senator Crapo to achieve consensus with moderate Democrats in the Senate by adopting several small regulatory relief measures correcting several problems arising from the Dodd-Frank Act. Accordingly, a fair reading of the range of reforms is that they consist primarily of the elimination of many technical and annoying overreach problems caused by the Dodd-Frank Act.

A summary of more significant provisions of the Reform Act – broken down into several categories – is as follows:

i. Regulatory Relief for Large Banks

Perhaps the most significant regulatory relief provision, Section 401 of the Reform Act prospectively raises the so-called “SIFI” (systemically important financial institution) level for enhanced prudential regulation from $50 billion to $100 billion immediately, and from $100 billion to $250 billion in 18 months. This change potentially saves smaller SIFIs no longer subject to enhanced prudential regulation collectively hundreds of millions of dollars in compliance costs (and reduces the number of SIFIs by approximately two-thirds).3  

As discussed in greater detail below, this increase in the level at which enhanced prudential standards would now apply may result in a wave of bank consolidations—not only among the SIFIs who will now fall well below the new minimum level, but among larger banks who have been hesitant to enter into consolidations lest they lose potential economies of scale due to increased compliance costs as the SIFI level is approached.

ii. Various Capital Calculations

The Reform Act includes several tailored modifications to capital calculations and related requirements for several categories of banks and holding companies, as follows:

  • Capital Relief for Custodial Institutions. Section 402 of the Reform Act provides capital relief for large custodial bank holding companies and their insured subsidiaries that “predominantly engaged in custody, safekeeping, and asset servicing activities.” For those entities, fiduciary and trust accounts will no longer be subject to the supplementary leverage ratio as calculated based upon Federal Reserve Board capital regulations. 
  • Municipal Securities Deemed High Quality Assets. Section 403 directs the federal banking agencies to amend their liquidity coverage ratio regulations to treat certain municipal securities as high quality assets—and thereby lower the capital risk retention requirement for banks holding those assets.

iii. Regulatory Relief for Smaller Banks

In order not to leave out smaller, community banks that have suffered by the trickle-down effect of enhanced prudential regulation imposed by bank regulators, the Reform Act adopts several provisions aimed at reducing the regulatory burden on smaller community banks, including the following:

  • New Community Bank Leverage Ratio. Section 201 of the Reform Act requires that the federal banking agencies establish a community bank leverage ratio of tangible equity to average total consolidated assets of not less than eight percent and not more than ten percent. Banks with less than $10 billion in total consolidated assets that maintain tangible equity in an amount that exceeds this new community bank leverage ratio will be deemed to be well capitalized and in compliance with risk-based capital and leverage requirements.
  • Elimination of the Volcker Rule to Smaller Banks. Section 203 eliminates the application of the Volcker Rule for banks with assets below $10 billion and total trading assets and trading liabilities that are not more than five percent of total consolidated assets.
  • Shortened Call Reports and Extended Examination Cycle. Sections 205 and 210 modify two burdensome reporting requirements for smaller banks, by mandating that banks below a $5 billion threshold in consolidated assets be allowed to use a shortened Call Report, and increased from a $1 billion to a $3 billion threshold below which the 18-month examination schedule would apply.4
  • Expanded Scope of the FRB’s Small Bank Holding Company Statement. In a technical change that could assist many small banks, Section 207 raises the consolidated asset threshold of the Federal Reserve’s Small Bank Holding Company Policy Statement (the “Policy Statement”) from $1 billion to $3 billion.5

iv. Consumer Laws and Operations

The Reform Act is also noteworthy for what it does not broadly address—namely the structure and authority of the CFPB. However, several industry-friendly provisions in the consumer arena and retail operations were adopted, as follows:

  • Mortgages Held in Portfolio by Smaller Banks and Credit Unions. Because of the liability that arises by not making a mortgage loan that qualifies as a “qualified mortgage” or “QM” under the Truth-in-Lending Act and the CFPB’s implementing Regulation Z, smaller community banks have been extremely reluctant to originate non-QM mortgages. Section 101 corrects this problem by providing that certain mortgage loans that are originated and retained in portfolio by an insured depository institution or an insured credit union with less than $10 billion in total consolidated assets will be deemed QMs.6
  • Modification of TILA’s 3-day Waiting Period. Section 109 eliminates the TRID 3-day waiting period if the lender extends a second offer of credit that has a lower annual percentage rate.7
  • HMDA Reporting Relief. Small volume mortgage loan originators (i.e., originating less than 500 closed-end mortgage loans or 500 HELOCs in each of the two preceding years) are exempt from reporting the expanded HMDA disclosures created by the Dodd-Frank Act. This will exempt a large percentage of financial institutions on a go-forward basis.8
  • TILA Relief for Loan Originators. Due to the time delay created when a loan originator (“LO”) switches employment, that individual was precluded from working in the capacity of an LO while his/her LO license was transferred (primarily through the NMLS registration system). Section 106 provides a 120-day period during which the LO may continue working while the subject license is processed.9
  • Online Banking and Identity Theft. Section 213 allows banks and credit unions to utilize information from a driver’s license or an identification card when opening new accounts for customers when an application is made through the internet or a mobile banking application. 
  • TILA Escrow Relief. Section 108 exempts insured depository institutions and insured credit unions with less than $10 billion in assets from TILA’s escrow requirements.
  • Manufactured Home Exemption.  Section 107 excludes from the definition of “mortgage originator” an employee of a retail manufactured home seller who does not receive compensation or gain for taking residential mortgage loan applications.
  • Preemption of State Credit-Freeze Laws. Section 301 preempts state credit-freeze laws and adopts a national standard for placing and removing credit freezes, including a direction to the FTC to coordinate the process by creating a webpage to access credit reporting agencies.

v. Miscellaneous

In addition to the categories described above, the Reform Act has numerous individual provisions that are minor in nature, technical and non-controversial. They include, among others: (a) several reports required to be prepared by various federal agencies; (b) relief from the FDIC’s reciprocal deposit rule; (c) increasing the mutual saving association size to allow those institutions to operate as a national bank without switching charters; (d)  expanding the definition of a 1-to-4 family dwelling for credit unions; (e) instructing the Social Security Administration to create a database to assist in preventing identity theft; (f) instructing that certain Acquisition, Development, and Construction (“ADC”) loans that meet specified criteria will not be subject to a heightened risk weighting under the banking agencies’ risk-based capital rules; (g) relieving some disclosure burdens for issuers that offer securities to employees through compensation plans; and (h) raising from 100 to 250 the number of investors in a “qualified venture capital fund” that is exempt from SEC registration.

Finally, the Reform Act adopts several procedural protections for veterans and consumers, including: (1) modifying consumer reporting information on certain debt incurred by a veteran; (2) protecting veterans from predatory action relating to refinancings; (3) expanding for one year the stay on foreclosure for a veteran after the veteran’s service ends; (4) providing protections for whistleblowers for senior abuse; (4) permanently reinstating the Protect Tenants at Foreclosure Act; (5) requiring that Fannie Mae and Freddie Mac establish a process for validating credit scoring models; and (6) enhancing protections for student borrowers.

C. Observations 

We offer the following initial observations:  

First, in regard to regulatory reform going forward, virtually every corrective measure included in the Reform Act requires rule-making by the federal banking agencies. That is because in many instances the Reform Act’s provisions directly modify or negate existing regulations currently in effect that will require notice and comment. This process will likely take the remainder of 2018 (and probably extend well beyond). 

However, the Reform Act is extremely compatible with the report issued by the Department of the Treasury in June of 2017, in which numerous administrative actions were identified that could significantly ease the compliance burden on banks and their affiliates.10 

The Reform Act, therefore, could be a prism through which rulemaking might be accelerated. For example, joint agency rulemaking is extremely difficult—modifying existing joint agency rules seemingly impossible. However, with the statutory exemption for small banks from the Volcker Rule now in place, the federal banking agencies announced a proposal to amend the Volcker Rule. The Reform Act may ultimately have a similar salutary effect on regulatory relief through the administrative process.11  

Second, we note that the most significant statutory change—the increased SIFI floor—may occasion a wave of merger activity in the banking sector. Over the past several years, medium to larger-sized bank holding companies and banks have been reluctant to make strategic acquisitions of other larger-sized institutions because of the regulatory penalty associated with exceeding the SIFI level (and incurring enhanced prudential scrutiny). As a result of the SIFI asset floor increase, the opportunity may be available for expanded interstate acquisitions and enhanced economies of scale— with diminished risk management obligations. 


1 S.2155 
2 Although most of the provisions of the Reform Act are immediately effective, due to the necessity of modifying or issuing new regulations, it will be incumbent upon the banking agencies to provide guidance regarding compliance as soon as possible.
3 Foreign banks with greater than $100 billion in total assets will not qualify for this expanded relief.
4 The 18-month exam cycle would only apply to community banks that are well managed and well capitalized.
5 The Policy Statement permits small bank holding companies and saving and loan holding companies to hold a higher level of debt than is generally permitted for holding companies (and facilitates acquisition strategies).
6 Certain documentation and other requirements are necessary.
7 In a criticism of the CFPB’s former leadership, Section 109 also includes a statement urging the CFPB to issue reliable guidance in this complicated area.
8 Note that the data will still be required to be gathered by exempted entities, and the exemption is lost if the institution’s CRA rating is “needs to improve.”
9 Section 106 also extends civil liability protection to government officials who make good faith errors related to the collection, furnishing, or dissemination of information with respect to people registered with the NMLS.
10 A Financial System That Creates Economic Opportunities—Banks and Credit Unions—A Report to President Donald J. Trump.
11 With the confirmation of the Administration’s nominee to head the FDIC, President Trump’s financial services leadership is now completely in control. The Administration now owns regulatory relief, and excuses for delays based upon Obama hold-overs in key agency positions no longer apply.

Firm Highlights

Insights

SEC Proposes Expansion of Investment Adviser Performance-Based Compensation Rule

On September 30, 2026, the Securities and Exchange Commission (the “SEC”) proposed amendments to Rule 205-3 under the Investment Advisers Act of 1940, as amended (the “Advisers Act”), which provides an exemption from the general prohibition under Section 205(a)(1) of the Advisers Act on registered investment advisers receiving performance-based compensation (the “Proposal”) so long as performance-based compensation is limited to “qualified clients”.1 Most notably for private fund sponsors, the Proposal would expand the definition of “qualified client” to include any investors that satisfy the “accredited investor” definition under Regulation D. The Proposal may also have implications for private fund managers that rely on exemptions from investment adviser registration under state law because certain state-level investment adviser registration exemptions incorporate or otherwise reference the federal qualified client definition. Expansion of the Qualified Client Definition Under the current Rule 205-3, an investor generally may qualify as a qualified client if, among other alternatives, the investor has at least $1.4 million under management with the adviser or has a net worth exceeding $2.7 million. These thresholds are higher than the financial thresholds applicable to many accredited investors under Regulation D. As a result, an investor may currently qualify as an accredited investor for purposes of investing in a private offering without qualifying as a qualified client for purposes of paying performance-based compensation. The Proposal would expand the qualified client definition to include any natural person or legal entity investor that satisfies the accredited investor definition under Regulation D. The Proposal would also remove the assets under management and net worth thresholds under the current Rule 205-3 qualified client test. For private funds relying on Section 3(c)(1) of the Investment Company Act of 1940, this change could reduce the need to apply a separate qualified client standard to investors that already qualify as accredited investors. Dorsey Observations and Next Steps If adopted as proposed, the expanded qualified client definition could be particularly significant for private fund managers. Most private fund offerings are already limited to accredited investors under Regulation D. However, the Proposal could expand the pool of prospective investors available to emerging private fund managers while reducing the regulatory burden associated with complying with Rule 205-3. The Proposal could also benefit advisers operating below the SEC registration threshold that rely on a state private fund adviser exemption. A number of states have adopted exemptions modeled on the North American Securities Administrators Association (“NASAA”) private fund adviser exemption, which may condition relief for advisers to certain funds relying on Section 3(c)(1) on each beneficial owner satisfying the federal qualified client definition. However, state requirements vary, and any effect of the Proposal would depend on the text of the applicable state exemption and how it incorporates Rule 205-3. Many emerging private fund managers may have a larger network of accredited investor relationships than qualified client relationships during the early stages of their investment advisory business. Currently, under Rule 205-3, private fund managers may receive performance-based compensation from investors who do not satisfy the qualified client definition if those investors were admitted to their private funds prior to registration with the SEC. Following registration with the SEC, however, managers may continue to permit investors that are not qualified clients to invest in future private funds but may not receive performance-based compensation from those investors with respect to such investments. In addition, because the net worth and assets under management thresholds for qualified client status are adjusted for inflation every five years, the pool of qualified client investors may diminish over time as previously eligible investors no longer satisfy the applicable thresholds. The Proposal could provide the dual benefit of greater flexibility for private fund managers to establish and maintain relationships with accredited investors as their businesses scale and they become registered with the SEC, and greater flexibility for certain accredited investors to participate in investment strategies that historically have been restricted to much larger institutional investors. Unless and until the Proposal is adopted, investment advisers should continue to comply with the existing qualified client requirements. If the Proposal is adopted, private fund sponsors should consider whether corresponding changes are appropriate for their subscription documents, investor questionnaires, and other offering materials. Advisers that are state-registered or rely on a state-level exemption should also consult the laws and regulations of each relevant jurisdiction before changing investor eligibility standards or performance-based compensation practices, because adoption of the federal amendments may not automatically modify state requirements. Comments on the Proposal will be due 60 days after publication in the Federal Register. 1 Investment Adviser Performance-Based Compensation Modernization, Investment Advisers Act Release No. IA-7022 (Sept. 30, 2026), available at https://www.sec.gov/rules-regulations/2026/09/s7-2026-28#33-11443proposed.

Insights

Energy Law: Month in Review - September 2026

Welcome to Dorsey’s Energy Law: Month in Review. We provide this update to our clients to identify significant developments in the previous month. Please reach out to any of the authors, listed above, to discuss these issues. Regulatory Developments Massachusetts Ratchets Up State and Local Regulation of AI Data Centers In early September, Governor Maura Healey of Massachusetts signed an executive order requiring that artificial intelligence data centers secure the approval of local communities as a precondition to proceeding with a given project. According to the terms of the order, data center developers will need to secure a “community benefits agreement” as a precondition to receiving permits from numerous state agencies, including the Department of Environmental Protection, the Energy Facilities Siting Board, and the Massachusetts Environmental Policy Act Office. Beyond requiring community benefits agreements, the order also mandates that developers mitigate utility costs to consumers, prohibits the use of nondisclosure agreements, and requires various state agencies to develop measures to limit data center impacts on the environment. North Carolina Regulators Decline Approval of Duke Energy Gas Turbine On September 18, 2026, North Carolina Utilities Commission (NCUC) denied Duke Energy’s application for a certificate of public convenience and necessity required to construct a gas-fueled combustion turbine at its Smith Energy Complex in North Carolina. The NCUC objected strongly to the $584 million price tag and noted that Duke appeared to be constructing the facility “based on anticipated data center customer additions.” The NCUC rejected that anticipated growth as “insufficiently reliable for the Commission to act at this point.” In rejecting Duke’s application, the NCUC also noted that Duke had signed the White House Ratepayer Protection Pledge, in which it represented that it would not shift data center costs to consumers. The NCUC observed that the record did not demonstrate how Duke “intends to adhere to its commitments under the Ratepayer Protection Pledge with regard to the Proposed Facility.” Notably, commission staff had actually supported the construction of the turbine, citing concerns about Duke’s reserve margins. The NCUC noted that it “understands the Public Staff’s expressed concerns,” but those concerns were outweighed by the NCUC’s reservations, including questions of demand. Department of Energy Approves Funds for Grid Improvement The U.S. Department of Energy (DOE) recently announced that it would fund 31 grid-improvement projects in 26 states. The funding initiative is part of the DOE’s “SPARK” initiative. The funding will include $1.9 billion in federal funding from DOE and $3.35 billion in recipient cost-sharing funding. The funds will go to projects designed to improve grid reliability and lower electricity costs. Recipients plan to reconductor over 1,500 miles of transmission lines and will deploy grid-enhancing technologies across approximately 21,000 miles. DOE stated that this initiative will make available over 23 additional gigawatts of electricity. Texas Moderates Rules Governing Data Center Interconnection The Texas Public Utility Commission adopted new regulations governing large-load interconnections. The rules impose a flat study fee of $100,000 for all proposed interconnections, which departs from the initial proposal to impose study fees using a tiered system based on project size. Additionally, the final rule eliminates the PUC’s previous proposal to impose a non-refundable interconnection fee of $50,000 per MW of contracted peak demand. The final rule also moderates the initially proposed regulations governing Electric Reliability Council of Texas (ERCOT) notifications for large-load customers’ non-utilized capacity. The proposed rules would have required notifying ERCOT within 30 days of missing a scheduled energization milestone by six months. The final rules, however, do not require informing ERCOT unless a scheduled energization milestone is missed by 24 months. FERC Denies TransAlta 202(c) Cost-Recovery Plan The Federal Energy Regulatory Commission (FERC) recently rejected TransAlta’s plan to recover $19.9 million in expenses stemming from a DOE order in which DOE prohibited TransAlta from retiring its coal-powered Centralia power plant. TransAlta had previously intended to retire the facility at the end of 2025. TransAlta’s cost recovery plan proposed spending an additional $23 million on repairs to continue operating the unit. FERC’s main objection had to do with geographic scope. TransAlta’s recovery plan called for recovering costs from California Independent System Operator (CAISO) and the Southwest Power Pool (SPP), but the DOE’s order requiring operation of the plant was designed to ensure reliability in the Northwest assessment area (Montana, Oregon, Washington, and parts of northern California and northern Idaho). Accordingly, FERC was unwilling to allow cost recovery from CAISO and SPP when the order that precipitated the additional costs only related to the Northwest assessment area. FERC informed TransAlta that it would only approve cost recovery from load-serving entities in the Northwest assessment area. FERC’s decision comes amid a rush of DOE emergency orders requiring the continued operation of coal-fired generating units. Litigation Appeals Court Upholds Washington Hydropower Plant With Caveats In a September 21, 2026, opinion, the Washington Court of Appeals largely upheld a Clean Water Act water quality certification by the Washington Department of Ecology for the Goldendale Energy Storage Project, a proposed pumped-water storage hydropower system adjacent to, but off-stream from, the Columbia River. A nonprofit (Columbia Riverkeeper) and the Confederated Tribes and Bands of the Yakama Nation appealed the certification, contending that it failed to impose necessary conditions and monitoring requirements to protect the water quality of the Columbia River. Most saliently, the plaintiffs argued that the project had the potential to leak 100 acre-feet of water per year into tributaries of the Columbia River. The Court of Appeals broadly rejected plaintiffs’ challenge to the state’s conclusion that “the project was designed not to leak.” That said, the Court of Appeals did reverse on one narrow issue. Specifically, the court determined that the state’s conclusion that “leakage from the project’s tunnels would be monitored and reported” was not supported by the evidence because the certification “does not explicitly require monitoring and reporting to determine whether there is any leakage.” Accordingly, the court remanded the matter to the state to impose monitoring and reporting requirements but otherwise affirmed the certification. Legislative Developments California Legislates Restrictions on Data Center Energy Use and Grid Costs On September 21, 2026, California Governor Gavin Newsom signed seven bills broadly regulating data centers in the state. SB 1168 directed the California Public Utilities Commission to assess the energy used by data centers. It also requires the PUC to pass costs of transmission and distribution upgrades and load increases on to data centers, rather than customers. SB 886 and SB 887 compel data centers to pay for infrastructure upgrade and generation costs, and wildfire mitigation costs, in addition to imposing environmental review. The statutes additionally increase local oversight of data centers. AB 1577 imposes a monthly reporting requirement that requires data centers to supply energy consumption and efficiency data to the California Energy Commission. AB 2383 contains incentives for data centers to use onsite clean energy generation. Finally, AB 2469 and AB 2619 require data center developments to assess water supply and develop a water scarcity plan. The statutes also mandate statewide water reporting as a precondition to obtaining and renewing business licenses.

Insights

The Supreme Court Update - October 8, 2026

On September 29, 2026, the Supreme Court granted certiorari in one case: Department of Homeland Security v. D.V.D., No. 26-426: This case concerns the Trump Administration’s “third-country removal” procedures, where immigrants are deported to countries not listed in the removal orders. In granting certiorari, the Court granted the Government’s application to stay a lower court decision halting the practice, which will allow third-country removals to continue pending resolution of the case. The issues presented are: (1) Whether the district court had jurisdiction over respondents’ claims; (2) whether the district court had authority to enter class-wide declaratory relief and APA vacatur under 8 U.S.C. § 1252(f)(1); (3) whether the Government’s guidance on third-country removals is unlawful under 8 U.S.C. § 1231(b), the due process clause, or FARRA/CAT and its implementing regulations; and (4) such other questions that the Government determines are appropriate for the proper disposition of the case. On October 1, 2026, the Court granted certiorari in three additional cases: Rhoney v. Barbosa da Cunha, No. 26-104: Immigration officials detained Ricardo Aparecido Barbosa da Cunha—a Brazilian citizen who had lived in the United States for approximately twenty years after entering without inspection—and denied him a bond hearing under 8 U.S.C. § 1225(b)(2)(A). The Second Circuit held that his detention was instead governed by § 1226(a), which permits release on bond, because § 1225(b)(2)(A)’s mandatory-detention requirement applies only to noncitizens apprehended while entering the country or shortly thereafter. The question presented is: Whether 8 U.S.C. § 1225(b)(2)(A) mandates the detention pending removal proceedings of aliens who, like Barbosa da Cunha, are present in the United States without having been admitted. Missionaries of St. John the Baptist, Inc. v. Frederic, No. 25-113: A Catholic religious organization sought to build a shrine to the Virgin Mary on land the organization owned adjacent to its church in Park Hills, Kentucky. Local zoning restrictions prohibited the proposed construction. The question presented is: Whether a land-use regulation that prohibits a religious institution from building a religious structure on its own property constitutes a “substantial burden” on religious exercise under the Substantial Burden Provision of the Religious Land Use and Institutionalized Persons Act, 42 U.S.C. § 2000cc(a). Marschner v. Marschner, No. 25-1349: Under the Uniformed Services Former Spouses’ Protection Act (“USFSPA”), a veteran’s longevity-based retirement pay can be divided in a divorce, but retirement pay based on disability and retirement pay that was waived to receive disability pay are indivisible. The question presented is: Does the USFSPA require state courts to refuse enforcement of indemnification provisions in a divorce settlement agreement?

Insights

EPA Limits Title V Re-Litigation of NSR Permits

Overview On September 25, 2026, the U.S. Environmental Protection Agency (“EPA”) published a final rule that significantly limits the ability of third parties to use the Clean Air Act (“CAA”) Title V permitting process to revisit New Source Review (“NSR”) permitting decisions years after those decisions were made. The rule establishes that NSR permitting determinations generally must be challenged during the original permitting proceeding, thereby providing regulated sources with greater permitting certainty and finality for major capital projects. Published in the Federal Register titled Clarifying the Scope of “Applicable Requirements” Under State Operating Permit Programs and the Federal Operating Permit Program (Docket ID No. EPA-HQ-OAR-2023-0401), the rule amends 40 C.F.R. Parts 70 and 71 to codify EPA’s interpretation regarding when requirements established under other CAA programs may be reviewed, modified, or implemented through the Title V operating permit program. The rule becomes effective 30 days after publication. The rule addresses two principal issues: (1) the relationship between NSR preconstruction permitting and Title V operating permits, and (2) the treatment of the General Duty Clause under CAA section 112(r)(1). Most significantly, the rule provides greater certainty for sources navigating the NSR permitting process. EPA’s amendments are intended to ensure that NSR permitting decisions made through an approved public process are generally not revisited later through Title V permit proceedings. The rule responds to a circuit split between the U.S. Courts of Appeals for the Fifth and Tenth Circuits. In Environmental Integrity Project v. EPA, 969 F.3d 529 (5th Cir. 2020), the Fifth Circuit upheld EPA’s interpretation, concluding that it was consistent with the text, structure, and purpose of Title V. In contrast, the Tenth Circuit reached the opposite conclusion in Sierra Club v. EPA, 964 F.3d 882 (10th Cir. 2020), finding that the then-existing regulatory definition of “applicable requirement” did not support EPA’s position. By amending the regulatory language on which the Tenth Circuit relied and codifying the interpretation approved by the Fifth Circuit, EPA has established a nationwide framework governing the interaction between NSR and Title V. NSR and Title V: EPA Establishes a Uniform Nationwide Framework At the core of the rule is EPA’s effort to define the respective roles of NSR and Title V. The rule codifies the approach EPA has applied since 2017: once a source obtains an NSR permit under an EPA-approved permitting program, and that permit was issued following public notice with an opportunity for comment and judicial review, the permit establishes the NSR-related “applicable requirements” of the State Implementation Plan (“SIP”) or Federal Implementation Plan (“FIP”) for Title V purposes. Under this framework, Title V is not a vehicle for re-examining underlying NSR permitting decisions. EPA does not intend to use the Title V process to revisit applicability determinations, emissions calculations, control technology determinations, permit conditions, or other issues resolved through the NSR permitting process. This principle applies regardless of the stage of the Title V proceeding; whether the NSR permit was issued pursuant to a SIP or FIP; the type of NSR issue involved; or whether the NSR permit is incorporated into Title V sequentially or concurrently. Limited Exceptions EPA recognizes several circumstances in which NSR issues may still be reviewed through the Title V program: No NSR permit was issued at all; The permit was issued without public notice and an opportunity for comment and judicial review; or The issue involves substantive overlap between Title V and NSR requirements, such as the adequacy of monitoring provisions. As a result, the rule does not insulate unpermitted projects or foreclose review of matters that independently arise under Title V. Key Regulatory Amendments The rule revises the definition of “applicable requirement” in 40 C.F.R. §§ 70.2 and 71.2. Paragraph (1): Where an NSR permit is issued with public notice and an opportunity for comment and judicial review, the permit establishes and defines the applicable SIP or FIP requirements for Title V purposes. Paragraph (2): All NSR permit terms, including terms contained in minor NSR permits, constitute applicable requirements that must be incorporated into Title V permits. Paragraph (4): CAA section 112(r)(1) (the General Duty Clause) is expressly excluded from the definition of “applicable requirement,” while section 112(r)(7) Risk Management Program requirements remain included. EPA also amended 40 C.F.R. §§ 70.8 and 70.12 to clarify that alleged defects in requirements established outside the Title V process generally do not provide a basis for EPA objection to a Title V permit or for a Title V citizen petition. General Duty Clause Exclusion The rule also codifies EPA’s longstanding position that the General Duty Clause in CAA section 112(r)(1) is not an “applicable requirement” for Title V purposes. EPA points to several considerations supporting that conclusion, including the distinction between the General Duty Clause and Title V permit terms, the provision’s origins in the Occupational Safety and Health Act’s general duty clause, and the different enforcement structures applicable to the General Duty Clause and Title V permit requirements. Importantly, excluding section 112(r)(1) from the definition of “applicable requirement” does not eliminate EPA’s authority to enforce the General Duty Clause independently of the Title V program. The final rule instead clarifies that the General Duty Clause need not—and should not—be incorporated into Title V permits as an applicable requirement. Practical Implications for Regulated Sources Greater Finality for NSR Permits  For projects requiring PSD, nonattainment NSR, or minor NSR permits, the permitting process becomes the primary forum for resolving disputes regarding applicability determinations, emissions calculations, control technology requirements, offsets, and permit conditions. Once an NSR permit is issued through a qualifying public process, regulated sources should face substantially reduced risk that those same issues will be challenged years later through Title V permit proceedings. Reduced Risk of Collateral Permit Challenges Stakeholders have sometimes sought to use Title V permit issuance, renewal, revision, or citizen-petition proceedings to challenge underlying NSR determinations. The final rule makes clear that Title V is not the appropriate vehicle for challenging whether an applicable requirement was correctly established in the first instance. This should reduce the risk of permit delays and uncertainty associated with collateral challenges to previously issued NSR permits. The rule does not, however, eliminate all Title V challenges relating to an NSR permit. Challenges concerning the Title V permit itself—including whether it appropriately incorporates applicable requirements or contains adequate compliance provisions—remain possible. Increased Importance of the Initial NSR Proceeding Because Title V generally will not provide a second opportunity to challenge the substantive validity of an NSR determination, the administrative record developed during the NSR process becomes increasingly important. Permit applicants should ensure that applicability analyses, emissions calculations, control technology evaluations, modeling demonstrations, and supporting technical documentation are thoroughly developed during the original permitting proceeding. For significant projects, applicants may therefore have an additional incentive to identify and resolve potential permitting issues before the NSR permit is issued rather than assuming that unresolved issues can be addressed during a subsequent Title V proceeding. Potential Incentive for Broader Public Participation EPA also notes that permitting authorities may choose to provide public notice and an opportunity for comment for a broader range of NSR permits because permits issued through a qualifying public process receive the benefit of the finality framework established by the rule. Some permitting authorities may conclude that greater public participation at the NSR stage is preferable to uncertainty during subsequent Title V proceedings. Conclusion The final rule is principally a permitting-certainty measure. For sources that obtain NSR permits through a public process, EPA has substantially limited the ability of third parties to revisit underlying NSR determinations through the Title V program. As a result, regulated entities should benefit from greater finality regarding key permitting decisions, reduced risk of collateral permit challenges, and increased certainty when planning and implementing capital projects.