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Client Alert

Biden Administration Adds Sanctions Against Foreign Financial Institutions Supporting Russia’s Military-Industrial Base

February 5, 2024

by Lawrence Ward, Dave Townsend, and T. Augustine Lo

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As the February 2022 Russian invasion of neighboring Ukraine approaches its second anniversary and as Russia has increasingly turned to covert relationships with third country providers to avoid U.S., European Union and other global sanctions, the Biden Administration recently added new secondary sanctions to target foreign financial institutions (“FFI”) in third countries that participate in one or more “significant transactions” supporting Russia’s military-industrial sector. These new FFI sanctions seek to hobble Russia’s ability to wage war and expand the previous primary economic sanctions directed against Russian banks that have been in effect since 2021. The new rules resemble the secondary sanctions the United States had previously imposed on FFIs in third countries that choose to deal with Iran. The Office of Foreign Assets Control (“OFAC”) in the U.S. Department of the Treasury administers these new FFI sanctions.

President Biden issued Executive Order 14114 (“EO 14114”) on December 22, 2023[1] to expand previous Russian sanctions, particularly those issued under Executive Order 14024 (“EO 14024”).[2] Under EO 14114, the Secretary of the Treasury, in consultation with the Secretary of State, may designate any FFI to prohibit its use of U.S. correspondent banking and payable-through accounts (“CAPTA”) and to block any designated FFI’s assets in the United States if it has engaged in one or more “significant transactions” or provided services to persons who are subject to EO 14024 sanctions or who have supplied certain items to the Russian military-industrial base. EO 14114’s key operative language is laid out in Section 11(a), which states an FFI may be so designated if the Secretary of the Treasury and the Secretary of State conclude that it has:

(i)  conducted or facilitated any significant transaction or transactions for or on behalf of any person designated pursuant to section 1(a)(i) of this order for operating or having operated in the technology, defense and related materiel, construction, aerospace, or manufacturing sectors of the Russian Federation economy, or other such sectors as may be determined to support Russia’s military-industrial base by the Secretary of the Treasury, in consultation with the Secretary of State; or

(ii)  conducted or facilitated any significant transaction or transactions, or provided any service, involving Russia’s military-industrial base, including the sale, supply, or transfer, directly or indirectly, to the Russian Federation of any item or class of items as may be determined by the Secretary of the Treasury, in consultation with the Secretary of State and the Secretary of Commerce.

To implement this new FFI sanctions regime, the U.S. Treasury Department also issued concurrently on December 22, 2023 a new annex (“Annex”) listing specific goods that are deemed to support the Russian military-industrial complex and that thus will provide the basis for imposition of the new FFI sanctions.[3] These listed goods in the Annex include certain machine tools and manufacturing equipment; manufacturing materials for semiconductors and electronics; electronic test equipment; propellants and explosives; lubricants and additives; bearings; advanced optical systems; and navigation instruments.

The new FFI sanctions will have a broad scope as to entities that could become subject to an OFAC designation. EO 14114 defines FFIs to include “depository institutions; banks; savings banks; money services businesses; operators of credit card systems; trust companies; insurance companies; securities brokers and dealers; futures and options brokers and dealers; forward contract and foreign exchange merchants; securities and commodities exchanges; clearing corporations; investment companies; employee benefit plans; dealers in precious metals, stones, or jewels; and holding companies” and their affiliates and subsidiaries.” At the same time, EO 14114 expressly excludes the International Fund for Agricultural Development, the North American Development Bank and certain other intergovernmental organizations from the FFI definition.

EO 14114 also amends the existing ban under EO 14068 against U.S. imports of Russian-origin fish, seafood, alcoholic beverages, and non-industrial diamonds. We previously reported on this ban, which the Biden Administration issued in March 2022 in the wake of the Russian invasion of Ukraine. Now, under EO 14114, the U.S. Government may expand the EO 14068 import prohibition to reach products of third countries that use or incorporate such Russian-origin materials in their production. Significantly, this new EO 14114 ban would apply “notwithstanding whether such products have been incorporated or substantially transformed into other products outside of the Russian Federation.” The U.S. Treasury Department concurrently issued a determination to implement this expanded scope with respect to any fish, seafood, and preparations, regardless of origin, that were made from salmon, cod, pollock or crab that are wholly or in part from the Russian Federation, or that was harvested in Russian waters or by Russian-flagged vessels.

OFAC also concurrently issued two transitional general licenses (“GLs”) that allow for limited continuation of transactions that would otherwise be prohibited under EO 14114:

  • GL 83 authorizes transactions that are ordinarily incident to the import of seafood preparations with respect to products that are subject to the new ban against goods made from Russian origin salmon, cod, pollock or crab. GL 83 will remain in effect only until 12:01 am EST on February 21, 2024; and
  • GL 84 authorizes U.S. financial institutions to engage in transactions to close correspondent and payable-through accounts for FFIs that are designated under the new CAPTA sanctions. However, a U.S. financial institution will have only 10 days to complete such closing transactions after such a designation has been made.

OFAC has also issued interpretive guidance for these expanded sanctions. OFAC FAQ 1148 explains that a FFI could become designated for sanctions by engaging in any of the following activities:

  • Processing any “significant transaction” for persons that have been designated for EO 14024 sanctions because of their role in Russia’s military-industrial base;
  • Processing any “significant transaction” or providing any service involving Russia’s military-industrial base, including
    • “maintaining accounts, transferring funds, or providing other financial services to persons, either inside or outside Russia, that operate in the specified sectors of the Russian Federation economy”; and
    • “facilitating the sale, supply, or transfer, directly or indirectly, to the Russian Federation of certain items critical to Russia’s war effort identified in the determination of December 22, 2023.”

OFAC also issued a “Guidance for Foreign Financial Institutions on OFAC Sanctions Authorities Targeting Support to Russia’s Military-Industrial Base” (“OFAC Guidance”).[4] The OFAC Guidance specifically urges FFIs to refer to the Treasury Department’s Annex in conducting their due diligence efforts when transacting business that may be linked to Russia’s military-industrial base. The OFAC Guidance also provides examples of FFI due diligence practices that OFAC endorses.

Implications for FFIs and U.S. Importers

The new FFI sanctions under EO 14114 resemble other OFAC secondary sanctions such as the Iranian sanctions, which seek to dissuade persons in third countries from assisting persons already subject to OFAC’s primary sanctions. By calling out FFIs in third countries specifically, EO 14114 puts all such foreign banks on notice that they could lose access to the U.S. banking system and potentially even their ability to conduct any transactions in U.S. dollars if they provide banking or other financial services that support or assist Russia’s war-making capacity.  OFAC has assisted FFIs’ compliance by publishing its OFAC Guidance and its Annex of listed goods that the U.S. Government considers to be critical to the Russian military-industrial base, which a FFI could consult as part of its due diligence into financial transactions with any parties that may have a nexus to Russia and its targeted industrial sectors.

It is striking that EO 14114 appears to have a potentially low threshold to trigger a secondary sanctions designation because, by the terms of Section 11(a), even a single “significant transaction” could lead to an FFI’s designation by the Secretary of the Treasury and the Secretary of State. Presumably, if even one such transaction could be enough to lead to such an FFI designation, then a fortiori engaging in a series of such transactions in support of the Russian military-industrial base would be even more consequential under EO 14114.

In addition, U.S. importers should note that EO 14114’s expanded import ban on certain Russian-origin goods differs from ordinary practice under U.S. customs law. The EO 14114 ban against derivative products means that U.S. importers cannot claim the benefit of “substantial transformation” of affected Russian-origin goods in a third country to avoid the new import ban.  Since the 1930s, “country of origin” determinations for customs purposes generally have been governed by the “substantial transformation” rule, and U.S. importers have relied on that legal standard to determine the “country of origin” and applicable prohibitions for imported goods. Now, under EO 14114, U.S. importers may need to conduct more diligence to detect whether imported goods may incorporate any Russian-origin inputs even when the country of origin is outside Russia. EO 14114 also clarifies that its import ban applies to Foreign Trade Zones near U.S. ports, which are normally outside U.S. customs territory, but which cannot receive prohibited goods. 

Fortunately, at least thus far, the range of goods affected by the EO 14114 import ban is quite narrow and limited to certain kinds of fish, seafood, and preparations. Nonetheless, perhaps anticipating the difficulty this new prohibition could have on certain customs operations for U.S. importers and for the federal law enforcement officers who must screen such imported goods, EO 14114 requires the Secretary of Homeland Security, with the concurrence of the Secretary of the Treasury, to prescribe new rules and regulations to collect data that would enhance the enforcement of the new regime. 

If you have any questions regarding this eUpdate, please contact the attorneys profiled below. Dorsey’s attorneys in its National Security Group regularly counsel clients to address and mitigate the impact of U.S. economic sanctions, trade embargoes, export controls, CFIUS reviews or other national security measures that may affect cross-border transactions.



[2] EO 14024, issued on April 15, 2021, sought to deal with national security threats posed by specific Russian activities, including Russian efforts to undermine free and fair democratic elections and democratic institutions in the United States or in other allied nations; conducting or facilitating malicious cyber-related activities against the United States and its allies; encouraging and using transnational corruption to affect foreign governments; engaging in extraterritorial activities to target dissidents and journalists; weakening the security of countries or regions important to U.S. national security; and breaching established norms of international law, including respect for national territorial integrity.

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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.

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

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

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.