.

Client Alert

SEC Enforcement after Kokesh and Cohen

August 2, 2018

Download as a PDF

Share this page

The remedies the Securities and Exchange Commission (“SEC”) can seek in its enforcement actions are a critical question in the wake of the Kokesh v. SEC,  137 S.Ct. 1635 (2017) and SEC v. Cohen,  Civil Action No. 17-cv-430 (S.D.N.Y. Order entered July 12, 2018). Specifically, the Cohen Court dismissed the SEC’s amended Foreign Corrupt Practices Act (“FCPA”) complaint against Michael Cohen and Vanja Baros, each of whom was employed by a subsidiary of hedge fund management firm Och-Ziff Capital Management LLC (“OZCM”), based on the statute of limitations and Kokesh. SEC v. Cohen, Civil Action No. 17-cv-430 (S.D.N.Y. Order entered July 12, 2018).

Background

The FCPA charges, first asserted in a complaint filed on January 26, 2017, center on a scheme to bribe African officials in various countries from 2007 through 2011. Messrs. Cohen and Baros are former employees of OZCM, or one of its subsidiaries, based in London. 

The scheme allegations center around a series of transactions, each of which took place during a four year time period beginning in 2007. The first two transactions center on Libya and 2007. The business was sought for the firm in Libya when it was ruled by Colonel Muammar Gaddafi. Mr. Cohen enlisted Agent 1 who supposedly had connections to the ruling family. That person introduced Mr. Cohen to a son of Mr. Gaddafi who supposedly was the driving force behind the Libyan Investment Authority. A $3.75 million “deal fee” was demanded which Mr. Cohen understood would be used to pay kickbacks in return for investments. The Libyan Investment Authority invested $300 million in OZCH managed funds. The arrangement netted OZCH about $100 million in fees. 

The second Libya transaction focused on a real estate deal. To arrange for leases on real estate on which key developments would take place Agent 1 gave equity in the development company responsible for the project to a government official and Mr. Gaddafi’s daughter. Mr. Cohen arranged for OZCM to provide a $40 million convertible loan for the development and paid Agent 1 a $400,000 deal fee used to bribe government officials. 

Other transactions took place in, and involved, other countries. For example, a transaction involving mining rights in Chad and Niger began with an $86 million loan extended by OZCH in May 2007 through a Turks & Caicos entity. The purpose was to acquire mining rights and licenses in the two countries and invest in an African focused oil exploration firm. It was also to pay bribes to facilitate the deal. The bribes were arranged by Agent 2 and included payments to high ranking government officials in Chad and Niger. 

There were also transactions centered on the Democratic Republic of the Congo (“DRC”). In December 2007, for example, Defendants began discussions with Agent 3 about forming a joint venture to consolidate various DRC mining assets into a single, large mining company. On March 7, 2008 Agent 3 emailed Mr. Cohen regarding a plan to effect the consolidation. The first step involved OZCH acquiring a $150 million stake in a DRC focused mining company the agent controlled. The stake was purchased. Agent 3 then paid $11 million in bribes to certain officials. The DRC Mining Company, however, did not use the funds as planned. Rather the funds were used to acquire a platinum mining asset in Zimbabwe. Subsequently, the proceeds from the investment were used for a “loan” to affiliates of the ruling regime in Zimbabwe. 

Transactions in the DRC also included: One in which Defendants arranged for OZCM to enter into a $124 million convertible loan agreement through another entity with a DRC holding company. The point was to acquire a Congolese entity and fund future mining operations with the DRC. In another Agent 3 paid bribes to DRC officials to secure authorization for the scheme. DRC officials were bribed in part through a $130 million lending arrangement to a British Virgin Islands entity controlled by Agent 3 allowing for the consolidation of the mining holdings and their eventual sale. 

A 2010 transaction was implemented to provide funds for Agent 2 to bribe Guinean government officials in connection with another deal. To facilitate the transfer Defendants arranged for the purchase of 31.5 million shares of the London Mining Company for $25 million by a Turks & Caicos entity. Those shares were then sold in part to one of the funds established by the joint venture the hedge fund management company had entered into through African Management Limited for $77 million. The windfall profits permitted the payment of bribes to the Guinean government for the transaction. 

Finally, in May 2011 a transaction was entered into that involved the acquisition of a 25% stake in an oil field off the coast of Congo-Brazzavilee. A third party South African entity tied to the ANC would receive a stake for free. While the deal initially stalled because of regulatory concerns by Ochs-Ziff’s legal department, Mr. Cohen restructured it and secured approval.

The opinion

Defendants moved to dismiss based on §2462 of Title 28 and the Supreme Court’s decision in Kokesh. The section provides for a five year statute of limitations for “any proceeding for the enforcement of any civil fine, penalty, or forfeiture, pecuniary or otherwise . . .” In Kokesh v. SEC, the Court held that this limitation period applies to requests for disgorgement by the SEC since they constitute a penalty within the meaning of the statute. 

Here the parties agreed that the transactions took place between May 30, 2007 and April 15, 2011, years before the complaint was filed. The SEC claimed, however, that §2462 applies only to remedies, a question that should be considered later in the case, that the claims against Mr. Cohen were tolled and that it should be permitted to conduct discovery. The Court rejected each claim. 

First, a motion to dismiss is the proper vehicle for considering the statute of limitations questions in this case. While the statute of limitations is typically an affirmative defense “a court may dismiss a complaint for failure to state a claim if the allegations in the complaint . . . show that relief is barred by the applicable statute of limitations . . . This general rule applies with particular force to §2462, which prohibits the court from ‘entertainin[ing] actions that accrued more than five years earlier . . .’” While the statute focuses on remedies as Plaintiff contends, this does not change the analysis. 

The fact that an injunction is sought here and that the Commission reserved the right to take discovery does not preclude considering the statute of limitations on a motion to dismiss. If the injunction operates as a penalty it would be barred by the statute. Furthermore, “it would make no sense if the SEC could evade the statute of limitations by alleging untimely misconduct and then demand discovery in the hopes of uncovering misconduct within the limitations period.” Such discovery would be nothing but a “fishing expedition” which will not be permitted. 

The tolling agreements executed by Mr. Cohen also do not preclude the application of the statute of limitations at this stage of the proceedings. While Mr. Cohen did execute tolling agreements which extended the statute by 21 months, that does not save the action here. The tolling agreements related to the investigation captioned In the Matter of Libyan Investment Authority. Those transactions took place in 2007 and 2008. Mr. Cohen did not agree to toll matters that arose from the investigation captioned In the Matter of Och-Ziff Capital Management, LLC. Since the other transactions on which the amended complaint here is based arose from this investigation, the tolling agreements to not apply to them by their plain terms, despite the SEC’s claims to the contrary. 

Second, in view of the dictates of §2462 and the Supreme Court’s holding in Kokesh, the Court concluded that the SEC’s claims for disgorgement and an injunction, under the facts here, are untimely and must be dismissed. The statute of limitations runs from the time the Defendants engaged in the alleged misconduct. In this regard the statute specifically states that the claim accrues when the fraudulent conduct occurs. Plaintiff’s assertion that it does not begin to run until the person received compensation from the misconduct is not supported by the statute or any authority. Indeed, “if the SEC were correct that a claim for disgorgement accrues only when the defendant receives iii-gotten gains . . . that would mean Defendants’ receipt of ill-gotten gains was an element of the SEC’s ‘disgorgement claims,’ which the SEC would need to have plausibly alleged in its complaint. Because the Commission has not actually alleged that Defendants received any ill-gotten gains, the court would therefore need to dismiss the SEC’s ‘disgorgement claims’ for failure to state a claim.” While the SEC claimed that it is “reasonable to infer” that there were ill-gotten gains, a complaint cannot be amended by presenting new material in an opposition to a motion. 

Plaintiff’s request for injunctive relief is also time barred. Under the facts here that injunction “would operate at least partially as a penalty . . .” On its faces § 2462 does not specifically apply to an injunction. While some courts have held that the section does not apply to injunctions others have reached a different conclusion. More importantly, the conclusion that “injunctions are categorically exempt from §2462 is inconsistent with Kokesh. Under that decision the question of whether the injunction is a penalty is a function of if it is sought to redress alleged wrongs to the public and not just individuals and if it would at least in part function as a penalty. 

In this case the Kokesh analysis compels the conclusion that the injunction sought would at least in part function as a penalty. The there is no doubt that the violations alleged were committed against the United States, rather than an aggrieved individual. Likewise, the “parties agree, this injunction would impose no duties on Defendants beyond their existing duty to obey the law . . . What this injunction would do, however, is mark Defendants as lawbreakers and ‘stigmatize [them] in the eyes of the public.’” [internal citations omitted]. Under these circumstances, there is no doubt it would function at least in part as a penalty which is sufficient for the application of the statute of limitations. While the Eighth Circuit in reaching a contrary result discussed the “primary purpose” of the injunction “[t]o the extent Collyard [SEC v. Collyard, 861 F. 3d 760 (8th Cir. 2017)] suggests that a remedy is not a §2462 penalty if the remedy’s penal effect is only incidental to its remedial effect, the court respectfully finds this suggestion at odds with Kokesh.” The amended complaint is dismissed and leave to amend denied. 

Comment

Kokesh and Cohen present at least two significant issues for SEC Enforcement.  First, the straight forward application of the five year statute of limitations creates a potential issue.  Many SEC investigations focus on years old conduct, particularly in the FCPA area as in this action.  The time limitation imposed by the five year statute of limitations will present a significant challenge in those cases.  Those difficulties include not just the question of whether an injunction is viewed as a penalty but if it can be issued even if it is considered as equitable. If the facts in the case are outside the statute of limitations the court may well take the position that an injunction cannot issue under Rule 65, Fed. R. Civ. P. which requires that injunctions be based on specific facts.  See, e.g., SEC v. Jones, Civil Action No. 17-11226 (D. Mass. Opinion January 5, 2018). 

Second, the teachings of Kokesh can further delimit the remedies available to the Commission.  If, for example, the injunction sought is viewed as a penalty, the court may decline to enter it as in Cohen.  Disgorgement, traditionally an equitable remedy, may also be denied as a time barred penalty as it is presently configured by the agency under Kokesh.  Finally, even if the disgorgement sought in a particular case is not time barred, if it is viewed as a penalty a court might decline to enter it as inappropriate in view of the fact that Congress has given the SEC statutory authority to seek monetary penalties.  Thus, seeking a “disgorgement penalty” and a statutory penalty would be nothing but impermissible piling-on and overkill if not grossly unfair.  Viewed in this context the Commission would do well to reconsider not just the application of the statute of limitations when bringing an enforcement action but also the remedies being sought and the manner in which disgorgement is configured – a question left open by Kokesh.   

Firm Highlights

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.

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.