.

Articles

Chemical Industry Update - November 2019

November 11, 2019

by Troy M. Keller, Dave Townsend, and T. Augustine Lo

Download as a PDF

Share this page

Stand in the Place Where you Live

In the late 1980s, almost no antitrust enforcement cases were brought in jurisdictions outside the United States, even though active enforcement had been ongoing there for nearly 100 years. In the thirty years since, practically every developed nation has adopted an antitrust statutory regime and begun enforcing it. That timeframe may seem glacially slow, but in the regulatory world, this is in fact a relatively rapid global roll-out.

Given this reality, that law and policy developments take time, often years, REM’s classic advice—to stand where you live and control what you can—has some value as a legal strategy. Consider Brexit. While the UK’s exit from the European Union has threatened to upend value chains with the break-up of the European market, companies that did not panic in 2016 have now had several years to cycle through long-term agreements and mitigate foreign exchange risk, update governing law provisions, clarify force majeure clauses and broaden compliance requirements in anticipation of an additional UK layer of regulation and disrupted supply chains. The overall situation remains uncertain, and risks abound, but paying attention to the little things can pay off over time.

We believe this approach is effective with respect to most law and policy trends. Through watchful monitoring, businesses can make informed decisions about how best to position their unique product lines and be effective in their engagement with customers, suppliers, regulators and policymakers. In this issue we visit (and revisit) some legal trends that continue to be the most significant for the chemical industry. As always, don’t hesitate to reach out should you have follow-up questions.

Toxic Tort Litigation Trends

There may be more behind the proliferation of product liability cases involving substances like glyphosate, PFAS, and talcum powder than one-off, product-related concerns.  This Law360 article walks through some key trends influencing toxic tort litigation in the chemical industry. The article notes as a key factor that chemical manufacturers appear to be attractive targets in part because the universe of manufacturers is far smaller than that of all the potential sources of injury, such as the downstream players using the chemicals who are in fact more proximate to the place of injury. The article also cites a belief by some that delays in action by regulators like the Environmental Protection Agency (EPA) have led to a vacuum that courts and juries have tried to fill. The argument goes that instead of having clearly defined standards enforced by an active agency, there is now room for plaintiffs to bring claims and argue what the standards should be.

Another important trend results from more regulatory agencies (like California’s Office of Environmental Health Hazard Assessment under Proposition 65) taking public health positions on particular chemicals, which affords plaintiffs persuasive authority to prove liability. Notwithstanding the fact that these health assessments should arguably be excluded as not relevant to the question of specific causation, judges have been loath to exclude them. This has put manufacturers at a severe disadvantage and emboldened plaintiffs.

We are also seeing an impact from states eliminating or loosening traditional bars to these types of claims. This New York law, adopted last week, is a real-time example. By increasing the statute of limitations period, the pool of available plaintiffs is likely to expand. Unfortunately, with these and other trends seem to be creating an environment that promotes product liability claims against the industry.

For more information, contact Jon Williams.

Global Trade Update

Attention from the business community will focus this month on the expected announcement of “Phase One” of a U.S.-China agreement to begin reducing trade frictions between the countries, which have led to reciprocal tariffs, reduced Chinese purchases of American exports, and other forms of retaliation during the past two years. Expected to be signed in November or December 2019, neither side has disclosed the full details of the agreement. According to recent statements from U.S. officials, Phase One potentially involves an agreement to remove some of the “Section 301” tariffs on imports into the United States of Chinese origin goods in exchange for Chinese commitments to purchase U.S. agricultural goods. However, the White House has equivocated on the extent of the tariff relief, if any. Phase One is intended to set the stage for Phase Two, which the Trump administration hopes will result in broader Chinese commitments related to protection of U.S. intellectual property rights and elimination of subsidies for Chinese businesses. As of today, nearly all goods between the two countries are subject to Section 301 tariffs, with a final tranche scheduled for December 15 that will impact a wide range of household goods purchased in the United States as well as a number of chemical products.

Several other significant international trade developments occurred in October that could affect the chemical industry.

  • China gained World Trade Organization (WTO) approval to retaliate against $3.5 billion worth of U.S. goods because of the continued use of “zeroing” in U.S. antidumping proceedings, which leads to the calculation of higher antidumping duty rates on Chinese goods. Now that China has won this WTO approval, China may impose tariffs on U.S. goods, possibly tariffs far in excess of tariffs already imposed as a result of the U.S.-China trade dispute (see above). China’s authority to impose these tariffs, consistent with WTO rules, would remain even after the United States and China reach an agreement to resolve the ongoing U.S.-China trade dispute, unless the two countries specifically resolve this separate WTO dispute as part of the agreement.
  • A WTO panel found that India’s export subsidies, including those that benefit Indian producers of chemicals, are illegal under the WTO Agreement on Subsidies and Countervailing Measures. India can appeal the panel’s decision to the WTO Appellate Body. According to USTR, the value of subsidies provided to Indian businesses is $7 billion annually, and include those to Indian chemical producers. The specific Indian programs at issue are: the Merchandise Exports from India Scheme (MEIS); Export Oriented Units Scheme and related sector specific schemes (EOU); Special Economic Zones (SEZ); Export Promotion Capital Goods Scheme (EPCG); and a duty free imports for exporters program (DFIS). Detailed information about the dispute can be found at the WTO’s website, here.
  • The U.S. Trade Representative (USTR) revoked Thailand’s benefits under the Generalized System of Preferences (GSP) for $1.3 billion in annual imports into the United States from Thailand. A list of goods impacted is available here. USTR’s decision resulted from a petition from the American Federation of Labor and Congress of Industrial Organizations (AFL-CIO) alleging violations of workers and human rights in Thailand. Thailand is one of the largest GSP beneficiary, with $4.4 billion in annual trade from Thailand benefiting from GSP. USTR also announced new GSP reviews of South Africa and Azerbaijan, which could result in changes to their status under the GSP. Details from USTR can be found here.

For more information, contact Dave Townsend and Augustine Lo.

Retail Regulation Trends

Continuing the retail regulation trend, Staples recently announced a detailed chemicals policy. Among the chemicals listed as priority items and targeted for elimination in its products are PFAS, BPA, nonylphenol and nonylphenol ethoxylates, all organohalogen, halogenated and organophosphate flame retardants, a number of biocides, pthalates, solvents and other chemicals.

The Staples announcement is the latest among major retailers no longer deferring to or waiting for governmental regulators. Target and Walmart adopted chemicals policies in 2017, and Amazon and Walgreens adopted theirs in 2018. A long list of retailers have followed suit in the ensuing months. This trend is the new reality for the industry and adds to the complexities of managing a modern-day chemical company, with the constant need to reformulate and find solutions that work within a layered regime of governmental regulation, retail policies and NGO advocacy.

For more information, contact Troy Keller.

Tech Policy

While typically not the targets of these policies, chemical companies nonetheless bear the burden of dealing with new regulations in areas like data privacy, data ownership, content monitoring and competition law. These policies can have an outsized effect on the chemical industry due to its global nature, with products constantly moving back and forth across borders at various steps in the value chain.

This recent article in Politico EU argues that in the battle over tech leadership, the EU is considering more aggressive and potentially protectionist tech policies. A more idealistic but still interesting read was this article from the WSJ. The EU’s success with GDPR may accelerate trends into areas like antitrust and data localization, a particularly scary one. Like any global industry, the chemical industry manages personal data of employees and contractors around the world. Add on top of that a high volume of cross-border commercial transactions involving highly regulated materials, and the personal and commercial data flow is tremendous. Digitalization, frequently pointed to as a future source of cost savings and efficiency for the industry, could be upended or at least delayed by higher compliance costs and limited operational flexibility as a result of aggressive tech policies.

For more information, contact Troy Keller.

In Case You Missed It

Updated Proxy Rules. The SEC continues to shake up the U.S. proxy process. In their hearing this week, the Commission proposed rules requiring disclosures of conflicts of interest, revising the share ownership thresholds for making a proposal and the approval thresholds for making repeat proposals. Shareholder proposals will remain a popular tool of shareholder activism, but these changes could certainly reduce some of the leverage proponents and proxy advisors have been accumulating over the years.

CCPA Rulemaking. California is in the process of adopting additional rules to clarify aspects of the California Consumer Protection Act of 2018. These rules will help in some respects but fall far short of what is needed.

PRC Trademark Law Updates. China recently announced revisions to its trademark laws to clamp down on bad faith applications. The changes also increase the maximum amount for statutory damages for trademark infringement from RMB 3 million (~US$425K) to RMB 5 million (~USD710K), and the maximum punitive multiplier is increased from three to five (Article 63).

China Opens up Investment Opportunities. Via a collection of changes to previous rules restricting foreign access to certain end markets and trade zone opportunities, China has made moves to invite foreign investment in ways it has not before.

CFIUS Rules Released. Long-awaited rules implementing the Foreign Investment Risk Review Modernization Act of 2018 were released in October. The rules expand both the scope and nature of review of foreign investments into the U.S.

CORPORATE LAW 

M&A and the Evaluation of Corporate Compliance Programs

Acquisitions of chemical companies, especially target companies with international operations, require buyers to carefully scrutinize the target’s compliance programs, including the target’s compliance with the U.S. Foreign Corrupt Practices Act and other anti-bribery and anti-corruption laws. Doing so enables the buyer to more accurately assess the target’s value and risk profile, negotiate for the costs of any misconduct to be borne by the sellers and evaluate whether remedial steps are needed.

When designing and executing a pre-M&A due diligence process on compliance-related matters and evaluating how to mitigate potential post-closing liabilities, buyers should consider the U.S. Department of Justice’s updated guidance on the evaluation of corporate compliance programs, which was released in April 2019. The DOJ guidance document is aimed at prosecutors making decisions as to whether, and to what extent, a corporation’s compliance program is adequate and effective. Under the DOJ’s principles for the prosecution of business organizations, the adequacy and effectiveness of a corporation’s compliance program is one of the factors that prosecutors should consider when conducting a corporate investigation, making charging decisions and determining the appropriate form of any monetary penalties or other enforcement action.

The guidance clearly indicates that the DOJ expects a buyer to conduct comprehensive due diligence of any acquisition targets. It provides, “flawed or incomplete due diligence can allow misconduct to continue at the target company, causing resulting harm to a business’s profitability and reputation and risking civil and criminal liability.” Among the questions prosecutors will consider when evaluating whether a buyer subjected an acquired business to appropriate scrutiny are the following:

  • “Due Diligence Process – Was the misconduct or the risk of misconduct identified during due diligence? Who conducted the risk review for the acquired/merged entities and how was it done? What is the M&A due diligence process generally?
  • Integration in the M&A Process – How has the compliance function been integrated into the merger, acquisition, and integration process?
  • Process Connecting Due Diligence to Implementation – What has been the company’s process for tracking and remediating misconduct or misconduct risks identified during the due diligence process? What has been the company’s process for implementing compliance policies and procedures at new entities?”

The DOJ’s guidance provides a reminder of the importance of assembling the right team of subject matter experts and prioritizing the analysis of compliance risks when planning and conducting pre-M&A due diligence. Buyers should also consider whether, based on the target’s business and the regulatory environment in which it operates, enhanced due diligence is appropriate in certain jurisdictions or regarding particular compliance risks. Prospective sellers should anticipate greater scrutiny and earlier buyer inquiries in these areas, and ensure that remedial actions are taken to address any deficiencies.

For more information, contact Edward Davis.

Exxon’s Climate Change Trial

The trial in the case brought by the New York Attorney General’s office over whether Exxon misled investors with respect to the potential impact of climate change on its business has had some dramatic twists and turns. The state trial court judge, Justice Barry Ostrager, expressed skepticism with one of the State’s experts and at one point threatened to cut the AG’s case off if it didn’t manage the timing of its witnesses better. During closing arguments, the AG’s office said they were dropping their claims for common law fraud and equitable fraud, resulting in outrage from Exxon’s counsel that the AG’s office is at this late stage “not pressing the two claims that have cost in many respects the most severe reputational harm to the company.”

A decision is expected in about a month. However the trial turns out, the genie is to some extent out of the bottle. The Massachusetts Attorney General’s office filed a case in October similar to the New York case, though expanded to include consumer claims. Several cases have been brought by private litigants in other states based on securities law claims and one as a derivative suit. Whether these types of claims turn into a broader trend beyond Exxon, however, may depend on how the New York case turns out.

Disclosure trends in the chemical industry could also be affected. One ground-breaking aspect of this case has been the baseline question of whether climate change disclosures can create liability under securities laws. For years, companies have been creating sustainability reports discussing the impact of their operations on the environment, but this case asks whether a company could face liability for failing to accurately assess and disclose the effects of climate change and related environmental policies on the company’s financial prospects.

Such disclosure is a tall order. Many companies in the chemical industry already include high level risk factor disclosure regarding climate change, but getting more specific would require data that is not readily available and perhaps a new accounting framework in which to report it. Under Chairman Clayton, the SEC has declined to look seriously at adopting such specific requirements. The idea could gain momentum if plaintiffs start to make headway.

For more information, contact Troy Keller.

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

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

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

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.