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ClientEarth v Shell plc Case Analysis: Directors’ Duties, Derivative Actions and ESG

September 21, 2023

by Joseph Lewin

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The High Court's recent decision in the case of ClientEarth v Shell plc [2023] EWHC 1897 (Ch) has significant implications for activist investors seeking to challenge the response of companies to climate-related risks, and for boards responding to challenges.  It will provide reassurance to company directors.

ClientEarth, a climate change shareholder activist group, brought legal action aiming to challenge Anglo-Dutch oil and gas major Shell's response to climate change risks.  The claim has been widely reported as a “world-first” that seeks to hold corporate directors personally liable through the court for allegedly failing to move away from fossil fuels fast enough.

ClientEarth was seeking a declaration in respect of Shell’s directors’ acts and omissions, together with a mandatory injunction that Shell (i) adopts and implements a strategy to manage climate risk in compliance with its directors’ statutory duties, and (ii) immediately complies with an order of the Dutch court in separate litigation concerning Shell in the Netherlands.

In this judgment, the Court confirmed its earlier decision to reject the application by ClientEarth for permission to bring a derivative action against Shell’s directors.

Derivative claims procedure

ClientEarth initiated legal proceedings as a “derivative claim”.

A derivative claim is a claim brought by a shareholder or shareholders on behalf of the company against a third party (often the directors of the company) under s.260(1) Companies Acts 2006 (CA 2006). 

The statutory procedure for bringing derivative actions effectively consists of two stages:

  1. Prima facie case.

    A shareholder seeking to bring a derivative claim must make an application for permission to continue with the claim, and must show a prima facie case.

    This application is made “on the papers”, i.e., by written application, without the need for a hearing.

    Under s.263(2) CA 2006 the court must refuse permission if it considers that a person acting in accordance with the duty to promote the success of the company would not continue the claim, or if the act or omission from which the cause of action arises was authorised or subsequently ratified by the company.

    If the court dismisses the application on paper, then, under CPR 19.15 the applicant / claimant has 7 days to request an oral hearing, at which point the claimant will invite the court to reconsider its application for permission.

     

  2. Substantive application for permission.

Assuming that a prima facie case is established, the court will then order the defendant parties to respond to the permission application, and it will give directions for a substantive hearing of that application (CPR 19.15(12)).  At this hearing the court retains a wide discretion to allow the claim to continue.

Exercising such discretion, the court takes into account all “relevant matters”, including a number of factors listed in s.263(3) CA 2006, such as: (i) whether the claimant is acting in good faith; (ii) the views of other shareholders that have no direct or indirect personal interest in the claim; and (iii) the importance that a person acting in accordance with his duty to promote success of the company would place on continuing the claim.

In the ClientEarth v Shell plc case, the Court’s earlier decision was made on papers. ClientEarth then exercised its right under CPR 19.15 to ask the court to reconsider its decision at an oral hearing.

The recent judgment given follows the oral hearing and consolidates the original judgment.

Directors’ duties relied on by ClientEarth

ClientEarth sought to rely on two of the statutory duties owed by Shell's directors.  These duties are common to all English companies, and are set out in CA 2006:

  1. Duty to promote the success of the company (s.172 CA 2006). This duty requires a director to act in in good faith when promoting the success of a company, for the benefit of the shareholders as a whole, having regard, amongst other matters, to a wide list of considerations.This includes the likely consequences of any decision in the long term and the impact of the company's business operations on the community and the environment.

     

  2. Duty to exercise reasonable skill, care and diligence (s.174 CA 2006). This duty requires a director to exercise the care, skill and diligence that would be exercised by a reasonably diligent person with the general knowledge, skill and experience that might reasonably be expected of a person carrying out the functions that person carries out, and the general skill and experience that director actually has.

ClientEarth also alleged that the directors owed six additional incidental duties specifically related to their duty to manage climate risk:

  1. a duty to make judgements regarding climate risk that are based upon a reasonable consensus of scientific opinion;
  2. a duty to accord appropriate weight to climate risk;
  3. a duty to implement reasonable measures to mitigate the risks to the long-term financial profitability and resilience of Shell in the transition to a global energy system and economy aligned with the global temperature objective of 1.5°c under the Paris Agreement on Climate Change 2015;
  4. a duty to adopt strategies which are reasonably likely to meet Shell's targets to mitigate climate risk;
  5. a duty to ensure that the strategies adopted to manage climate risk are reasonably in the control of both existing and future directors; and
  6. a duty to ensure that Shell takes reasonable steps to comply with applicable legal obligations.

ClientEarth also pleaded that there is a duty on a director who is aware of a court order to take reasonable steps to ensure that the order is obeyed.  ClientEarth referred specifically to the order granted by the Dutch court against Shell, requiring Shell to reduce its group-wide CO2 emissions.

The pleaded breaches of duties included failures to set an appropriate emissions target and to adopt a strategy that would establish a reasonable basis for achieving net-zero targets, and a failure to comply with the Dutch court order.

ClientEarth sought a declaration that the directors had breached their duties and a mandatory injunction requiring the directors (i) to adopt and implement a strategy to manage climate risk in compliance with their statutory duties, and (ii) to comply immediately with the Dutch court order, with which it said that Shell had failed to comply.

ClientEarth decision

At the oral hearing, Mr. Justice Trower dismissed ClientEarth's application on the basis that the group had failed to establish a prima facie case for permission, as required by s.261(2) CA 2006.

The key takeaways from the judgment are summarised below:

  1. Evidential burden on the claimant. The court emphasised that the purpose of the prima facie stage was to provide a filter for “unmeritorious” or “clearly undeserving” cases, which imposes an evidential burden on the claimant at the outset. The court must exercise a critical approach and take the evidence at its “reasonable highest”, which means that the evidence must be sufficiently substantial, without more, to justify the grant of relief. This confirmed that the approach to what amounts a prima facie case under CA 2006 is similar to the common law position, which is “a higher test than a seriously arguable case” as set up in Abouraya v Sigmund [2014] EWHC 277 (Ch).

     

  2. Criteria to consider at prima facie stage. The court disagreed with ClientEarth’s apparent suggestion that the discretionary factors listed in s.263(3) CA 2006 shouldn’t be taken into account when deciding whether the evidence established a prima facie case. The same applied to the nature of the relief sought, which was as much a factor in the decision whether to grant permission as the nature of the breaches relied on. The court said that it could not see a legitimate benefit of the declaratory relief, emphasising that it’s not the court’s function to express views on directors’ conduct which have no substantive legal effect.

     

  3. Relevance of a shareholder’s motivation, good faith and the views of other shareholders. One of the discretionary factors the court considered was whether the shareholder is acting in good faith in seeking to continue the claims. The court’s conclusion was that the claimant needs to prove they are acting in good faith. Even if shareholders have an honest belief that the claim is in the best interests of the company, the good faith test may not be met if the primary purpose of bringing the claim is to pursue the shareholders' own political agenda. Court noted that ClientEarth's claim had been brought primarily to publicise its own agenda. It also gave weight to the fact that the relevant climate policy had been approved by over 80% of the other shareholders in Shell, and this "strongly" militated against the grant of permission. In the court’s clear view, the proper forum for ClientEarth to voice its concerns was by vote of the members in general meeting.

     

  4. The court is reluctant to interfere in company management decisions. It is for company directors, not the court, to determine how to promote the success of the company, but they must still have regard to the non-exhaustive list of factors under s.172 CA 2006, which include environmental and community considerations. It would also be incompatible with the subjective nature of a director’s duty to act with reasonable skill and care (s.174 CA 2006) if the court was to dictate how the management of a business should be conducted.

     

  5. The court rejected attempts to formulate new and absolute duties in respect of climate change. The court held that Shell's directors were not subject to these incidental duties for three key reasons: (i) they were inherently vague and incapable of constituting enforceable personal legal duties; (ii) they 'cut across' the basic principle of company law that it is for the directors to determine company strategy and to identify which, out of competing considerations, take precedence in meeting their obligation to promote the success of the company; and (iii) they were incompatible with the subjective nature of a director's duty to take reasonable care and skill in managing the business. The court noted that, at the oral hearing, there was a “subtle but important shift” in the way ClientEarth pleaded its case. It originally alleged that directors of companies “such as Shell” would be subject to these duties, but in oral argument its position was that the incidental duties arose logically once the directors had identified that Shell’s climate strategy was a commercial objective which was most likely to promote the success of Shell. The court rejected that argument and commented that if it should not interfere with the commercial question of the strategy to be adopted, the same principle of restraint should be applied to the means by which that strategy was to be implemented.

     

  6. The distinction between subjective and objective tests for breaches of directors' duties was also clarified. Breach of section 172 is subjective and requires proof of acting in bad faith. Breach of section 174 involves whether decisions fall outside the range reasonably available to directors at the time. The court emphasised that ClientEarth must show a prima facie case that directors couldn't reasonably conclude their actions were in Shell's interest.

     

  7. Unless and until there is a 'universally accepted methodology' by which climate change action can be measured, it will be difficult to prove that directors have not acted reasonably in addressing climate considerations.

     

  8. Under English law, there is no specific duty on directors to comply with an order of a foreign court, or to take steps to ensure the foreign court's order is obeyed.

     

  9. The court will not grant mandatory injunctive relief (such as to implement climate risk strategies) which is too imprecise to be suitable for enforcement and would require constant supervision by the court. It is not the function of the court to adjudicate on whether the business is being run in accordance with the terms of the injunction.

     

  10. Relevance of expert evidence. ClientEarth relied on evidence from one of its senior lawyers as to the alleged inadequacies in the directors’ management of climate change risk. The court held that it could place very little weight on the lawyer’s opinions, despite accepting that they were genuinely held. It rejected ClientEarth’s submission that it was unreasonable to require or expect expert evidence at the prima facie stage. The conclusion was that the lawyer’s evidence, unsupported by any expert analysis of why the directors got the section 174 balancing exercise so wrong as to be actionable, did not advance a prima facie case.

Impact on the ESG litigation

The ClientEarth claim has been dismissed after failing both in written submissions and during the oral hearing.

Notwithstanding the outcome of the potential appeal indicated by ClientEarth, the litigation has garnered substantial attention, consequently spotlighting Shell's policies that might have otherwise have not become public.  Furthermore, Shell's shareholder meetings have undergone heightened scrutiny and review, potentially encouraging all boards to follow suit. To an extent, ClientEarth therefore achieved its objectives, emphasising the importance for company directors to prioritise climate change responsibilities.

Beyond the procedural challenges within the derivative claim process, the case emphasised the substantive challenges which are relevant to all ongoing and future climate change litigation, affecting both claimants and defendants: it is the lack of a universally agreed methodology to gauge and assess climate change actions.

Directors should also be cautious, ensuring that terms used in strategic documents and policies are substantive and as precise as possible, to avoid any disputes arising from differences in director / shareholder expectations. Given the escalating public consciousness surrounding environmental and de-carbonisation concerns, climate-related claims, even if ultimately unsuccessful, have the potential to inflict reputational harm on a company, impacting its stock value and ability to attract investments.

As for activists, this was a clear indication that the court will not accept wide-ranging assertions of climate change duty.  Claimants will need to fully consider the remedies that they are seeking, and whether they are likely to constitute interference with a company’s business, or are even unenforceable.  The courts are unlikely to uphold broad injunctions mandating directors' compliance with general climate considerations, deeming them too vague to enforce and excessively burdensome on the court to oversee. However, the court’s judgment does not rule out the possibility of such a claim succeeding in future, provided that it is more tightly drafted, and is tied to specific actions and projects.

While the pursuit of activist shareholders aiming to promote ESG agenda in corporate management is unlikely to cease, this recent decision offers a degree of reassurance to directors. It shows that, despite societal and political pressures in environmental and sustainability spheres, judicial intervention in corporate decisions will remain marked by caution. As emphasised by Mr Justice Trower in this case, the court will aim to refrain from prescribing how directors fulfil their duties. Additionally, it serves as a caution to shareholders, particularly those with minority stakes such as ClientEarth (which had only 27 shares in Shell), against initiating derivative claims with ulterior motives.

In another recent case McGaughey & Anor v Universities Superannuation Scheme Ltd & Ors [2023] EWCA Civ 873, the Court of Appeal rejected an appeal by academics seeking permission to bring a derivative claim against the directors of a university pension scheme for its alleged failure to divest from fossil fuels, criticising the use of the derivative claim process in attempt to challenge the management and investment decisions without any supportive evidence by reference to the ClientEarth v Shell decision. The Court of Appeal also held that 'the derivative procedural mechanism is not intended to enable the would be claimants to avoid other procedural hurdles’.

Firm Highlights

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.