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The Era of Private Ordering for Corporate Governance

August 28, 2017

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    Following the 2016 election, corporate governance circles have focused intently on what will happen in the nation’s capital with regard to a potential roll back of the current regulatory regime. The Trump Administration immediately signaled a strong desire for wide-ranging regulatory reform through a series of executive orders directed at federal agencies. Subsequent Congressional and agency actions initiated the potential unwinding of a broad swath of existing regulations. In the governance and disclosure world, the Republican-controlled Congress adopted a joint resolution suspending the resource extraction disclosure rules. In June, the House passed the Financial CHOICE Act which would repeal many of the governance-related provisions of the Dodd-Frank Wall Street Reform and Consumer Protection Act (disclosures of CEO pay ratio and hedging policies) and limit the scope of other provisions (clawbacks), prohibit the SEC from mandating the use of universal proxy cards and increase shareholder proposal thresholds. Recently, the Securities and Exchange Commission revised its rule-making docket under newly appointed Chairman Clayton’s leadership and pushed all of the unfinished Dodd-Frank related rules (pay-for-performance disclosure, clawbacks and disclosure of hedging policies) and some additional governance rule-making (universal proxy cards and board diversity) to the back burner.

    While attention given to Congress and the SEC for the potential direction of corporate governance is not misplaced, future change in this arena will most likely come from investors, and they have their own agenda which is very different from that of the current administration. A recent survey of 75 North American and European institutional investors by Rivel Research indicates, not surprisingly, that most institutional investors oppose major changes in the U.S. governance regulatory framework. Fearing that a watered down Dodd-Frank Act will result in negative governance outcomes at public companies, a large plurality of the surveyed investors (43%) oppose efforts to pare back the Dodd-Frank Act, while only a small minority (18%) support it. Even if Dodd-Frank is pared back, the vast majority of these investors believe that companies should continue to abide by the original rules. In fact, many investors responded that they will be seeking expanded disclosure in a number of areas. In the event that key governance and disclosure mandates are repealed, nearly half of the investors said they would ramp up their efforts to engage companies on governance matters, and 41% said that they would be more inclined to support an activist.

    The power of institutional investors to effect changes in the corporate governance framework in the absence of regulation has been demonstrated by the recent and dramatic rise of privately-ordered proxy access. Following authorization under the Dodd-Frank Act to establish rules governing access to proxy statements, the SEC adopted Rule 14a-11 in 2010. Litigation ensued, and Rule 14a-11 was ultimately vacated by the U.S. Court of Appeals for the District of Columbia Circuit which held that the SEC had not realistically weighed the rule’s effect upon efficiency, competition and capital formation. When the SEC failed to pick up the ball on proxy access for several years after the ruling, institutional investors stepped into the breach led by the Office of the New York City Comptroller and other large pension fund managers. Primarily as a result of shareholder proposals and the shareholder engagement process, the number of companies that have adopted proxy access bylaws in the absence of any regulatory requirement increased from nine in 2013 to over 425 companies today, including more than 60% of the S&P 500, a trend that few public companies and their advisors had foreseen or even imagined. And pressure from investors continues even for companies that have adopted proxy access bylaws, as seen in the this year’s round of proxy access “fix it” shareholder proposals and the July 2017 position paper on best practices for proxy access posted by the Council for Institutional Investors.

    In addition, at a time when the technical disclosure requirements for proxy statements under SEC Schedule 14A and Regulation S-K have remained static, voluntary disclosures in proxy statements have mushroomed. Much of this has been driven by the need for public companies to present their case on executive compensation to shareholders for the “say-on-pay” vote which, notably, occurred during a period when Dodd-Frank-mandated SEC rule-making for pay-for-performance disclosure languished. Responding to investor demands for disclosure that is easy to understand, as well as a realization that proxy advisory firms provide competing versions of this information in their voting reports, companies have introduced proxy summaries, pay-for-performance graphics, alternative tables for realized and realizable pay and other voluntary disclosures in an effort to communicate their executive compensation programs in clear and compelling ways.

    Recently, we have seen the advent of voluntary disclosures outside of executive compensation in other emerging areas of investor concerns, such as environmental, social and governance (ESG) matters. Investors are increasingly seeing ESG issues as linked to the long-term financial strength of a company, not merely a matter of moral conscience or political preference. The Chairman and CEO of BlackRock, Inc., the world’s largest asset manager and a major shareholder in many companies, wrote “[o]ver the long-term, environmental, social and governance issues – ranging from climate change to diversity to board effectiveness – have real and quantifiable financial impacts.” The Principles for Responsible Investment have garnered over 1500 signatories with $62 trillion in assets under management who have agreed to incorporate ESG issues into investment decision-making and seek related disclosures from companies in which they invest. A variety of organizations are now evaluating and rating public companies on their ESG performance, and investors are increasingly asking companies in a broad range of industries “What are you doing about sustainability?”

Environment and Sustainability

    In response to these investor demands, prominent voluntary disclosures about environmental impacts and sustainability are finding their way into proxy statements and other SEC filings, even for companies outside of the energy and manufacturing sectors. See, for example, the 2017 proxy statement for Prudential Financial, Inc. In addition, shareholders put forward more proposals on environmental and social matters than on any other topic in 2017, and such proposals received greater support than in prior years, including majority support for climate change related proposals at three energy companies.

    Looking ahead, the quantification of sustainability disclosures is expected to grow as the Sustainability Accounting Standards Board (SASB) moves forward with its mission to identify and maintain a set of material sustainability metrics tied to financial performance that public companies will need to consider disclosing in their SEC filings in order to meet investor demands. SASB’s board of directors and investor advisory group include representatives from many large asset managers and shareowners. In addition, on June 29, 2017, the Financial Stability Board’s Task Force on Climate-Related Financial Disclosure (TCFD), formed at the request of the G20, released its Final Recommendations Report for voluntary climate-related financial disclosure. The core elements of the final recommendations include disclosure of the governance, business impacts, processes, metrics and targets of a company’s climate-related risks and opportunities. The report was accompanied by a statement of support signed by approximately 100 entities, including major financial institutions, asset managers, pension funds, rating agencies, stock exchanges and companies in the chemical, steel, airline, mining, energy, consumer goods and other industries.

Board Diversity

    Unlike some European nations, the United States does not mandate board diversity. While Democrats in Congress have requested that the SEC take up rule-making on board diversity, it is not a priority on the SEC’s recently updated rule-making agenda. Currently, the SEC’s proxy rules require only a statement as to whether and how diversity is considered in identifying director nominees and, if the company has a director diversity policy, how that policy is implemented and assessed. Until recently, this requirement typically yielded boilerplate disclosure to the effect that the company considers a variety of factors when reviewing director nominees, including age, gender, ethnicity, experience and skills. Investors are pressing for additional disclosure, however, believing that board diversity is tied to long-term shareholder value creation, and proxy statements in recent years have included increased voluntary disclosure regarding the importance of board refreshment and diversity, including charts and graphs breaking down the composition of their boards.

    More importantly, investors are now pushing for increased board diversity at the ballot box. For example, State Street Global Advisors reportedly voted against or withheld votes for the re-election of nominating committee chairs (or their equivalents) at 400 out of a total of 476 portfolio companies it identified as male-only boards this proxy season. BlackRock reportedly supported eight of nine shareholder proposals calling on companies to adopt board diversity policies or commit to disclose their plans to increase their board diversity, and also voted against the nominating committee members at five of the those companies for their alleged failure to address board diversity concerns. Shareholder proposals calling for greater board diversity received majority support at two companies in each of the past two years.

What’s Next?

    In July, the Human Capital Management Coalition (HCMC), a group of institutional investors with $2.8 trillion in assets under management, requested that the SEC take up rule-making to require public companies to disclose information about their human capital management policies, practices and performance. HCMC believes that skillful management of human capital is associated with better corporate performance, risk mitigation and long-term value creation and is therefore material to investors when evaluating a company’s prospects. The requested categories of disclosure are comprehensive, including workforce demographics, stability, composition, skills, culture, empowerment, health, safety, productivity, human rights, compensation and incentives. SASB has also identified human capital issues as material for some industries. The SEC’s current rule with regard to required disclosure of workforce information is limited to the number of employees, and it is highly unlikely that the SEC will initiate human capital disclosure rule-making under the current administration. However, HCMC and other investors have already been requesting that companies provide workforce data and voluntary disclosure, and they are expected to broaden such requests in the future. Some companies, such as Unilever and Diesel & Motor Engineering plc are already making voluntary disclosures related to human capital. In addition, shareholder proposals relating to human capital issues such as workforce diversity and pay disparity increased substantially in 2017 over the prior year.

    In conclusion, while the current regulatory requirements relating to corporate governance matters may be rolled back by Congress and the SEC in certain areas, public companies will need, first and foremost, to understand and be responsive to the priorities of their largest shareholders. In most cases, investor priorities will require actions and disclosures beyond what is mandated by the regulatory framework. Public companies should also anticipate increased quantification and metrification of environmental, social and governance indicators and related disclosures that facilitate spreadsheet comparison by market analysts. Regardless of, or perhaps in response to, any relief provided by Congress or the SEC, investors and groups of investors are likely to continue to push for greater shareholder engagement and enhanced disclosure and will use the their voting power to effect change, especially in ESG and other non-traditional performance areas where they see a strong tie to long-term value creation.

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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?

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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.

Regulatory Affairs Partner Randy Dann Joins Dorsey

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Regulatory Affairs Partner Randy Dann Joins Dorsey

Dorsey Recognized in Chambers UK 2027

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Dorsey’s London Corporate Practice and Partners Earn Chambers UK 2027 Rankings

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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.

Regulatory Affairs Partner Jeff Beelaert Joins Dorsey in Boise

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Regulatory Affairs Partner Jeff Beelaert Joins Dorsey in Boise

Attorney John Cooney Returns to Dorsey in the Finance & Restructuring Group in Minneapolis

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Attorney John Cooney Returns to Dorsey in the Finance & Restructuring Group in Minneapolis

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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.

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The Supreme Court Update - October 14, 2026

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Dorsey Recognized in Inaugural 2026 IAM/WTR Copyright 1000

Dorsey & Whitney LLP is pleased to announce its recognition in the inaugural edition of the Copyright 1000: The World’s Leading Copyright Professionals, published by IAM and World Trademark Review (WTR). Nine Dorsey attorneys were individually recognized, and the Firm’s Denver, Minneapolis, New York, Salt Lake City, and Seattle offices were recognized in the firm rankings. The following Dorsey attorneys were recognized in the inaugural guide: Lindsey Sadler Gregory Tamkin Charlene Krogh Evan Everist Jeffrey Cadwell Fara Sunderji Bruce Ewing Catherine Parrish Lake J. Michael Keyes The Copyright 1000 is the first dedicated ranking focused solely on the world’s leading copyright practitioners. The guide identifies leading copyright firms and practitioners across key jurisdictions worldwide. Dorsey’s intellectual property attorneys advise clients on a wide range of copyright matters, including protection, enforcement, licensing, litigation, transactions, and issues involving emerging technologies and digital content. The inaugural Copyright 1000 rankings are published by IAM and WTR.