.

Layne Smith structures and negotiates mergers, acquisitions, joint ventures and other transactions for strategic buyers, private company sellers, private equity sponsors, and healthcare operators—turning complex deals into closed transactions.

Whether representing a hospital system in executing a roll-up of surgery centers and medical practices, a founder-owned business in an exit transaction involving a private equity buyer, or a family office forming a joint venture, Layne structures transactions from letter of intent through closing with a focus on protecting his clients' economic interests and managing deal risk.

Layne's deepest industry concentration is healthcare mergers and acquisitions. He regularly advises hospitals, surgical centers, physician practices, and healthcare investors on the full range of M&A activity—acquisitions, divestitures, minority investments, and joint ventures. He also serves as outside general counsel for healthcare operators, negotiating service agreements, lease agreements, and supporting regulatory compliance on an ongoing basis.

Beyond healthcare, Layne advises clients across a range of M&A and corporate transactions in technology, software, real estate, manufacturing, and financial services. His M&A work spans both buy-side and sell-side mandates, and he regularly negotiates purchase agreements, operating agreements, services agreements, and development agreements on behalf of buyers, sellers, and investors alike.

Layne is ranked by Chambers USA and, according to his clients, he is “exceptional” and “a fantastic external resource with a keen legal mind and ability to deliver consistent results.” He is a committed user of AI tools in his practice and integrates them to deliver more efficient and precise work product for clients.

Select Experience

  • Represented a hospital system in the sale of a $125 million minority interest to a strategic investor.
  • Represented a hospital in the acquisition of dozens of health care facilities, including ambulatory surgical centers, urgent care facilities, and physician practices.
  • Represented a healthcare business in a $380 million preferred equity repurchase and restructuring.
  • Represented Agent Boost Marketing in its sale to AmeriLife.

Education

  • Brigham Young University (J.D., 2005)
    • magna cum laude
  • Brigham Young University (B.A., 2001)
    • cum laude

Bar Admissions

  • Utah

Court Admissions

  • U.S. Court of Appeal for the Tenth Circuit
  • U.S. District Court for the District of Utah

Professional Affiliations

  • Board of Directors, Camp Kostopulos Dream Foundation, 2014-2020     
  • Alumni Board, BYU Law School,  2008-2015
  • Board of Directors, The Living Planet Aquarium, 2007-2010

Accolades

  • Chambers USA, Corporate/M&A, Utah, 2023-2026
  • Best Lawyers in America®, 2021-2026
  • Legal 500, Mergers & Acquisitions, 2015, 2019
  • Utah Business Magazine Legal Elite, Corporate Law and Transactions; Mergers and Acquisitions, 2013, 2015-2020
  • American College of Trust & Estate Counsel, First Place, Mary Moers Wenig Student Writing Competition, 2005
  • J. Reuben Clark Law School, Faculty Award for Meritorious Achievement and Distinguished Service, 2005
  • J. Reuben Clark Law School, J. Reuben Clark Award, 2004

Select Presentations

  • The Case of Disney’s Abandoned Fusion Joint Venture – Planning for an Exit, Association of Corporate Counsel Seminar, August 31, 2016

Insights

Media Mentions

Utah 2023 Legal Elite

June 1, 2023

Articles

Chemical Industry Update - January 2020

January 17, 2020

Antitrust Liability Allocation and the Problem of “Oversharing” As with other mature industries, many sectors of the chemical industry have become relatively concentrated over the years. Under these circumstances, current U.S. antitrust laws often create perverse incentives that lead to significant exposure for industry defendants, even where violations are de minimis or non-existent. With antitrust reform being much in the air of late, some modest changes to how liability is apportioned among defendants would seem in order to both improve the level of fairness overall and encourage new entrants by removing barriers to entry. In any federal civil antitrust case, private antitrust damages awarded by a jury are automatically trebled. And, in a case with more than one defendant, liability is “joint and several”—meaning that a successful plaintiff can recover three times the amount of harm it suffered as a result of anticompetitive activity, and it may recover that amount from any non-settling defendant it chooses, regardless of that defendant’s market share or relative degree of responsibility for the alleged conspiracy. This means that each defendant faces potential liability of three times the industry-wide damages that the antitrust violation allegedly caused. This is of particular note in industries, including the chemicals industry, that are relatively concentrated and are therefore likely to see greater antitrust scrutiny. Two features of the antitrust liability allocation rules mean that a defendant cannot shift any of its liability to other defendants that may be more culpable. First, a defendant has no right to make its co-defendants pay their fair share—that is, no right of “contribution.” That distinguishes antitrust from other types of cases, where a defendant that loses a trial can typically at least avoid paying a disproportionate share by claiming contribution from those defendants that it can show are more culpable. Second, when a case is tried to judgment, a settlement reached earlier in the case with one defendant is deducted from the trebled damages, not from the actual damages—and without regard to the relative share of damages for which the settling defendant ought to be responsible. In other words, there is no right of claim reduction proportionate to settling defendants’ share of liability. Together, these two allocation rules contribute to a race for even innocent or mostly innocent defendants to settle early, leaving the remaining defendants on the hook for an unfairly large share of damages. As a result, a company named as a defendant in any kind of antitrust conspiracy case has no good choices: it can either pay a substantial amount of money to settle the claims, or it can take on the risk that it may ultimately be held responsible for paying three times the actual damages caused by the conspiracy, reduced only by the actual amount of any settlements by other defendants. If the company has actually participated in the conspiracy, then those choices may be fair enough (and in those circumstances, companies may try to negotiate “judgment sharing” agreements with their co-defendants). But even if the company concludes, after a thorough self-investigation, that it has done nothing wrong, the choices remain the same. That is true even if the company has a relatively small market share or participated in the alleged conspiracy for only a short period of time (or believes it did not do so at all). There may be some appetite for reform. After all, the bipartisan Antitrust Modernization Commission recommended in 2007 that the federal antitrust laws be amended both to allow for a right of contribution among non-settling defendants and also to permit non-settling defendants to obtain reduction of a plaintiff’s claims by the amount of any settlements or the allocated share(s) of liability of settling defendants, whichever is greater. And antitrust has already received more attention in the current campaign for the Democratic nomination for the presidency than in any national election in decades. Perhaps addressing these damages-allocation rules could form part of a bipartisan reform package. But for the time being, even a company that is completely innocent or that at worst played a minor role in an anticompetitive agreement may reasonably feel compelled to rush into settlement for fear of being left exposed to pay industry-wide damages that are disproportionate to the company’s responsibility. For more information, contact Michael Lindsay and Anthony Badaracco. NOTES FROM ALL OVER General Counsel Faces Prospect of Duty of Care Violations for SEC Disclosure Violations. A recent Delaware motion to dismiss ruling leaves a company’s general counsel facing the prospect of liability for duty of care violations due to the company’s material omissions in an SEC filing. Summary and commentary here. PFAS Legislation. Last week, the U.S. House of Representatives passed HR 535 that would impose significant restrictions on the use of PFAS chemicals and heavy clean-up fines for manufacturers. Senator John Barrasso of Wyoming has stated the bill has no chance in the Senate. Joint Venture Governance. The JV structure is a popular and important deal structure for the chemical industry. This article runs interesting comparisons of JV governance against public company governance. Exxon Climate Change Case Ends in a Whimper. Bringing an end to the supposedly groundbreaking case by the New York Attorney General’s office over whether Exxon misled its investors with respect to the potential impact of climate change on its business, in December, the trial court judge ruled against the AG’s office on all counts. Earlier this week, the AG’s office announced it would not appeal. CORPORATE LAW Delaware Continues to Refine MAE Standards In our November 2018 edition, we commented on the special relevance of the laws surrounding material adverse change (MAC) provisions for the chemical industry. With the cyclical nature of some sectors in the industry, questions over MACs can become more complex than in other spaces, as evidenced by the Delaware decision in Hexion Specialty Chems. Inc. v. Huntsman Corp, 965 A.2d 715 (Del. Ch. 2008). In 2018, we then reviewed the landmark decision Akorn, Inc. v. Fresenius Kabi AG, which marked the first time that the Chancery Court upheld a buyer’s use of a MAC clause to terminate a merger agreement. However, the Court’s reasoning in that case suggested that the favorable ruling was based on the particularity of the facts and that the general standard for successfully invoking such a clause remains high. The Court’s recent decision in Channel Medsystems v. Boston Sci. Corp confirms the continuation of that high standard and reaffirms the Delaware Court’s stance that a MAC clause cannot be invoked to alleviate the effects of “buyer’s remorse” or undesirable business decisions. We cover the Channel decision in more detail in this e-update, but in brief, Channel v. Boston Scientific reaffirms that despite the Chancery Court’s decision in Akorn in 2018, the bar for invoking a MAE clause to terminate a merger agreement is still high. Material inaccuracies in the representations and warranties are not enough to trigger a Material Adverse Effect. Rather, the buyer must show that at the time of termination that there is a future expectation of a long-term adverse effect on the earning power of the target business. For more information, contact Layne Smith and Akosua Owusu-Akyaw. Blackrock and ESG Risks In its November 2019 10-K, Scotts Miracle-Gro broke new ground (at least in the chem industry) with a risk factor warning of risks associated with its corporate citizenship and sustainability efforts. The risk factor notes that “There is an increasing focus from certain investors, customers, consumers, employees, and other stakeholders concerning corporate citizenship and sustainability matters” and “we could fail, or be perceived to fail, in our achievement of such initiatives or goals.” It’s easy to see how these risks can have a material impact on companies.  Last year, despite being an early and vocal proponent of corporate responsibility, Blackrock Inc. saw itself receiving criticism from a number of directions for not doing enough, particularly with respect climate change. Perhaps in response, earlier this month, in its annual letter to clients, Blackrock’s CEO announced significant capital reallocation that would lower exposure to fossil fuel companies and move out of thermal coal stocks altogether. That’s all well and good, but it is a stark reminder that companies can face serious headwinds in the capital markets by not fitting into investors’ sustainability goals. For more information, contact Troy Keller.

Firm Highlights

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?

News

Dorsey & Whitney Partner Michael W. Droke Releases Fourth Edition of Cooperative Business Law: A Practical Guide with Enhanced Insights for Today's Cooperatives

Industry-leading reference updated with practical tips and current cooperative law developments Dorsey & Whitney LLP is pleased to announce the publication of the fourth edition of Cooperative Business Law: A Practical Guide to the Special Laws Governing Cooperatives, authored by Dorsey Partner Michael W. Droke. Drawing on more than 20 years of direct experience as outside general counsel to major agricultural and food industry cooperatives, Droke has updated this essential resource with new practical tips, real-world guidance, and insights into emerging cooperative law issues that matter to cooperative leaders and their advisors. Since its initial publication, this comprehensive guide has become the standard reference for attorneys, executives, and cooperative governance professionals navigating the unique legal landscape of cooperative organizations. The new fourth edition builds on that foundation by incorporating practical lessons learned from recent cooperative transactions, governance challenges, and regulatory developments. "I am grateful for Dorsey's continued support of this work and for the opportunity to contribute to the cooperative community," said Droke. "Over the past 20 years, I've had the privilege of serving as outside general counsel to some of the nation's most successful cooperatives. The practical insights gained from that work inform every page of this edition. I wanted to create a resource that helps cooperative leaders and their legal advisors tackle real business challenges with confidence." The Fourth Edition features: Practical tips and real-world case examples drawn from decades of cooperative practice Guidance on cooperative formation, governance, member rights, and voting structures Current analysis of antitrust and Capper-Volstead Act issues affecting modern cooperatives Insights into financing, mergers and acquisitions, and corporate restructuring for cooperatives Member relations strategies and dispute resolution approaches specific to cooperative structures About Michael W. Droke Michael W. Droke is a Partner at Dorsey & Whitney LLP and Firmwide Co-Chair of the Food, Beverage & Agriculture practice group. He serves as outside primary counsel for numerous cooperatives, providing comprehensive legal guidance on all aspects of cooperative operations, governance, member relations, corporate restructuring, financing, and mergers and acquisitions. His representative clients include National Co+op Grocers, Darigold, the Northwest Dairy Association, Organic Family Farms Cooperative, Chelan Fruit Cooperative, and Sacramento Natural Foods Co-op. A former business executive who brings a dual perspective to his practice, Droke combines legal expertise with practical business acumen. He has served as an outside board member and general counsel for major cooperatives and maintains deep involvement in the cooperative community through regular presentations and participation in industry organizations including NCBA CLUSA, the National Society of Accountants for Cooperatives, and the National Council of Farmer Cooperatives. About Dorsey & Whitney's Cooperative Law Practice Dorsey & Whitney's Cooperative Law practice group is a recognized national leader in cooperative law with more than 45 years of experience serving agricultural cooperatives, rural electric cooperatives, purchasing cooperatives, consumer cooperatives, worker cooperatives, and cooperative start-ups across the nation. The practice includes 20 dedicated lawyers who advise cooperatives and other agriculture-related organizations on formation and organization, voting rights and governance, antitrust and Capper-Volstead Act compliance, tax issues, project development and finance, mergers and acquisitions, real estate, labor and employment, environmental compliance, and all other aspects of cooperative business operations. Cooperative Business Law: A Practical Guide to the Special Laws Governing Cooperatives, Fourth Edition, is available from major book retailers and online booksellers.

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.

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.