.

Mike structures and negotiates tribal finance and commercial gaming transactions so that lenders, tribes, developers and operators can close complex deals with confidence.

Mike’s tribal finance practice is among the most active in the country. He represents lenders, tribes, and other transaction participants in connection with the construction and expansion of casino, lodging, and entertainment facilities, health care facilities and other economic and governmental projects and initiatives. His work in this space spans Indian Country and facility types, including bilateral, syndicated and tax-exempt financings, with individual credit facilities ranging in size from one to over a billion dollars. Chambers USA has recognized Michael in Native American Law: Finance at the national level.

Mike also has an active commercial gaming finance practice, which includes the representation of lenders, developers and operators in transactions involving commercial casinos, route operators, gaming equipment manufacturers and vendors, and gaming development and management companies throughout the United States

In addition, Mike serves as outside general counsel for a public power agency, regularly advises end-user clients with respect to interest rate, foreign exchange and commodity derivatives, represents lenders in commercial finance transactions in a wide range of industries, and also has experience in project finance transactions across multiple industries, including energy (gas, coal, wind, solar, hydroelectric, battery storage), ethanol and other biofuels and mining. 

Within Dorsey, Mike currently serves as the Minneapolis Office Co-Head and the Co-Chair of the Banking and Financial Institutions Industry Group.  He was previously the Co-Chair of the Energy and Natural Resources Industry Group.

Select Experience

  • Represented tribally-owned commercial gaming developer and operator in the development, financing and refinancing of its three commercial gaming projects located in Nebraska, in an aggregate amount of approximately $700 million in senior secured credit facilities. 
  • Represented administrative agent in connection with a $1 billion senior secured credit facility for a gaming equipment finance company with extensive routes in Indian Country.
  • Represented administrative agent in connection with a $300 million senior secured credit facilities for a tribal gaming enterprise and tribal economic development enterprise in Washington to provide expansion and acquisition growth capital.
  • Represented tribal corporation located in Arizona in connection with a $46 million taxable bond issuance for the construction of health care facilities.

Education

  • University of California, Santa Cruz (B.A., 1991)
  • University of California College of the Law, San Francisco (J.D., 1994)

Bar Admissions

  • Minnesota
  • California

Court Admissions

  • U.S. Court of Appeals for the Ninth Circuit
  • U.S. District Court for the Northern and Eastern Districts of California

Professional Affiliations

  • Board of Directors, Lawyers’ Committee for Civil Rights Under Law

Accolades

  • Chambers USA, Native American Law: Finance, National, 2025 – 2026
  • Best Lawyers in America®, 2021 – 2026
  • Minnesota Lawyer, Legal 250, 2026
  • Minnesota Monthly, Top Lawyer in Banking & Financial Service Law, 2024
  • MSBA, North Star Lawyer, 2012 – 2014, 2016, 2018, 2020 – 2022, 2024
  • Minnesota Lawyers of the Year, 2012

Select Speaking Engagements

  • Managing Risk Through Derivatives: Don’t Be Afraid, It’s Not That Complicated:  Dorsey & Whitney LLP Corporate Counsel Symposium 2024, November 7, 2024
  • LIBOR + SOFR = Confusion: What Tribes Need to Know About Treasury Management and Loan Interest Rate Agreements, NAFOA’s 37th Annual Conference, April 14-16, 2019
  • Construction Seminar: An Owner's Challenges, April 12, 2007 - April 12, 2007

Insights

Pro Bono

2020 Election Protection

November 3, 2020

Updated November 6, 2020 USNews & World Report: Early Voting: A 2020 Success Story Law 360: From The Front Lines: The Attorneys Protecting This Election WCCO: News at 5: Election 2020 Southwest Journal: Minnesota votes in big numbers for Biden Minnesota Lawyer: Lawyer volunteers: Minnesota elections ran well

Client Alert

Preparing for LIBOR Substitution-Commercial and Consumer Lending Considerations

September 19, 2019

1. Introduction As of December 31, 2021 (the “Effective Date”), the use of LIBOR as an index for commercial and consumer loans will likely cease—which presents lenders and other industry participants with the challenges to address: (a) the process for replacing LIBOR as an index for commercial and consumer loans outstanding as of the Effective Date that employ LIBOR as an index; and (b) how to proactively anticipate the end of LIBOR by beginning to substitute a new index for LIBOR between now and the Effective Date. This Alert will provide a short background on the developments that have led up to the decision to replace LIBOR, as well as some metrics estimating the scope of commercial and consumer financing transactions that may be affected as of the Effective Date. In addition, this Alert will provide an analysis of factors to be considered when reviewing loan documents using LIBOR as an index, as well as risk-related approaches for drafting provisions to include in current and future loan documents. 2. Background LIBOR—which stands for the “London Interbank Offered Rate”—is a calculation announced each morning by the ICE Benchmark Administration (the “ICE”), and is calculated each day based on the representations of panel banks as to the rates at which they could each borrow on the London interbank lending market.1 Unfortunately, over the years the calculation of LIBOR was regularly manipulated by traders, with the result that over the course of the last decade certain large money-center banks and other trading organizations paid over $9 billion in fines and penalties.2 Ultimately, the determination by U.S. and EU governmental and private organizations was to phase out the use of LIBOR, and to cease announcing LIBOR daily values rates as of December 31, 2021. Following this decision, several governmental and trade association groups have been analyzing replacement indices for LIBOR, including the following: SOFR—The Secured Overnight Financing Rate (the “SOFR”) SONIA—The Reformed Sterling Overnight Index Average TONAR—The Tokyo Overnight Average Rate SARON—The Swiss Average Rate Overnight EONIA—The Euro Overnight Index Average A Modified Version of LIBOR (as calculated by ICE) In June of 2017, the “Alternative Reference Rates Committee” or “ARRC,” which was created by the Federal Reserve Board to identify an alternative, transaction-based reference rate to replace LIBOR, designated the SOFR as its preferred substitute for USD LIBOR.3 Since that time, the ARRC has issued numerous studies and analyses regarding the use of the SOFR,4 and has issued draft language not only for use by the swaps and derivatives markets, but also draft commercial loan language and proposed recommended language to be used for residential mortgage instruments.5 On September 19th, the ARRC issued a draft project plan approach, discussed below, to assist financial institutions in the implementation of a LIBOR substitution process. The task of addressing the elimination and replacement of LIBOR as an index is daunting—for the swaps and derivatives markets the notational amount of LIBOR-based instruments as of the Effective Date is estimated to exceed $180 trillion dollars; for commercial and consumer loans the principal amount may exceeds $20 trillion. Moreover, since in all markets there will be transaction documents outstanding on the Effective Date that will continue to employ LIBOR as the designated index, counterparties will be faced with literally trillions of dollars of instruments requiring modification. Since no replacement index can be certain to track LIBOR values identically, winners and losers in any replacement scenario may experience gain or loss when a new index is substituted. This may or may not be addressed by changes in margins used in conjunction with a LIBOR value to determine a transaction’s rate of interest (discussed in greater detail below). 3. The Components of an Index Replacement Event When considering the replacement of LIBOR, several questions need to be answered to determine a course of action—both as to current instruments that employ LIBOR as an index and for new loans originated between now and the Effective Date: What is the Triggering Event? A triggering event refers to an event that requires the replacement of one index with another. In this context, the event is the cessation of announcing a current LIBOR value. Is there a Contractual Methodology to be Followed? Assuming that a triggering event occurs, does the current instrument being analyzed provide a procedure to be followed with respect to the replacement of LIBOR with another index? Can the Margin also be Replaced/Adjusted? Usually expressed in terms of basis points, does the instrument being analyzed address whether the spread over (or under) the chosen index (i.e., the “margin”) may be adjusted to align with the interest rate immediately prior to the LIBOR substitution? What is the Index that will be the Substituted Index? This is the selected reference rate that will be used to set the interest rate for adjustable rate transactions, which will adjust from time to time. 4. Replacement Factors Considerations The following are several significant considerations that impact each of the four factors identified above. A. Triggering Event Because the administration of credit transactions is typically handled by an originating lender, an administrative agent or a servicer, a decision to declare that a triggering event has occurred creates potential risk of objections being raised by borrowers against creditors and their agents. Although it might seem that the cessation of the use of LIBOR is straightforward, applying the applicable contract language may not be. For example, frequently triggering events are described when an index is no longer “available.” (e.g., daily LIBOR values are no longer printed in the Wall Street Journal or another designated authoritative source.) Similarly, disputes may arise if the calculation of LIBOR becomes so unreliable that its continued use is inconsistent with the intent of the counterparties. (e.g., ICE elects to modify its calculation of LIBOR in a manner that no longer reflects the methodology or movement of the current/original calculation methodology of LIBOR.) B. Fallback and Replacement Methodology Contractual language describing index replacement methodology is frequently deficient when describing the process and procedure how LIBOR may be replaced. In many cases, the authority to make the replacement is solely held by the creditor or holder of the promissory obligation. Ignoring for a moment the presence or absence of contractual authority to adjust the margin at the same time that a LIBOR index is replaced, discussed below, in the absence of clear rules, replacement of an index could be objected to due to: (i) the authority of a lender to select a replacement index that is detrimental to a borrower; and (ii) the timing and value of the index actually selected. For example, loan contract language may authorize a lender or holder to select a replacement index that is “based upon comparable information.” Because the SOFR is a secured index rate (as compared to LIBOR, which is an unsecured index rate and includes a credit risk component), and therefore likely to be lower than LIBOR, a lender may not want to substitute SOFR for LIBOR unless it can simultaneously adjust the margin to reflect the difference. A borrower may object to the lender’s choice of an alternate index, particularly if SOFR becomes the new “market standard.” Where the lender has the authority to adjust the margin, a borrower may object to the margin adjustment as not properly reflecting the likely variance between SOFR and what LIBOR would have been. Similarly, the timing and related procedure by which LIBOR is replaced may be a source of dispute. Since the SOFR has been shown to experience short-term spikes in value, a selection of the substituted SOFR index value within a short time period might benefit or harm each respective counterparty.6 For example, if the SOFR is chosen as the replacement index and it varies to any significant degree within a 30-day period, the SOFR value on the date being used to substitute for the LIBOR index may not be deemed to be “comparable” with LIBOR as of the date computed.7 In addition, the actual authorization of the creditor to select and substitute a replacement index might be challenged, particularly in instances in which contract language is imprecise or unclear. In such circumstances, parties might be required to agree to an independent person or entity to direct the substitution and replacement of a LIBOR index value. C. Margin Replacement/Adjustment When evaluating the elimination of LIBOR, the issue of margin adjustment may create the most significant legal risk for litigation, based upon several factors. First, due to drafters’ inability to anticipate future developments, many credit documents, such as numerous standard residential mortgage documents, do not address the authority to adjust the margin value when a substitute for LIBOR is selected. Unless the timing for the substitution is fortuitous, in the absence of the contractually stated ability to adjust the margin (to reflect as closely as possible the value of LIBOR plus the margin immediately prior to the substitution), either the creditor or the borrower may suffer an adverse interest rate result. For example, in the instance in which a securitization has occurred involving variable rate instruments, the holder of securities might incur significant loss of expected income if an underlying loan pool substitutes a SOFR index for a LIBOR value without a concomitant adjustment to the margin. Similarly, in the same manner that timing issues may affect the substituted index value, the date from which a margin is calculated may also create disputes. For example, consumer mortgage notes frequently require that an index value used to adjust the interest rate be the index value 45 or more days prior to the effective date of an interest rate change. If a substituted index value is adopted that looks back to a date for resetting a margin—yet the substituted index moves between the calculation date and the effective date of the adjusted interest rate—an change in the index that might affect the resetting of the margin might also be challenged. Finally, industry participants and ARRC members have indicated that a “margin adjustment” might be calculated as a component of a LIBOR replacement process. While this approach is meritorious in concept, in the absence of contractual language authorizing the use of a margin adjustment legal risk is presented. D. The Substituted Index Although the ARRC is viewed as taking the lead adopting a consensus approach for a substitute for US dollar LIBOR (i.e., it appears to be the SOFR), the policy perspectives of many members of the ARRC may differ from those of the commercial and consumer lending industry. Stated another way, ARRC and the parties with the power to substitute indexes may disagree about whether the SOFR is an appropriate choice for a substituted index.8 Moreover, the ARRC’s announced substitution language has been criticized as being too complicated for many categories of commercial and consumer credit transactions.9 As this replacement process moves forward, assuming SOFR remains the preferred alternative of the ARRC, commercial and consumer lenders not involved in the swaps and derivatives markets might consider whether other announced indices may be more suitable for their lending products and management of their cost of funds. 5. The ARRC Project Plan Checklist As noted above, on September 19th, the ARRC released a checklist, entitled “Practical Implementation Checklist for SOFR” (the “Checklist”) that might be used as part of a project plan for implementing a LIBOR substitution strategy.10 The Checklist includes the following steps a financial intermediary might consider as part of an implementation strategy: Establish Program Governance Develop Transition Management Program Implement Communication Strategy Identify and Validate Exposure Develop Product Strategy Risk Management Assess Contractual Remediation Impact and Design Plan Develop Operational and Technology Readiness Plan Accounting and Reporting Taxation and Regulation While the Checklist may be a useful starting point for those institutions that are at the early stages of developing a LIBOR substitution plan, we note that, in our view, the Checklist is deficient in its approach. First, it appears to have been written by consultants and largely ignores the fact that the LIBOR issue itself requires a legal analysis of existing and proposed financing documents and the legal risk presented to a financial institution. Stated another way, we believe that, as an initial step in the substitution process, an institution must identify and categorize its varying degrees of litigation risk (e.g., based upon the content of its financing documents) and develop a substitution strategy that addresses litigation exposure. Second, the Checklist indicates that it is focused on “banking institutions,” whereas non-bank and consumer lenders are equally exposed to LIBOR-related litigation risk. Finally, as analyzed in this Alert, larger financing transactions may involve multiple layers of LIBOR-related risk, and the Checklist maybe too simplistic as an effective tool for financial intermediaries to employ. 6. Loan Document Modification Regardless of the status of the replacement factors and the selection of a substitution index, we offer the following observations. First, while most commercial loans (particularly non-real-estate secured credits) are of shorter term and will begin to run off sooner than other classes of commercial and consumer loans, it may be prudent to look for opportunities to clarify the index substitution provisions set forth in loan documents. In the instance in which a renegotiation would support adequate consideration for the adoption by counterparties of fulsome substitution language, from a risk perspective such a strategy might be advisable. Addressing the margin adjustment concern should be a high priority.11 Second, on a go-forward basis, we suggest that a lender draft index replacement provisions that are reflective of their customer base. By this we mean that one size does not fit all. For example, the ARRC has promulgated an extensive set of commercial contract provisions—which may be appropriate for large syndicated loans but not bilateral portfolioed commercial credits. Similarly, the ARRC has recently issued language for mortgage documents—but ultimately most lenders will adopt mortgage contract modifications as issued and required by Fannie Mae and Freddie Mac.12 Third, several segments of the commercial and consumer loan market continue to use LIBOR as the chosen index value. Unless a lender is comfortable with the index replacement language contained in its lending documents, and particularly for longer-term transactions where the runoff period (and therefore the impact of an index substitution) may be substantial, it may be prudent to adopt a new index prior to the Effective Date to minimize the risk presented. *       *       * Please note that this Alert is intended to reflect recent developments in the efforts by commercial and consumer lenders to address the impending elimination of LIBOR. We have not focused on the parallel developments in the derivatives market, where other considerations may predominate. The LIBOR substitution developments discussed herein are anticipated to accelerate in the coming months; members of Dorsey’s Finance and Restructuring Group are available to discuss any questions or concerns that may arise. 1 LIBOR is calculated and announced in five currencies (CHF, EUR, GBP, JPY and USD) and seven tenors (Overnight/Spot Next, 1 Week, 1 Month, 2 Months, 3 Months, 6 Months and 12 Months) based on submissions from a reference panel of between 11 and 16 banks for each currency, resulting in the publication of 35 rates every applicable London business day. See, https://www.theice.com/iba/libor?utm_source=website&utm_medium=search&utm_campaign=spotlight. 2 Among other things, the use of estimates rather than actual LIBOR transactions diminished the market’s confidence in LIBOR as a reliable baseline of interbank short-term borrowing costs. 3 https://www.newyorkfed.org/arrc/about. For transactions denominated in pound sterling, the SONIA has been designated as the announced replacement index. (Whether a UK-based index will experience unanticipated fluctuations in value caused by Brexit is a source of concern.) 4 The ARRC has issued a graphic presentation of its “Paced Transition Plan” at https://www.newyorkfed.org/arrc/sofr-transition. 5 See, https://www.newyorkfed.org/medialibrary/Microsites/arrc/files/2019/ARRC-May-31-2019-announcement.pdf; https://www.newyorkfed.org/medialibrary/Microsites/arrc/files/2019/ARRC-Consultation-Paper-Fallback-Language-Consumer-ARM-announcement.pdf. 6 It should be noted that complex syndication and securitization transactions require an analysis to correctly identify the entity (or entities) authorized to direct substitution of index procedures, including the degree to which security holders or syndicate members are required to be consulted or otherwise hold voting rights. (Further, related transaction documents such as hedge positions create the possibility that multiple index substitutions may be required.) 7 For example, several Fannie Mae and Freddie Mac variable rate mortgage instruments require the use of an index value in effect 45 days prior to the date an interest rate change date is scheduled to occur. 8 As an example of difficulties presented, this matter, the ARRC has indicated that variations in the value of the SOFR have yet to be developed and announced on a regular basis, such as weekly, monthly and yearly SOFR values. 9 While beyond the scope of this Alert, it should be noted that the ARRC’s suggested replacement language may only be appropriate for use in very large and complicated financing transactions. For smaller dollar amount or less complicated loans, this presents lenders with a business decision whether to draft replacement language deemed acceptable to a particular market segment and transaction category. 10 See, https://www.newyorkfed.org/medialibrary/Microsites/arrc/files/2019/ARRC-SOFR-Checklist-Press-Release-20190919.pdf. 11 In the case of the syndicated commercial loan market, the Loan Syndications and Trading Association has issued several useful interpretative and guidance documents addressing alternative approaches to index substitution language. See, https://www.lsta.org/content/the-great-migration-away-from-libor/. 12 As of the date of this Alert, both Fannie Mae and Freddie Mac have not ceased purchasing Libor-based variable rate mortgage loans, and their standard LIBOR mortgage notes do not include a margin substitution provision.  

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?

Insights

Energy Law: Month in Review - September 2026

Welcome to Dorsey’s Energy Law: Month in Review. We provide this update to our clients to identify significant developments in the previous month. Please reach out to any of the authors, listed above, to discuss these issues. Regulatory Developments Massachusetts Ratchets Up State and Local Regulation of AI Data Centers In early September, Governor Maura Healey of Massachusetts signed an executive order requiring that artificial intelligence data centers secure the approval of local communities as a precondition to proceeding with a given project. According to the terms of the order, data center developers will need to secure a “community benefits agreement” as a precondition to receiving permits from numerous state agencies, including the Department of Environmental Protection, the Energy Facilities Siting Board, and the Massachusetts Environmental Policy Act Office. Beyond requiring community benefits agreements, the order also mandates that developers mitigate utility costs to consumers, prohibits the use of nondisclosure agreements, and requires various state agencies to develop measures to limit data center impacts on the environment. North Carolina Regulators Decline Approval of Duke Energy Gas Turbine On September 18, 2026, North Carolina Utilities Commission (NCUC) denied Duke Energy’s application for a certificate of public convenience and necessity required to construct a gas-fueled combustion turbine at its Smith Energy Complex in North Carolina. The NCUC objected strongly to the $584 million price tag and noted that Duke appeared to be constructing the facility “based on anticipated data center customer additions.” The NCUC rejected that anticipated growth as “insufficiently reliable for the Commission to act at this point.” In rejecting Duke’s application, the NCUC also noted that Duke had signed the White House Ratepayer Protection Pledge, in which it represented that it would not shift data center costs to consumers. The NCUC observed that the record did not demonstrate how Duke “intends to adhere to its commitments under the Ratepayer Protection Pledge with regard to the Proposed Facility.” Notably, commission staff had actually supported the construction of the turbine, citing concerns about Duke’s reserve margins. The NCUC noted that it “understands the Public Staff’s expressed concerns,” but those concerns were outweighed by the NCUC’s reservations, including questions of demand. Department of Energy Approves Funds for Grid Improvement The U.S. Department of Energy (DOE) recently announced that it would fund 31 grid-improvement projects in 26 states. The funding initiative is part of the DOE’s “SPARK” initiative. The funding will include $1.9 billion in federal funding from DOE and $3.35 billion in recipient cost-sharing funding. The funds will go to projects designed to improve grid reliability and lower electricity costs. Recipients plan to reconductor over 1,500 miles of transmission lines and will deploy grid-enhancing technologies across approximately 21,000 miles. DOE stated that this initiative will make available over 23 additional gigawatts of electricity. Texas Moderates Rules Governing Data Center Interconnection The Texas Public Utility Commission adopted new regulations governing large-load interconnections. The rules impose a flat study fee of $100,000 for all proposed interconnections, which departs from the initial proposal to impose study fees using a tiered system based on project size. Additionally, the final rule eliminates the PUC’s previous proposal to impose a non-refundable interconnection fee of $50,000 per MW of contracted peak demand. The final rule also moderates the initially proposed regulations governing Electric Reliability Council of Texas (ERCOT) notifications for large-load customers’ non-utilized capacity. The proposed rules would have required notifying ERCOT within 30 days of missing a scheduled energization milestone by six months. The final rules, however, do not require informing ERCOT unless a scheduled energization milestone is missed by 24 months. FERC Denies TransAlta 202(c) Cost-Recovery Plan The Federal Energy Regulatory Commission (FERC) recently rejected TransAlta’s plan to recover $19.9 million in expenses stemming from a DOE order in which DOE prohibited TransAlta from retiring its coal-powered Centralia power plant. TransAlta had previously intended to retire the facility at the end of 2025. TransAlta’s cost recovery plan proposed spending an additional $23 million on repairs to continue operating the unit. FERC’s main objection had to do with geographic scope. TransAlta’s recovery plan called for recovering costs from California Independent System Operator (CAISO) and the Southwest Power Pool (SPP), but the DOE’s order requiring operation of the plant was designed to ensure reliability in the Northwest assessment area (Montana, Oregon, Washington, and parts of northern California and northern Idaho). Accordingly, FERC was unwilling to allow cost recovery from CAISO and SPP when the order that precipitated the additional costs only related to the Northwest assessment area. FERC informed TransAlta that it would only approve cost recovery from load-serving entities in the Northwest assessment area. FERC’s decision comes amid a rush of DOE emergency orders requiring the continued operation of coal-fired generating units. Litigation Appeals Court Upholds Washington Hydropower Plant With Caveats In a September 21, 2026, opinion, the Washington Court of Appeals largely upheld a Clean Water Act water quality certification by the Washington Department of Ecology for the Goldendale Energy Storage Project, a proposed pumped-water storage hydropower system adjacent to, but off-stream from, the Columbia River. A nonprofit (Columbia Riverkeeper) and the Confederated Tribes and Bands of the Yakama Nation appealed the certification, contending that it failed to impose necessary conditions and monitoring requirements to protect the water quality of the Columbia River. Most saliently, the plaintiffs argued that the project had the potential to leak 100 acre-feet of water per year into tributaries of the Columbia River. The Court of Appeals broadly rejected plaintiffs’ challenge to the state’s conclusion that “the project was designed not to leak.” That said, the Court of Appeals did reverse on one narrow issue. Specifically, the court determined that the state’s conclusion that “leakage from the project’s tunnels would be monitored and reported” was not supported by the evidence because the certification “does not explicitly require monitoring and reporting to determine whether there is any leakage.” Accordingly, the court remanded the matter to the state to impose monitoring and reporting requirements but otherwise affirmed the certification. Legislative Developments California Legislates Restrictions on Data Center Energy Use and Grid Costs On September 21, 2026, California Governor Gavin Newsom signed seven bills broadly regulating data centers in the state. SB 1168 directed the California Public Utilities Commission to assess the energy used by data centers. It also requires the PUC to pass costs of transmission and distribution upgrades and load increases on to data centers, rather than customers. SB 886 and SB 887 compel data centers to pay for infrastructure upgrade and generation costs, and wildfire mitigation costs, in addition to imposing environmental review. The statutes additionally increase local oversight of data centers. AB 1577 imposes a monthly reporting requirement that requires data centers to supply energy consumption and efficiency data to the California Energy Commission. AB 2383 contains incentives for data centers to use onsite clean energy generation. Finally, AB 2469 and AB 2619 require data center developments to assess water supply and develop a water scarcity plan. The statutes also mandate statewide water reporting as a precondition to obtaining and renewing business licenses.

Insights

SEC Proposes Expansion of Investment Adviser Performance-Based Compensation Rule

On September 30, 2026, the Securities and Exchange Commission (the “SEC”) proposed amendments to Rule 205-3 under the Investment Advisers Act of 1940, as amended (the “Advisers Act”), which provides an exemption from the general prohibition under Section 205(a)(1) of the Advisers Act on registered investment advisers receiving performance-based compensation (the “Proposal”) so long as performance-based compensation is limited to “qualified clients”.1 Most notably for private fund sponsors, the Proposal would expand the definition of “qualified client” to include any investors that satisfy the “accredited investor” definition under Regulation D. The Proposal may also have implications for private fund managers that rely on exemptions from investment adviser registration under state law because certain state-level investment adviser registration exemptions incorporate or otherwise reference the federal qualified client definition. Expansion of the Qualified Client Definition Under the current Rule 205-3, an investor generally may qualify as a qualified client if, among other alternatives, the investor has at least $1.4 million under management with the adviser or has a net worth exceeding $2.7 million. These thresholds are higher than the financial thresholds applicable to many accredited investors under Regulation D. As a result, an investor may currently qualify as an accredited investor for purposes of investing in a private offering without qualifying as a qualified client for purposes of paying performance-based compensation. The Proposal would expand the qualified client definition to include any natural person or legal entity investor that satisfies the accredited investor definition under Regulation D. The Proposal would also remove the assets under management and net worth thresholds under the current Rule 205-3 qualified client test. For private funds relying on Section 3(c)(1) of the Investment Company Act of 1940, this change could reduce the need to apply a separate qualified client standard to investors that already qualify as accredited investors. Dorsey Observations and Next Steps If adopted as proposed, the expanded qualified client definition could be particularly significant for private fund managers. Most private fund offerings are already limited to accredited investors under Regulation D. However, the Proposal could expand the pool of prospective investors available to emerging private fund managers while reducing the regulatory burden associated with complying with Rule 205-3. The Proposal could also benefit advisers operating below the SEC registration threshold that rely on a state private fund adviser exemption. A number of states have adopted exemptions modeled on the North American Securities Administrators Association (“NASAA”) private fund adviser exemption, which may condition relief for advisers to certain funds relying on Section 3(c)(1) on each beneficial owner satisfying the federal qualified client definition. However, state requirements vary, and any effect of the Proposal would depend on the text of the applicable state exemption and how it incorporates Rule 205-3. Many emerging private fund managers may have a larger network of accredited investor relationships than qualified client relationships during the early stages of their investment advisory business. Currently, under Rule 205-3, private fund managers may receive performance-based compensation from investors who do not satisfy the qualified client definition if those investors were admitted to their private funds prior to registration with the SEC. Following registration with the SEC, however, managers may continue to permit investors that are not qualified clients to invest in future private funds but may not receive performance-based compensation from those investors with respect to such investments. In addition, because the net worth and assets under management thresholds for qualified client status are adjusted for inflation every five years, the pool of qualified client investors may diminish over time as previously eligible investors no longer satisfy the applicable thresholds. The Proposal could provide the dual benefit of greater flexibility for private fund managers to establish and maintain relationships with accredited investors as their businesses scale and they become registered with the SEC, and greater flexibility for certain accredited investors to participate in investment strategies that historically have been restricted to much larger institutional investors. Unless and until the Proposal is adopted, investment advisers should continue to comply with the existing qualified client requirements. If the Proposal is adopted, private fund sponsors should consider whether corresponding changes are appropriate for their subscription documents, investor questionnaires, and other offering materials. Advisers that are state-registered or rely on a state-level exemption should also consult the laws and regulations of each relevant jurisdiction before changing investor eligibility standards or performance-based compensation practices, because adoption of the federal amendments may not automatically modify state requirements. Comments on the Proposal will be due 60 days after publication in the Federal Register. 1 Investment Adviser Performance-Based Compensation Modernization, Investment Advisers Act Release No. IA-7022 (Sept. 30, 2026), available at https://www.sec.gov/rules-regulations/2026/09/s7-2026-28#33-11443proposed.

Insights

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.