.

Brad Wright structures cross-border real estate and business transactions for growth-stage and global enterprises entering the U.S. market, so they can secure sites, capture incentives, and build lasting roots in Arizona.

Brad brings more than 30 years of experience to clients navigating the intersection of real estate development, economic development, and cross-border investment in Arizona and across the United States. He focuses on helping Taiwanese and other Asia-Pacific (APAC) companies establish and expand their facilities, operations, and workforce in the U.S.—guiding them through site selection, regulatory approvals, incentive negotiations, and community integration as they develop manufacturing plants, mixed-use projects, and employee communities.

Brad's practice draws on a career that spans both in-house general counsel roles and private practice, giving him a practical perspective on high-stakes real estate transactions, infrastructure projects, and crisis management. He negotiates directly with state and local governments on economic development incentives, structures joint ventures between international partners, and advises on the full lifecycle of commercial real estate transactions—from land acquisition and construction financing through disposition.

Brad serves as Global Co-Chair of Dorsey & Whitney's Real Estate Practice Group, and the Chair of Dorsey’s Taiwan/US Practice Group.  His leadership in Arizona's economic development community is reflected in his service on the Executive Committee of the Greater Phoenix Economic Council (GPEC), a regional organization focused on attracting and supporting foreign direct investment, including major APAC-based projects in advanced manufacturing and technology. He was also part of the founding team of the Greater Maricopa Foreign Trade Zone in Western Maricopa County, Arizona.

Brad has been appointed by multiple Arizona Governors to various boards and commissions, including two terms as a Governor's appointee and past Chairman of the Arizona Sports and Tourism Authority. He served as Chairman of the Arizona Organizing Committee for the 2016 College Football Playoff Championship Game and as a board member of the Phoenix Local Organizing Committee for the 2017 NCAA Final Four.

Chambers USA recognizes Brad in Real Estate.

Select Experience

Cross-Border & APAC Investment

  • Represented a Taiwanese engineering company on the acquisition of a 100,000-square-foot commercial office building and 18 acres of adjacent land for development in Arizona.
  • Represented a Taiwanese chemical manufacturing company on the acquisition of land for the construction of a manufacturing facility and the negotiation of construction financing.
  • Represented a Korean semiconductor manufacturing company in negotiations with the State of Arizona over incentives to locate operations in the Phoenix Metropolitan Area.
  • Represented a Japanese chemical manufacturing company on negotiations of power infrastructure necessary for a major plant expansion in the Phoenix Metropolitan Area.

Education

  • Washington University School of Law (J.D., 1991)
  • Illinois State University (B.S., Accounting, 1988)

Bar Admissions

  • Arizona

Accolades

  • Chambers recognized 2026
  • Best Lawyers in America®, Real Estate Law, 2025-2026
  • Consistently providing pro bono legal assistance to those in need through Dorsey’s Pro Bono program
  • People to Know in Commercial Real Estate, AZ Big Media, 2020
  • 20 People to Know in Law, Phoenix Business Journal, 2016

Professional Affiliations

  • Executive Committee Member, Greater Phoenix Economic Council (2014 – Present)
  • Executive Committee Member, AZ Chamber of Commerce (2016 – 2024)
  • Board Member, Valley Partnership (2000 – Present)
  • Board Member, Greater Maricopa Foreign Trade Zone (2012 – 2024)

Court Admissions

  • U.S. District Court, District of Arizona
  • U.S. District Court, Eastern District of Missouri

Select Speaking Engagements

  • SAID Districts – GPEC hosted Webinar September 28, 2026.
  • Taiwanese / Arizona Investment Conference: hosted by the Arizona-Tiawan Trade and Commerce Investment Office March 2, 2026, and July 27, 2026.

Insights

Media Mentions

Brad Wright Explains What TSMC’s Investment Means for Arizona’s Future

July 23, 2026

Phoenix Real Estate Partner Brad Wright provided insight into Taiwan Semiconductor Manufacturing Company’s (TSMC) announcement of a new $100 billion investment in U.S. business, potentially including four new chipmaking factories in Arizona. Brad described the state as “the world’s epicenter for the manufacturing of advanced semiconductor chips” in an AZCentral article. "TSMC's newly announced commitment of an additional $100 billion will accelerate the already great demand for industrial-flex, logistics parks, R&D campuses, and workforce housing across the north Phoenix and east Phoenix corridors," Brad told the Phoenix Business Journal. He added, "We're seeing Taiwanese investors already positioning for land near TSMC's facilities and along Interstate 10 logistics routes. The market will absorb significant acreage for supplier clustering. Commercial office space for engineering, design, and corporate functions will follow. This is a once-in-a-lifetime, multibillion-dollar real estate event." Speaking with the Peoria Independent, Brad noted that Peoria, advantageously located along the microchip supply chain and home to Amkor Technology’s $7 billion plant, is a model for how a city positions itself ahead of a wave. “By partnering with the State Land Department, investing in infrastructure, and landing an anchor like Amkor, Peoria created a landing zone for the suppliers and manufacturing that follow TSMC’s expansion. Their investment is precisely why that groundwork matters.” Brad’s analysis was featured across numerous outlets, including: Dorsey Article – State Affordability Infrastructure Districts (SAIDs) — A Financing Tool for Taiwanese Investment in Arizona Science and Technology Parks Dorsey Article – The Long-Awaited Public Infrastructure Financing Solution for Development in Arizona AZCentral – $265 Billion Investment from TSMC is 'Vote of Confidence' in Arizona Peoria Independent – TSMC’s Additional $100B Investment in Arizona Bodes Well for Peoria Fox 10 Phoenix – Taiwan Chipmaker TSMC Could Bring New Factories to Phoenix as Part of Investment Plan Phoenix Business Journal – TSMC to Invest an Additional $100 Billion in Arizona Fab Site

Client Alert

The Long-Awaited Public Infrastructure Financing Solution for Development in Arizona

July 15, 2026

Every developer who has taken raw Arizona ground to a finished project knows the largest upfront cost other than the land price is almost always the cost to install the public infrastructure. Water, sewer, stormwater, streets, dry utilities, and the fiber backbone all have to be in the ground before a single lot closes or a building opens. That capital is deployed early and generates no return for years. For decades the standard workaround has been the Community Facilities District (CFD). That tool has grown materially harder to use, for reasons cited below, and House Bill 2999, signed in June 2026 and now codified as Chapter 40 of Title 48, is Arizona's response. Some Background I have spent a good part of my career on the other side of this problem. In the 1990s and early 2000s I served as general counsel of SunCor Development Company, one of Arizona's most active master-planned community developers, where we used Community Facilities Districts to finance hundreds of millions of dollars of major infrastructure across Arizona in cities such as Goodyear, Phoenix, Tempe, Litchfield Park, and Prescott Valley. For its time the CFD was an effective structure, and a great deal of what is now on the ground in those communities was financed with this tool. Unfortunately, CFDs have over time become considerably harder to use. Successive legislative amendments have layered on tax-rate ceilings, homebuyer disclosure obligations, and added procedural steps. Another drag on the use of CFDs is that formation of them runs through the municipality, where approval can turn as much on local politics as on the merits of a project. Developers now routinely are asked to absorb delay and uncertainty that a project's economics cannot support, which is a large part of why Arizona has fallen behind Colorado, Texas, and Utah in getting infrastructure financed. A better tool was needed, and Chapter 40 is it. How a SAID Improves on a CFD A State Affordability Infrastructure District (SAID) keeps what worked about the CFD: tax-exempt, property-secured, non-recourse infrastructure financing — while shedding much of what made the CFD cumbersome. Its principal advantages over a traditional CFD: Administrative formation. A SAID is formed by the Arizona Finance Authority against fixed statutory criteria, through a yes-or-no compliance review on a sixty-day clock, rather than through the discretionary approval of a city council or a board of supervisors. Insulation from municipal politics. Because formation is a state-level compliance determination, a meritorious project is far less exposed to local political headwinds than it is under the CFD process. Landowner control of the board. A SAID is governed by a board of the landowners — appointed at formation, then elected on an acreage basis. In a typical municipal CFD, the city council sits as the district board; here, the developer controls governance. Advance funding of impact fees. A SAID can use bond proceeds to advance-pay municipal development impact fees, unlike CFDs, removing one of the largest upfront cash burdens in a project. A uniform, statewide process. The criteria are the same regardless of jurisdiction, replacing the municipality-by-municipality variation that has made CFD outcomes hard to predict. Flexible boundaries. A district may include noncontiguous parcels in the same county within five miles of one another, which fits phased and multi-tract development. Capped cost and a fixed timeline. Authority fees to form a district are capped at $15,000, and a complete petition must be acted on within sixty days. The full range of bonds. A SAID may issue general obligation, special assessment, revenue, and refunding bonds, secured solely by district property and creating no obligation for any other taxpayer. What is a SAID A SAID is a special taxing district that the owners of a development form to finance public infrastructure with tax-exempt bonds: general obligation bonds, special assessment bonds, and revenue bonds. The bonds are secured only by the property inside the district and are repaid over the long term, with terms up to 30 years. They do not affect the credit of the city, the county, or the State, and they create no obligation for any taxpayer outside the district. In practical terms, a SAID lets you finance horizontal infrastructure over the life of the asset instead of writing the check at the front end. The maximum ad valorem rate securing general obligation bonds is capped by statute at $5.00 per $100 of net assessed limited property valuation, with a limited step-up to cover a debt-service shortfall. SAIDs Work for Commercial as Well as Residential Development The SAID bill drew most of its press as a housing-affordability measure, and it appears to be a strong one. It is the first Arizona district statute to let bond proceeds advance-fund municipal development impact fees, which pulls one of the largest upfront cash burdens off a homebuilder's pro forma. But the statute's eligible infrastructure categories apply with equal force to commercial, industrial, and mixed-use projects. An industrial or logistics project can finance roads, rail crossings, sidings, and grade separations. A life-sciences or technology campus can finance its water, sewer, roads, and broadband the same way a subdivision can. Read Chapter 40 as a general-purpose infrastructure finance platform, not a subdivision-only device. How Formation Works A SAID is formed administratively by the Arizona Finance Authority. The Authority reviews the petition for compliance with the statute; it is a yes-or-no review against fixed criteria, not a discretionary negotiation with a city council or a board of supervisors, and it runs on a sixty-day clock once a complete petition is filed. Formation requires the written consent of 100% of the landowners in the proposed district and an engineer's certification that public infrastructure costs will exceed $5 million. The district may include noncontiguous parcels so long as they lie in the same county and within five miles of the district's other property, which accommodates phased and multi-tract development; if any part of the district sits inside a municipality, the whole district must stay within that municipality's limits or planning area. The Authority's fees to form a district are capped at $15,000. Issuing bonds requires a district election. Governance Simplified A SAID is run by a three-member board. The initial directors are named in the petition; after that, directors are elected by the landowners on an acreage basis as ownership diversifies. Board service runs with ownership; a director must either hold fee title inside the district or be an individual designated by a fee-title owner; and corporations, partnerships, and other entities may hold that ownership, vote as owners, and designate the individual who serves. A district has no power of eminent domain and no zoning authority, and directors may not be officials or employees of the municipality in which the district sits. What a SAID Does Not Do It finances; it does not entitle. Zoning, platting, rezonings, use permits, and the specialized approvals a manufacturing or life-sciences facility may need all remain with the local jurisdiction and proceed on their own track. The financing and entitlement timelines should be coordinated with formation of the SAID, but they are separate processes. Two substantive limits are worth flagging at the planning stage. First, electric power is largely outside the tool: the statutory definition of public infrastructure does not reach power generation or transmission, and broader energy infrastructure was removed from the bill during the Senate amendments. A power-intensive user should not assume a SAID will carry its electrical load. Second, where water, sewer, or wastewater facilities fall within a regulated utility's certificated service territory, the district cannot build or own them without the utility's written consent and must convey them to the utility upon completion. Our Take For most master-planned residential work, and for a wide range of commercial and industrial development, a SAID will be the most efficient infrastructure-financing structure Arizona has offered. The right time to evaluate it is early in the acquisition and pre-development process, while the capital stack, the development agreement, and the entitlement strategy are still being set. Once the district's boundaries, general plan, and financing parameters are set, it is cumbersome at best to bring those into conformance later. Our Dorsey team has begun advising our developer clients on SAID formation on residential, commercial, and industrial projects statewide. If you would like us to assess whether a SAID fits a project you are working on, please reach out.

Firm Highlights

Insights

Energy Law: Month in Review - September 2026

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

Insights

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.

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

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.

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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?