On Wednesday, September 30th, Senate Energy and Natural Resources (ENR) Chairman Mike Lee, ENR Ranking Member Martin Heinrich, Environment and Public Works (EPW) Chairman Shelley Moore Capito, and EPW Ranking Member Sheldon Whitehouse released the Bipartisan American Affordability and Jobs Act of 2026, a 417-page bipartisan permitting reform package.

Chairman Lee said the bill will “fix this broken process and get America back to building.” Ranking Member Heinrich said, “it should not take decades to build the infrastructure our country needs,” and Ranking Member Whitehouse said the bill will “make data centers start paying their fair share.” No markup date has been announced. Chairman Capito said the sponsors will work with the House and President Trump to get the bill signed into law.

The full bill text is linked here. Every page reference below links directly to the page of the bill where that section begins. This overview is not exhaustive. It highlights provisions affecting our clients’ key priorities: NEPA; electric transmission; oil and gas, particularly pipelines and linear infrastructure; data centers; Clean Water Act Section 404 and the Army Corps of Engineers; and judicial review reform.

KEY PRIORITY FINDER

Click a section number to jump to its summary below.

SECTION-BY-SECTION OVERVIEW

DIVISION A – COMMITTEE ON ENVIRONMENT AND PUBLIC WORKS

Title I – National Environmental Policy Act (NEPA)

Subtitle A – Declaration of Environmental Policy (Page 4)

Sec. 1101. Purposes; Procedure; Savings Provision (Page 4)

  • Declares that NEPA “prescribes a procedure” whose result is “an informational document” and that nothing in the Act “mandates a particular outcome,” codifying the view that NEPA is purely procedural.
  • Limits the scope of review to effects on the human environment “of the United States.”

Sec. 1102. Definitions (Page 5)

  • Moves NEPA’s definitions into a new Section 3 and redefines “major Federal action” to require “substantial Federal control and responsibility.”
  • Adds 14 exclusions from “major Federal action.” The most relevant to our clients:
    • Non-Federal projects with minimal Federal funding or involvement, or where the only Federal role is a loan or loan guarantee.
    • Grants and other financial assistance where the agency lacks “predominant control and responsibility.”
    • Repair, retrofit, or replacement of lifeline infrastructure that does not increase capacity by more than 20 percent.
    • Transmission activities in existing rights-of-way under new Federal Power Act (FPA) Sec. 216A(b) (see Sec. 2102).
    • Natural gas pipeline “covered activities” within existing corridors under new Natural Gas Act (NGA) Sec. 7(i)(1) (see Sec. 2102).
    • Army Corps of Engineers Continuing Authorities Program and environmental infrastructure projects with a Federal share of $50 million or less.
    • Routine administrative actions, including Federal facility repair and maintenance, up to $10 million, and actions already reviewed by another agency under NEPA.
  • Creates a “record of stakeholder engagement” that applicants must submit, capped at 20 pages. Defines purpose and need to include “the goals of the project sponsor.”
  • Lists the Corps of Engineers, FERC, DOE, DOT, Interior, EPA, and others as “key permitting agencies,” each with a chief environmental review and permitting officer.

Sec. 1103. Implementing Procedures (Page 25)

  • Requires all agencies to revise their NEPA procedures within 180 days of enactment and directs CEQ to standardize agency procedures “to the maximum extent practicable.”

Sec. 1104. Cooperation of Agencies; Reports; Availability of Information (Page 26)

  • Requires agencies to develop NEPA procedures in consultation with CEQ and in compliance with new eNEPA data and technology standards.

Sec. 1105. Procedure for Determination of Level of Review (Page 28)

  • Allows agencies to combine multiple categorical exclusions (CEs) for a single action, but not to repeat the same size- or acreage-capped CE, and to use CEs established by Congress.
  • No NEPA document is required where a State or Tribal environmental review, or compliance with another Federal law, “serves a similar function.”
  • Requires the lead agency to convert an environmental assessment (EA) into an environmental impact statement (EIS) at the project sponsor’s request.
  • If the lead agency determines no environmental document is required, “no agency shall prepare” one.

Sec. 1106. Timely and Unified Federal Reviews (Page 31)

  • Lead agency. If agencies cannot agree on a lead agency within 21 days, a sponsor may petition CEQ, which must designate one within 21 days. That designation is not subject to judicial review.
  • Cooperating agencies. Cooperating agencies must be invited within 30 days of the notice of intent and must respond within 7 days. They are bound by the lead agency’s purpose and need and its range of alternatives.
  • Single document. Agencies must use a single environmental document and a single schedule and run their reviews concurrently. Agencies need not consider research that becomes public after the notice of intent.
  • Alternatives. Alternatives that do not “meet the goals of an applicable non-Federal project sponsor” must be eliminated.
  • Deadlines:
    • EA: 1 year. EIS: 2 years. Both run from the earlier of the level-of-review determination or notice that the application is complete.
    • Finding of no significant impact (FONSI): 7 days after the EA. Record of decision (ROD): 45 days after the EIS.
    • All remaining Federal authorizations: 90 days for participating agencies, 120 days for others.
    • Public comment on a draft EIS: 45–60 days, and up to 75 days only if the sponsor agrees.
    • Deadline extensions now require the sponsor’s approval.
  • CEQ dispute resolution. A sponsor may elevate interagency disputes to CEQ. After 30 days of facilitation, CEQ issues a binding order within 14 days. The order is not reviewable and “shall constitute full compliance with” the underlying interagency consultation requirements.
  • Accountability for missed deadlines. Thirty days after a missed deadline, the agency’s permitting officer and senior staff must devote at least 50 percent of their workweek to the delayed project. After 60 days, the agency head may not travel more than 25 miles from the duty station on official business. The Department of Defense is exempt.
  • Sponsor lawsuits. Sponsors may sue over missed deadlines. The court must rule within 120 days and order a decision within 60 days. The agency’s defenses must be proven by clear and convincing evidence.
  • Existing EIS and EA page limits are unchanged.

Sec. 1107. Programmatic Environmental Document (Page 61)

  • Extends the period agencies may rely on a programmatic EA or EIS from 5 years to 10 years.

Sec. 1108. Use of Categorical Exclusions by Other Agencies (Page 62)

  • CEQ will maintain a public registry of all CEs. Agencies must report their existing CEs within 30 days and new CEs within 7 days.
  • Any agency may adopt another agency’s CE, or one established by Congress, after consulting the originating agency and publicly documenting the adoption.

Sec. 1109. Applications for Authorizations (Page 64)

  • Agencies must determine completeness or request missing information within 60 days of submission. They must then notify the sponsor of the level of review (CE, EA, or EIS) within 60 days after that.

Sec. 1110. Judicial Review (Page 67)

  • Filing deadline. NEPA claims must be filed within 150 days of the authorization being published or made public.
  • Standing and exhaustion. Plaintiffs must have filed a substantive comment raising the issue and must allege an injury “amounting to a direct harm.”
  • Forum. Claims go directly to the court of appeals for the circuit where the project is located. Judges are randomly assigned.
  • Remedies. The only remedy is remand “without vacatur or issuance of an injunction,” with a correction deadline of no more than 180 days. The authorization stays in effect and the project may proceed during remand.
  • Injunctions. Preliminary injunctions are available only for a likely violation of a law other than NEPA or the National Historic Preservation Act (NHPA). A NEPA violation alone cannot support an injunction.
  • Deference. Courts must give “substantial deference” to the agency on the scope and contents of environmental documents.

Subtitle B – Council on Environmental Quality (Page 74)

Sec. 1121. Council on Environmental Quality (eNEPA Technologies) (Page 74)

  • Requires CEQ to publish data standards within 60 days and implementation guidance within 120 days. Agencies must begin implementing within 180 days.
  • Creates a single GSA-hosted “ePermit” portal where sponsors submit all documents and track status in real time, to be in place by December 1, 2028. Authorizes $5 million per year for NEPA.

Subtitle C – Federal Permitting Improvement (Page 96)

Sec. 1131–1132. Definitions; Environmental Review and Permitting Tracker (Page 96)

  • CEQ will maintain a public online tracker of every EIS, and of any EA more than 13 months past its deadline. The tracker is updated quarterly and identifies whether each delay is attributable to the agency or the sponsor.

Sec. 1133. Permitting Improvement Fund (Page 101)

  • Creates a fund, directed by CEQ, to support permitting agency staffing, training, and process standardization. Authorizes $20 million per year for FY2027–2033.

Title II – Clean Water Act

Sec. 1201. Water Quality Criteria (Page 102)

  • Requires EPA to set Section 304(a) water quality criteria through notice-and-comment rulemaking. Challenges to any rule defining “waters of the United States” go directly to the courts of appeals. The bill does not change the WOTUS definition itself.

Sec. 1202. Clean Water Act Permitting and State Certification (Section 401) (Page 103)

  • Limits State Section 401 review to “water quality requirements” (CWA Secs. 301, 302, 303, 306, 307, and State or Tribal laws implementing them). States may deny certification or impose conditions only on clear and convincing evidence, and conditions must be the “least burdensome” option.
  • Sets the review period, which cannot exceed 1 year. If the State does not act in time, certification is waived. Extensions require both the applicant’s request and the State’s agreement.
  • Establishes application completeness rules. A prefiling meeting must be held within 60 days of an applicant’s request. For individual permits, the State must confirm completeness or identify missing items within 90 days.
  • Pipelines and transmission. For NGA Sec. 7 interstate gas pipelines and interstate bulk-power transmission lines, certification is required only where the project “may result in a direct point source discharge.” The review period for these projects is capped at 9 months.

Sec. 1203. Permit Term for NPDES Permits (Page 123)

  • Extends the maximum NPDES permit term from 5 years to 10 years.

Sec. 1204. Permits for Dredged or Fill Material (Section 404) (Page 123)

  • EPA veto. EPA may use its Section 404(c) veto only between submission of a complete application and the Corps’ issuance of the permit. This ends both preemptive vetoes and vetoes after a permit issues, and applies to applications submitted after enactment.
  • General permit terms. Extends the maximum term of Corps general and nationwide permits from 5 years to 10 years.
  • Scope of Corps review. For general permits, the Corps may consider only effects on water quality requirements. Any discharge into less than 2 acres of waters must be treated as a “minimal adverse environmental effect.”
  • Linear infrastructure. The Corps “shall maintain” Nationwide Permits 12 (oil and gas pipelines), 14 (linear transportation), 43 (stormwater), 57 (electric utility lines), and 58 (utility lines for water and other substances), as reissued in the Corps’ January 8, 2026 final rule. Coverage extends to discharges into less than 2 acres per single and complete linear or non-linear project. The Corps keeps authority to issue regional general permits and individual permits for linear projects.
  • Nationwide permit reissuance. Reissuing a nationwide permit requires no ESA Section 7 consultation and no NHPA Section 106 consultation, and NEPA is satisfied by a programmatic EA. These shortcuts apply only if preconstruction notification requirements are not narrowed or eliminated and notification thresholds are not raised.
  • Compensatory mitigation is not addressed.

Sec. 1205. Judicial Review Timeline Clarity (Page 128)

  • Sets a 150-day statute of limitations for challenges to EPA approval of State 404 programs, individual and general 404 permits, and Corps verifications under a general permit.
  • Challenges to State 404 program approvals and to permits require that the plaintiff filed a detailed comment during the comment period. Challenges to verifications do not.
  • The court must remand, and may not vacate or enjoin a permit unless there is an “imminent and substantial danger to human health or the environment.” Remand deadlines may not exceed 180 days.

Title III – Endangered Species Act

Sec. 1301. Definitions (Page 133)

  • Defines “best scientific and commercial data available” as information available at the time of the agency action, “impartially gathered and objectively applied.”

Sec. 1302. Timeline for Section 7 Consultations (Page 134)

  • Shortens formal consultation from 90 days to 60 days. Unilateral extensions are capped at 100 days. Applicants may sue for agency action “unlawfully withheld” after 145 days.
  • Consultation must be completed by the NEPA deadline for the project’s environmental document.

Sec. 1303. Projects in the Operational Right-of-Way (Page 136)

  • Exempts transportation projects in an existing operational right-of-way from Section 7 consultation.

Sec. 1304. State Assumption of Consultation Responsibilities (Page 137)

  • Allows Interior to delegate Section 7 consultation to qualified States. Multi-State projects are excluded. The Secretary must act on a State application within 180 days, and agreements run up to 10 years.

Sec. 1305. Judicial Review (Page 154)

  • Allows challenges to biological opinions in the D.C. Circuit, filed within 150 days after the opinion is made public.

Secs. 1306–1308. Listing Determinations; Appropriations; Coastal State Fund (Page 155)

  • Requires integration of State-collected data in listing decisions. Authorizes $150 million per year for Section 7 implementation and $50 million per year for a new National Fish and Wildlife Foundation Coastal State Fund.

Title IV – Project Certainty

Sec. 1401. Maintaining Federal Authorizations or Permits for Projects with Non-Federal Sponsors (Page 158)

  • Bars agencies from revoking, suspending, withdrawing, or altering any Federal authorization in effect on or after September 16, 2026, and from otherwise interfering with a fully permitted project. “Authorization” is defined broadly and includes Corps verifications, biological opinions, and rights-of-way.
  • The only exceptions are a court order; a material violation by the permit holder; fraud; “specific, urgent, substantial, and proximate harm” based on new information; or the holder’s own request.
  • The agency bears the burden of proof by clear and convincing evidence in the district court where the project is located.
  • Remedies include reinstatement of the authorization, an injunction, fees, and delay costs, plus an additional award of 25–50 percent of project costs incurred to date. Awards are paid from the Judgment Fund.

Sec. 1402. Ensuring Fairness for Specific Types of Covered Projects (Page 166)

  • Creates a cause of action where a “pattern of disparate treatment” against a project type causes improper denial, or delay of more than 60 days past a deadline.
  • Covered project types include onshore and offshore transmission and natural gas, oil, hydrogen, CO2, natural gas liquids, ammonia, produced water, and helium pipelines, along with oil and gas production, LNG, refining, and every major generation type. Data centers are not listed.
  • Sets a 1-year decision deadline for covered projects that do not require an EA or EIS.
  • Remedies include an injunction and damages of 50–100 percent of expected construction costs. Class actions are barred.

Sec. 1403. Avoiding Unreasonable Delays in Permitting (Page 182)

  • Allows applicants to sue in district court to enforce the 1-year deadline. The court must rule within 120 days.

DIVISION B – COMMITTEE ON ENERGY AND NATURAL RESOURCES

Title I – Electric Transmission

Sec. 2101. Transmission Permitting (Page 185)

  • Repeals DOE’s National Interest Electric Transmission Corridor designation process. FERC “shall” issue backstop siting permits for lines of 230 kV or more, or lower voltage for advanced conductors, when States fail to act, deny, or lack authority.
  • The State clock now runs from the date of the State filing. For lines of 345 kV or more, a FERC proceeding may run at the same time as the State proceeding.
  • Eminent domain proceedings follow Federal Rule of Civil Procedure 71.1. FERC becomes lead agency for Federal authorizations. Section 401 certifications count as Federal authorizations, and challenges go directly to the courts of appeals.
  • Cost allocation. Costs must be allocated “at least roughly commensurate” with six listed benefits. Customers receiving no benefit, or only “trivial” benefits, cannot be involuntarily charged.
  • ERCOT is excluded. Public power is covered.

Sec. 2102. Reconductoring and Other Activities in Existing Rights-of-Way (Page 200)

  • Transmission (new FPA Sec. 216A). Work that maintains or increases grid capacity within an existing right-of-way is categorically excluded. It is not a NEPA “major Federal action” or an NHPA Section 106 “undertaking.” This covers reconductoring, voltage increases, advanced transmission technologies, parallel circuits, and storage at or near the facility. There is no voltage floor, so distribution is included.
  • Natural gas pipelines (new NGA Sec. 7(i)). Repair, replacement, upgrade, looping, compression, and capacity-enhancement work on existing interstate natural gas pipelines and associated facilities is exempt from NEPA and Section 106, provided it stays within the existing right-of-way or previously reviewed construction footprint. Associated facilities include compressor, meter, and regulator stations and storage facilities. The Clean Water Act and Clean Air Act still apply.

Sec. 2103. Transmission Planning (Page 205)

  • DOE must study transmission congestion every 3 years.
  • FERC must issue a rule within 180 days requiring regional and joint interregional transmission planning. Plans must be filed within 2 years and updated every 4 years. Compliance with Order No. 1920 satisfies the regional requirements.
  • A project selected in a regional or interregional plan is deemed to meet the Sec. 216 permit findings.

Sec. 2104. Improvements Relating to Local Transmission Planning and Development (Page 218)

  • States may refer utilities to FERC for investigation of local and supplemental transmission projects. Remedies include a reduced return on equity, loss of the prudence presumption, and fines of up to $5 million per facility, paid to the referring State.

Sec. 2105. Prohibition of Right of First Refusal (Page 224)

  • Prohibits a Federal right of first refusal for facilities selected in a regional or interregional plan. State ROFR laws are not addressed.

Sec. 2106. Consolidated Planning Process (Page 224)

  • Requires joint 20-year planning of transmission and generation. Regions must publish interconnection locations with “upfront, fixed, zonal, per-megawatt” costs and use cluster studies with nonrefundable security.

Sec. 2107. Ratepayer Protection (Page 226)

  • Data center transmission pricing. Within 270 days, FERC must revise its 1994 transmission pricing policy so that computational load sites (data centers, AI, and crypto mining) pay both embedded and incremental transmission costs, with a lower rate for non-firm service. A proposed rule and final rule follow.
  • New FPA Sec. 228 (Ratepayer Protection for Data Center and High-Density Computing Load). Applies to loads of 20 MW or more at one site, or at multiple sites under common ownership, including phased projects expected to reach 20 MW.
    • No incremental generation, transmission, distribution, or storage cost may be shifted to other customers. Cost recovery continues even if the data center exits its contract.
    • Utilities must require upfront financial assurance before building facilities to serve the load.
    • States may allocate service through open seasons or competitive solicitations rather than first-come, first-served; require data centers to “bring their own generation”; require non-firm service; and place data centers in a separate class with less favorable rates and interconnection priority.
    • Applies to loads that interconnect on or after enactment. Existing arrangements are grandfathered.

Sec. 2108. Dispatchable Energy Systems Market Access (Page 240)

  • Opens RTO energy, capacity, and ancillary services markets to aggregations of behind-the-meter resources of 100 kW or more within 18 months, and prohibits double compensation. Creates a $20 million per year DOE local permitting program for distributed energy.

Sec. 2109. Advanced Transmission Technologies (Page 260)

  • FERC must require public utilities to deploy advanced transmission technologies, including best-available conductors, wherever the benefit-cost ratio exceeds 1. Deployment is presumed prudent, and failure to deploy carries return-on-equity penalties.

Sec. 2110. Expediting Generator Interconnection Queues (Page 265)

  • Requires a rulemaking within 1 year to use AI and automation in large generator interconnection studies.

Sec. 2111. Grid Data Access (Page 266)

  • Requires grid users to provide data for generation and load interconnection studies within 15 days. Confidentiality rules cannot be used to withhold data. Relevant to data center interconnection timelines.

Secs. 2112–2113. Power Marketing Administrations; FERC Fee Assessments (Page 272)

  • Grants Power Marketing Administrations new pay authority and requires FERC to review its fees every 5 years.

Sec. 2114. Collection of Data on Computational Load Entities (Page 279)

  • Requires EIA to add data center load to Form EIA-861.

Sec. 2115. Conforming Amendments; Savings Provision (Page 280)

  • Clarifies that nothing in the title gives FERC authority over retail sales or local distribution.

Title II – Energy Permitting

Subtitle A – Accelerating Claims (Page 280)

Sec. 2201. Accelerating Claims (Page 280)

  • Sets a 150-day statute of limitations for challenges to any authorization for an energy, mineral, CO2, or wildfire project that requires an EA or EIS. Covers Mineral Leasing Act and OCSLA lease sales, rights-of-way, and ESA permits.
  • Agencies must publish final decisions within 3 days. Courts must expedite review and set remand deadlines of no more than 180 days. A supplemental document restarts the clock.

Subtitle B – Federal Onshore Energy Leasing and Permitting (Page 286)

Sec. 2211. Permitting Compliance on Non-Federal Land (Page 286)

  • Oil and gas. No Federal permit to drill is required for wells on non-Federal land where the United States owns less than 50 percent of the minerals in the spacing unit, or where the wellbore only enters or crosses Federal minerals. The State permit governs. Lessees must give Interior 5-day and 45-day notices, and royalties are unaffected.
  • Bars Interior from requiring bonds, mitigation, or reclamation approval on those non-Federal lands. Tribal lands are excluded.

Sec. 2212. Rights-of-Way Across Indian Land (Page 290)

  • Linear infrastructure. Tribes may grant rights-of-way “for any purpose,” including pipelines and transmission, without BIA approval under Secretary-approved tribal regulations. Approval of those regulations is exempt from NEPA, NHPA Section 106, and the ESA, and must occur within 180 days.

Sec. 2213. Accelerating Renewable Energy Permitting (Page 298)

  • Sets 30-day and 90-day deadlines for renewable right-of-way applications on BLM and Forest Service land, and requires new categorical exclusions within 180 days. Energy storage is added.

Sec. 2214. Electric Grid Projects (Page 304)

  • Interior and Agriculture must adopt categorical exclusions within 180 days for transmission and distribution lines in approved corridors, including EPAct Sec. 368 corridors; for reconductoring, grid-enhancing technologies, and substation work in existing rights-of-way; and for storage on disturbed land.

Sec. 2215. Hardrock Mining Mill Sites (Page 306)

  • Allows as many mill sites, up to 5 acres each, as are reasonably necessary, with a $400 annual fee. Extends acquired-lands leasing to hardrock minerals.

Subtitle C – Geothermal Leasing and Permitting (Page 318)

Secs. 2221–2228. Geothermal Provisions (Page 318)

  • Creates a categorical exclusion for geothermal observation test wells; moves to annual lease sales; sets 30-day permit deadlines; creates an ombudsman and task force; waives Federal permits where the Federal subsurface share is below 50 percent; and provides cost recovery and an updated “Gold Book.”

Sec. 2229. NEPA Review (Page 349)

  • Oil and gas. Amends EPAct 2005 Sec. 390 so that listed onshore oil, gas, and geothermal activities “shall not be considered a major Federal action” under NEPA.
  • Extends the window for placing a pipeline in a previously approved right-of-way corridor from 5 years to 10 years, and adds geothermal transmission lines of up to 20 miles.

Subtitles D–E – Hydropower; Hiring and Retention (Page 351)

Secs. 2231–2243. Hydropower and FERC Staffing (Page 351)

  • Requires a FERC report on hydropower market barriers and limits federal agency license conditions to those “reasonably related” to project effects. Allows routine hydropower maintenance without prior approval, creates a licensing path for micro-hydrokinetic projects of 5 MW or less, and expands FERC hiring authority.

Subtitle F – Offshore Energy (Page 363)

Sec. 2251. Offshore Energy (Page 363)

  • Allows electric transmission rights-of-way through National Marine Sanctuaries and loosens the “interference with other uses” standard under OCSLA Sec. 8(p). Does not address offshore oil and gas lease sales.

Sec. 2252. Offshore Energy Transmission (Page 365)

  • Interior and DOE must designate preferred offshore cable routes within 2 years. Interior is lead agency for offshore transmission, and a final right-of-way rule is due within 2 years.

Title III – Historic Preservation

Sec. 2301. Historic Preservation (Page 372)

  • Linear infrastructure. Narrows NHPA Section 106:
    • “Undertakings” exclude project portions without substantial Federal control and projects whose only Federal involvement is financial assistance.
    • Visual, atmospheric, and audible effects are generally not adverse effects.
    • Agencies may issue phased determinations for projects crossing “multiple corridors or large land areas.”
    • Properties listed after review begins do not reopen the review.
  • Sets fixed consultation timelines, from a 30-day undertaking determination through a final determination, tied to NEPA deadlines. Parties that do not respond within 30 days may be bypassed.
  • Judicial review. Claims must be filed within 150 days and go directly to the courts of appeals. Plaintiffs must allege “direct harm” and have filed a comment. The only remedy is remand without vacatur.

Sec. 2302. Historic Preservation Fund (Page 414)

  • Authorizes $200 million per year for FY2027–2036 and $20 million per year in grants to Tribal Historic Preservation Officers for records databases.

Risk-Based Tank Inspections

The draft does not address risk-based inspections of storage tanks, the Spill Prevention, Control, and Countermeasure (SPCC) rule, or PHMSA pipeline safety programs. The only inspection provisions concern geothermal operations (Secs. 2225 and 2227) and distributed energy permitting (Sec. 2108). We will monitor for this issue in any manager’s amendment or House companion.

WHAT WE ARE WATCHING

Constitution Partners will continue to monitor the Bipartisan American Affordability and Jobs Act of 2026 — including markup scheduling, amendments, and negotiations among the Senate, the House, and the Administration — and will provide updates as developments warrant. Clients with questions about how specific provisions affect their operations are encouraged to contact any member of our team.