Geoscience and Policy Intersections

EU Tightens Water Rules to Hit Zero‑Pollution Goal

Overview

The European Parliament and Council have adopted Directive 2026/805, amending the core EU water‑policy framework (Directives 2000/60/EC, 2006/118/EC and 2008/105/EC). The aim is to bring the Union closer to its “zero‑pollution” ambition by tightening environmental quality standards, expanding the list of priority substances, and improving monitoring and cross‑border cooperation. The directive builds on recent scientific assessments that show many water bodies still fail to reach good status, and it aligns water protection with the Green Deal, the Chemicals Strategy and the Water Resilience Strategy.

The amendment introduces a 15‑year deadline for all surface‑water bodies and groundwater to achieve and maintain good chemical status, with specific obligations for heavily modified or artificial waters. It also adds new thresholds for per‑ and poly‑fluoroalkyl substances (PFAS), pharmaceuticals, bisphenols and other emerging contaminants, and requires Member States to adopt source‑control measures and to review permits and authorisations more rigorously. Monitoring will be expanded to include effect‑based methods for estrogenic substances and a new “watch list” of up to five substances that pose a significant but insufficiently monitored risk.

For stakeholders in geoscience, energy, mining, agriculture and trade, the directive means tighter regulation of chemicals that can be released during extraction, processing or use, and a stronger emphasis on data sharing and transparency. The European Commission will have new delegated‑act powers to keep standards up to date, and Member States will be required to publish detailed monitoring maps and river‑basin management plans that integrate the new rules.

Key Elements

• 15‑year good status target for all surface‑water bodies and groundwater, with special provisions for artificial and heavily modified waters.
  
• Expanded priority‑substance list including PFAS, pharmaceuticals, bisphenols, micro‑plastics and antimicrobial‑resistance indicators.
  
• New PFAS and other emerging‑contaminant thresholds (e.g., total PFAS, four most problematic PFAS, sum of selected pharmaceuticals).
  
• Enhanced monitoring and reporting: annual or bi‑annual sampling, effect‑based monitoring for estrogenic substances, and mandatory publication of validated data every 2–3 years.
  
• Cross‑border cooperation: rapid information sharing on extreme weather events and pollution incidents, and a streamlined emergency response mechanism.
  
• Source‑control focus: Member States must prioritise measures that reduce pollutant inputs at the source, review permits, and phase out priority hazardous substances within 20 years.
  
• Commission delegated‑act powers: ability to update Annexes, EQS, and threshold values without full legislative procedures.
  
• Access to justice: NGOs and citizens can challenge decisions affecting water bodies through fair, timely, and affordable judicial or administrative review.
  
• Watch list of emerging contaminants: up to five substances or indicators to be monitored at a minimum of two representative sites, with periodic review every three years.
  
• Integration with other EU policies: alignment with the Green Deal, Chemicals Strategy, Water Resilience Strategy, and the Industrial Emissions Portal for transparent reporting.

Alaska’s Arctic Coast Set for Massive Oil & Gas Lease Sale: 400,000+ Acres Up for Bid

Overview

The U.S. Bureau of Land Management (BLM) Alaska State Office has announced a lease sale for tracts in the Coastal Plain of the Arctic National Wildlife Refuge (ANWR). The sale will open on June 5, 2026, with sealed bids required by June 3, 2026. The announcement follows the 2025 Record of Decision (ROD) that earmarked this area for potential oil and gas development and is part of a broader federal effort to meet the requirements of Executive Order 14153, Secretary’s Order 3422, and several public laws that mandate large lease sales in the region.

The sale covers no less than 400,000 acres, making it one of the largest lease opportunities in Alaska’s Arctic. It is intended to advance federal priorities for energy development while also providing a transparent, competitive process for companies interested in exploring and potentially extracting hydrocarbons from the Coastal Plain. The BLM will livestream the bid opening, ensuring public access to the proceedings.

For stakeholders—including geoscientists, energy companies, and environmental groups—this sale represents a critical juncture. It will shape the future of Arctic resource extraction, influence regional economic prospects, and raise questions about environmental stewardship and the protection of wildlife habitats within ANWR.

Key Elements

• Sale Dates

  • Sealed bids due: June 3, 2026, 4 p.m. AKDT
    
  • Bid opening: June 5, 2026, 10 a.m. AKDT (livestreamed online)

• Location & Acreage

  • Tracts in the Coastal Plain of the Arctic National Wildlife Refuge
    
  • Minimum of 400,000 acres available for leasing

• Legal Framework

  • Implements the 2025 Record of Decision for the Coastal Plain
    
  • Meets requirements of Executive Order 14153, Secretary’s Order 3422,
    Public Law 115‑97 (Tax Cuts and Jobs Act), Public Law 119‑21 (One Big Beautiful Bill Act), and P.L. 119‑52
    
  • Section 50104 of Public Law 119‑21 mandates four lease sales of at least 400,000 acres each over ten years, with the first sale no later than July 4, 2026

• Bid Submission

  • Bids must be sealed and submitted to the BLM Alaska State Office, Attn: Wayne Svejnoha, 222 West 7th Ave., #13, Anchorage, AK 99513‑7504
    
  • Detailed Statement of Sale (including terms, conditions, and operating procedures) available immediately after publication on the BLM Alaska website

• Public Access & Transparency

  • Bid opening will be available via video livestream
    
  • The United States reserves the right to withdraw any tract before acceptance of a bid

• Contact Information

  • Wayne Svejnoha, Acting Deputy State Director Resources
    
  • Phone: 907‑271‑4407 | Email: (not provided)
    
  • TTY/Relay services available for individuals with hearing or speech disabilities

These provisions outline the procedural, legal, and logistical framework governing the 2026 Coastal Plain oil and gas lease sale, setting the stage for a significant development opportunity in Alaska’s Arctic region.

Kankakee River Hydro Project Opens the Floodgates for Public Input and Study Requests

The City of Kankakee, Illinois has filed a hydroelectric application with the Federal Energy Regulatory Commission (FERC) for a run‑of‑river project on the Kankakee River. The proposed facility will include a 300‑acre reservoir, a 440‑foot concrete dam topped by an inflatable rubber dam, and a powerhouse with three 400‑kW turbines, totaling 1.2 MW of installed capacity and an estimated annual generation of 1,124 MWh. The application is a subsequent minor license (Project No. 8632‑023) and is currently not ready for environmental analysis.

FERC is inviting federal, state, local, and tribal agencies with environmental expertise to request additional scientific studies or to cooperate in preparing the environmental documentation. Requests must be filed within 60 days of the application’s filing date (by June 2, 2026) and can be submitted electronically via FERC’s eFiling system. Agencies that cooperate in the study preparation are prohibited from intervening in the proceeding, in accordance with FERC policy.

The notice outlines a preliminary schedule for the licensing process: a deficiency letter in July 2026, acceptance and scoping notices in October 2026, scoping comments due in November 2026, and a ready‑for‑environmental‑analysis notice in December 2026. Final amendments to the application must be filed within 30 days of that notice. Interested parties can view all documents online through FERC’s eLibrary or contact the Office of Public Participation for assistance.

Key Elements

• Project scope: 1.2 MW run‑of‑river hydroelectric facility on the Kankkee River, 300‑acre reservoir, 440‑ft concrete dam, 3 turbines.
• Environmental status: Application not yet ready for environmental analysis; additional studies may be requested.
• Study request deadline: June 2, 2026 (60 days from filing).
• Cooperating agency rule: Agencies that assist in study preparation cannot intervene in the proceeding.
• Procedural schedule:
  • July 2026 – Deficiency letter
  • October 2026 – Acceptance letter & scoping notice
  • November 2026 – Scoping comments due
  • December 2026 – Ready for environmental analysis notice
• Final amendment deadline: 30 days after the ready‑for‑analysis notice.
• Filing methods: Electronic filing via eFiling; paper filings accepted at FERC, Washington, DC or Rockville, MD.
• Contact information: Zachary Newton, City of Kankakee Environmental Services Utility; Laura Washington, FERC Office of Public Participation.

Coast Guard Declares Temporary Flood‑Risk Safety Zone on Michigan’s Cheboygan and Black Rivers

Overview
The U.S. Coast Guard has issued a temporary safety zone covering the Cheboygan River from the Lock and Dam Complex to its outlet at Mullett Lake, and the Black River from its confluence with the Cheboygan River to Alverno Dam. The zone is in place from April 15 to April 24, 2026, to protect vessels, personnel, and the marine environment from hazardous flood waters that have been reported in the area. Entry into the zone is prohibited unless expressly authorized by the Captain of the Port (COTP) for the Northern Great Lakes sector or a designated representative.

The rule was enacted without prior notice and comment because the flood threat was identified on April 14, 2026, leaving insufficient time for a traditional rule‑making process. The Coast Guard therefore exercised its authority under 5 U.S.C. 553(b)(B) and (d)(3) to issue an emergency regulation effective immediately. The regulation is categorized as having no significant environmental impact and does not impose any new federal mandates or costs on state, local, or tribal governments.

Key Elements

• Zone boundaries:
  
  • Cheboygan River: from the Lock and Dam Complex (45°38′09.8″ N, 084°28′47.3″ W) to the outlet of Mullett Lake (45°34′34.1″ N, 084°29′18.0″ W).
    
  • Black River: from its confluence with the Cheboygan River (45°36′15.3″ N, 084°27′52.3″ W) to Alverno Dam (45°33′06.6″ N, 084°23′42.5″ W).
    
• Effective dates: April 15–24, 2026 (enforcement begins April 15; rule published April 20).
  
• Enforcement authority: Coast Guard Patrol Commander or designated COTP officer; all vessels and persons must comply with orders.
  
• Entry restrictions: No entry allowed unless authorized by the COTP or their representative; permission can be requested via VHF‑FM channel 16 or by phone (906‑635‑3237).
  
• Regulatory context: Rule falls under 33 CFR Part 165; no new paperwork or environmental review required.
  
• No impact on small entities: The rule does not trigger the Regulatory Flexibility Act or impose unfunded mandates.
  
• Contact for information: Lt. Rebecca Simpson, Sector Northern Great Lakes Waterways Management Division, U.S. Coast Guard.

Rural Housing Service Tightens Insurance Rules to Shield Affordable Homes from Storms and Losses

Overview

The Rural Housing Service (RHS) has issued a final rule that modernizes the insurance requirements for its Multi‑Family Housing (MFH) Direct Loan and Grant programs. Effective May 20, 2026, the rule updates coverage amounts, deductible limits, and policy types to match current affordable‑housing industry standards. The goal is to reduce insurance premiums, simplify compliance for borrowers, and ensure that properties are adequately protected against natural hazards such as floods, windstorms, and earthquakes.

The rule aligns RHS’s insurance mandates with those used by other federal agencies (HUD, Freddie Mac) and private developers. By allowing higher deductibles and clearer coverage thresholds, the agency expects lower costs for borrowers while maintaining sufficient protection for the federal loan portfolio. The changes also introduce new mandatory coverages—worker’s compensation, business‑income loss, and fidelity bonds—alongside existing property, liability, and flood insurance.

Overall, the updated regulations aim to strengthen the resilience of rural affordable‑housing stock, protect tenants and communities from catastrophic losses, and improve the customer experience for developers and owners who rely on RHS financing.

Key Elements

• Coverage amounts updated to current dollar values and aligned with industry standards (e.g., 80 % of insurable replacement cost for property insurance).
  
• Higher deductible limits: up to $50 k for projects over $2 M, reducing premiums while still limiting loss exposure.
  
• Mandatory windstorm coverage added to hazard insurance, with a deductible capped at 5 % of the insured value.
  
• Business‑income loss insurance required after construction completion to protect rental income during damage events.
  
• Worker’s compensation insurance now mandatory for any permanent or part‑time staff on the project.
  
• Fidelity bond requirements revised to a minimum of 25 % of operational cash or $50 k, whichever is greater, with a $15 k deductible cap.
  
• Flood insurance remains required, with coverage not less than 80 % of the insurable replacement value or the maximum available under the National Flood Insurance Act.
  
• Earthquake coverage now includes a deductible limit of no more than 20 % of the coverage amount.
  
• Policy cancellation and modification rules: at least 30 days’ notice to RHS, non‑contributory mortgage clause, and loss‑payee naming.
  
• Insurance settlement handling clarified: proceeds may be deposited in the project’s operating account or applied to RHS debt if the property is a total loss and tenants have been relocated.
  
• Removal of reference to 7 CFR part 1806 (National Flood Insurance) from the general insurance requirement, consolidating flood coverage under § 3560.105.
  

These provisions collectively modernize RHS’s insurance framework, making it more cost‑effective, transparent, and aligned with the realities of today’s housing market and climate risks.

Congress Rejects BLM’s Plan to Withdraw Federal Lands in Minnesota

Overview

In a joint resolution presented to the President, Congress has formally disapproved a rule issued by the Bureau of Land Management (BLM) that would have withdrawn federal lands in Cook, Lake, and Saint Louis counties in Minnesota. The rule, published in the Federal Register on January 31, 2023, sought to transfer ownership of these lands from federal to state or local control, thereby ending federal stewardship and potentially opening the area for development or other uses.

The resolution, enacted under Chapter 8 of Title 5 of the U.S. Code, declares that the BLM rule has no force or effect. By doing so, Congress preserves federal ownership of the lands and maintains the protections and management framework that have governed the area for decades. The decision reflects concerns about the environmental, economic, and community impacts that could arise from relinquishing federal oversight.

This action underscores the role of Congress in reviewing and, when necessary, overturning agency decisions that affect public lands. It also signals a broader debate over land use, conservation, and the balance between federal and local control in the United States.

Key Elements

• Disapproval under Chapter 8, Title 5 – The resolution formally rejects the BLM rule, removing its legal authority.
  
• Targeted Lands – The rule concerned federal lands in Cook, Lake, and Saint Louis counties, Minnesota.
  
• No Effect Clause – The rule is declared to have no force or effect, preserving current federal ownership and management.
  
• Joint Resolution – Both the Senate and House approved the measure, and it was presented to the President for signature.
  
• Implications for Land Management – The decision maintains federal stewardship, potentially safeguarding environmental protections and public access.
  
• Policy Context – Reflects congressional oversight of agency actions that alter land ownership and use.

Assessing Missouri River Water Supply for Western South Dakota: A Feasibility Study Act

Overview

The Western South Dakota Water Supply Project Feasibility Study Act directs the U.S. Secretary of the Interior to evaluate whether a new water supply system can deliver municipal, rural, and industrial water from the Missouri River to the Western Dakota Regional Water System. The study will examine engineering, environmental, and financial aspects, culminating in a public report that recommends whether construction should proceed and how costs should be shared between the federal government and the non‑federal project entity.

The Act establishes a structured partnership between federal and local stakeholders. The Secretary must coordinate with the nonprofit Western Dakota Regional Water System, as well as with state, tribal, regional, and local authorities, ensuring that the study reflects a broad range of interests and complies with reclamation feasibility standards. The resulting feasibility report will be submitted to congressional committees and made publicly available, promoting transparency and informed decision‑making.

If the study concludes that the project is viable, the Act requires the Secretary to recommend a non‑federal share of at least 25 % of construction costs, based on the entity’s financial capacity to pay for construction, operations, maintenance, and replacement. Federal funding for the study itself is capped at 50 % of total costs, with a $10 million appropriation authorized for the project. The authority to conduct the study expires ten years after enactment, providing a clear timeline for completion and potential action.

Key Elements

• Federal Lead: Secretary of the Interior conducts a comprehensive feasibility study in partnership with the Western Dakota Regional Water System, Inc.
  
• Stakeholder Collaboration: Consultation with federal, state, tribal, regional, and local agencies to ensure inclusive planning and compliance with environmental standards.
  
• Feasibility Report: Includes recommendations on project authorization and a detailed cost‑sharing plan, with the non‑federal entity responsible for at least 25 % of construction costs.
  
• Cost‑Sharing for Study: Federal share of study costs limited to 50 % of total expenses; a $10 million appropriation authorized for the study.
  
• Public Transparency: Study findings and feasibility report made publicly available to inform communities and stakeholders.
  
• Time‑Bound Authority: The study authority expires ten years after the Act’s enactment, setting a clear deadline for decision‑making.
  
• Geoscience and Resource Focus: The project addresses water resource management, hydrological engineering, and sustainable supply for municipal, rural, and industrial users in Western South Dakota.

Reconciliation Bill Rewrites Energy, Natural‑Resource, and Environmental Policy

Overview

The 2025 reconciliation act, enacted as Public Law 119‑21, reorganizes federal priorities across 17 titles, with the most consequential changes for geoscience, energy, and natural resources concentrated in Title V – Committee on Energy and Natural Resources. The bill expands on‑shore and off‑shore oil and gas leasing, sets new methane royalty rates, and authorizes additional Alaska‑specific leases, while also permitting federal coal leasing and establishing a framework for renewable‑energy fees and revenue sharing on federal lands. At the same time, the act rescinds funding for the National Oceanic and Atmospheric Administration and cuts a broad array of environmental and climate‑justice programs, reshaping the federal landscape for resource extraction, renewable development, and environmental stewardship.

The legislation also introduces sweeping tax‑code amendments that affect energy and mineral projects, including new rules for renewable‑energy fees, wind‑right‑of‑way reductions, and a revised framework for federal leasing and royalty collection. Additional provisions address water infrastructure, disaster assistance, and agricultural commodity payments, but the core focus remains on how the federal government manages and finances natural‑resource extraction and renewable‑energy development.

Overall, the act signals a shift toward a more market‑driven approach to resource development, with increased federal leasing authority and reduced environmental oversight, while also tightening tax incentives for energy projects and expanding state‑level revenue sharing on federal lands.

Key Elements

• Oil & Gas Leasing – Authorizes new on‑shore and off‑shore leases, sets methane royalty rates, and expands Alaska‑specific leasing (including the National Petroleum Reserve‑Alaska).
  
• Coal Leasing – Permits federal coal leasing, caps royalty rates, and allows mining of federal coal adjacent to state or private reserves.
  
• Renewable‑Energy Fees – Establishes a renewable‑energy fee framework on federal lands, including acreage rents and capacity fees, with provisions for wind‑right‑of‑way fee reductions.
  
• NOAA Rescission & Climate Cuts – Rescinds NOAA funding and reduces a wide range of environmental and climate‑justice programs, shifting federal focus away from climate research and mitigation.
  
• Tax Incentives & Credits – Revises tax code provisions for energy projects, including new rules for renewable‑energy fees, wind‑right‑of‑way fee policy, and tax‑credit eligibility for clean‑energy and advanced‑manufacturing projects.
  
• Water & Infrastructure – Provides funding for water infrastructure under Subtitle E and outlines new water‑related appropriations.
  
• Agricultural & Disaster Support – Adjusts agricultural commodity payments, disaster assistance, and dairy margin coverage, with extended coverage periods and increased funding for surveys.
  
• Energy‑Related Appropriations – Allocates billions for defense and energy‑related programs, including advanced weapons, critical‑minerals stockpiles, and renewable‑energy infrastructure.
  
• Environmental & Land‑Use Provisions – Introduces new regulations for federal timber sales, renewable‑energy right‑of‑way fees, and land‑use changes on federal lands.
  
• Administrative & Compliance – Sets new reporting requirements for renewable‑energy projects, tax‑credit claims, and environmental compliance, with penalties for non‑compliance.

Keeping Public Lands in Public Hands: A New Bill Protects Accessible Federal Tracts

Overview
The Public Lands in Public Hands Act (H.R. 718) seeks to prevent the Secretary of the Interior and the Secretary of Agriculture from transferring ownership of certain federally managed lands to non‑federal entities. By defining a “publicly accessible tract” as any federal land reachable via public roads, trails, waterways, easements, or rights‑of‑way, the bill aims to preserve public access and prevent fragmentation of these lands.

The legislation establishes a broad prohibition on transferring title to lands that are either publicly accessible themselves or contiguous with publicly accessible or locally owned lands that are also publicly accessible. It includes a detailed list of statutory exceptions—such as small‑tract exchanges, specific historic acts, and authorized land‑exchange programs—ensuring that routine, low‑impact transfers can still occur under existing law.

For geoscientists, energy developers, and natural‑resource professionals, the bill means that large tracts of land that are currently open to the public will remain under federal stewardship, limiting opportunities for private acquisition and potentially affecting future resource‑development projects. The act also clarifies that subdivision of federal land to meet minimum acreage thresholds is prohibited, reinforcing the integrity of public lands.

Key Elements

• Prohibition on Transfer: The Interior and Agriculture Secretaries cannot transfer title to federally managed lands that are publicly accessible or contiguous with publicly accessible or locally owned lands that are publicly accessible.
  
• Definition of Publicly Accessible Tract: Includes any federal land reachable by public road, trail, waterway, easement, or right‑of‑way.
  
• Exceptions:
  
  • Lands under 300 acres or under 5 acres accessible via a public waterway.
    
  • Lands authorized under the Federal Land Policy and Management Act of 1976.
    
  • Lands covered by specific historic statutes (e.g., Southern Nevada Public Land Management Act, Sisk Act, Townsites Act, Small Tract Act, Native Allotment Act, Alaska Native Claims Settlement Act, etc.).
    
  • Lands explicitly authorized by federal law or acquired through a federally authorized land exchange.
    
• Subdivision Limitation: The Secretary cannot subdivide federal land to meet the acreage minimums required for the exceptions.
  
• Statutory Construction Clause: The act does not affect the legality of stepping over a property corner from one parcel of public land to another.
  

These provisions collectively aim to safeguard public access to federal lands while allowing for limited, legally sanctioned transfers that serve broader public or conservation interests.

Tax Breaks for Defense‑Led Environmental Projects: The REPI Sales Act

Overview

The Incentivizing Readiness and Environmental Protection Integration Sales Act of 2025 (H.R. 1083) seeks to encourage the transfer of real property to organizations that support the Department of Defense’s Readiness and Environmental Protection Integration (REPI) program. By amending the Internal Revenue Code, the bill removes the gain from the sale of qualified real‑property interests from taxable income, providing a clear fiscal incentive for entities to participate in REPI‑related projects.

The legislation defines a qualified real‑property interest broadly—encompassing entire interests, remainder interests, and perpetual restrictions—while ensuring that mineral rights do not automatically disqualify a property unless surface mining is required. It also clarifies that the sale must be to a qualified organization under the tax code and that the transaction must be authorized by the REPI program under Title 10, U.S. Code.

Key provisions limit the exclusion for pass‑through entities that acquire the property within three years of the sale, with a carve‑out for family partnerships and S‑corporations. The act takes effect for taxable years beginning after enactment, and it is currently referred to the House Committee on Ways and Means for further consideration.

Key Elements

• Tax Exclusion: Gain from the sale of qualified real‑property interests used for REPI purposes is excluded from gross income.
  
• Qualified Real‑Property Interest: Includes entire interests, remainder interests, and perpetual use restrictions; mineral interests are allowed unless surface mining is required.
  
• Qualified Organization: Must meet the definition in §170(h)(3) of the Internal Revenue Code.
  
• REPI Purpose: Sale must be authorized under the Department of Defense’s REPI program (section 2684a, Title 10).
  
• Pass‑Through Entity Limitation: No exclusion if the property was acquired by a pass‑through entity within three years of the sale, except for family partnerships or S‑corporations.
  
• Family Partnership Exception: Applies to partnerships where all interests are held by an individual and their family members.
  
• Effective Date: Applies to taxable years beginning after the act’s enactment.
  
• Legislative Status: Referred to the House Committee on Ways and Means for further review.

EU Puts €21.5 M on Standby to Rescue Farmers in Bulgaria, Estonia, Hungary from Climate‑Induced Crop Losses

Overview
The European Commission has adopted Regulation (EU) 2026/847 to provide emergency financial support to farmers in Bulgaria, Estonia and Hungary who suffered severe crop losses during the 2025 growing season due to extreme weather events. The measure, grounded in Article 221 of Regulation (EU) 1308/2013, allocates a total of €21.5 million—€7.4 million for Bulgaria, €3.3 million for Estonia and €10.8 million for Hungary—to compensate for the economic damage caused by droughts, heatwaves, frosts and excessive rainfall.

The regulation sets strict eligibility and payment deadlines: all Union‑funded aid must be disbursed by 30 September 2026, and any payments made after that date are ineligible. Member States may combine this aid with other EU instruments (European Agricultural Guarantee Fund and European Agricultural Fund for Rural Development) and may provide additional national support up to 200 % of the EU amount, provided it does not distort markets or over‑compensate farmers. Detailed reporting on criteria, distribution, and effectiveness is required by 31 March 2027.

The regulation enters into force immediately after publication in the Official Journal, ensuring rapid deployment of funds to the most affected farmers. It reflects the EU’s commitment to safeguarding agricultural viability in the face of escalating climate‑change risks.

Key Elements

• Total EU aid: €21.5 million (Bulgaria €7.4 m, Estonia €3.3 m, Hungary €10.8 m).
  
• Eligible crops:
  
  • Bulgaria – sunflower, maize.
    
  • Estonia – spring wheat, barley, field peas, spring rapeseed, potatoes, fruit & vegetable crops.
    
  • Hungary – sweetcorn, melons, sorghum, oil radish, maize, popcorn maize.
    
• Disbursement deadline: All Union‑funded payments must be made by 30 September 2026.
  
• Additional national support: Member States may grant up to 200 % of the EU amount, payable by 31 December 2026, provided it does not distort competition or cause over‑compensation.
  
• Cumulation: Aid can be combined with other EU support (EAGF, EAFRD) but must be monitored to avoid double‑counting.
  
• Exchange‑rate rule: For non‑euro Member States (e.g., Hungary), the operative exchange rate is the rate on the date the regulation enters into force.
  
• Reporting requirements:
  
  • Notification of measures, criteria, and expected impact by 30 June 2026.
    
  • Final payment and effectiveness report by 31 March 2027.
    
• Monitoring and eligibility: Rapid payment to beneficiaries, with a cut‑off date for eligibility; payments after 30 September 2026 are excluded from Union financing.
  
• Objective and non‑discriminatory criteria: Aid must be based on actual economic losses and must not distort markets or competition.
  
• Transparency: Member States must provide detailed information to the Commission to enable monitoring of the measure’s effectiveness.

EU Sets Gold Standard for Carbon‑Removal Certification – A New Blueprint for Permanent CO2 Capture

Overview

The European Commission’s Delegated Regulation (EU) 2026/285 establishes the first EU‑wide certification methodologies for permanent carbon removals, covering direct air capture with storage (DACCS), biogenic emissions capture with storage (BioCCS), and biochar carbon removal (BCR). The regulation builds on the voluntary framework of Regulation (EU) 2024/3012, providing detailed rules for quantification, monitoring, and sustainability that enable operators to demonstrate compliance and generate certified carbon removal units.

The policy aims to close the funding gap that currently hampers DACCS, BioCCS, and BCR projects by allowing operators to earn revenue through the sale of certified units or through public support. It also introduces a standardised baseline of zero tonnes CO₂ eq per year for these activities, recognising their additionality and market failure.

To ensure long‑term climate benefits, the regulation requires geological storage of captured CO₂, rigorous monitoring of transport and injection, and strict liability for leakage. It mandates periodic review every four years, incorporating scientific advances and changes in related EU legislation, and promotes knowledge sharing through best‑practice events.

Key Elements

• Certification Methodologies

  • Separate, detailed procedures for DACCS, BioCCS, and BCR activities, covering eligibility, activity periods (≤ 15 yr for DACCS/BioCCS, ≤ 5 yr for BCR), monitoring, and certification periods (≤ 1 yr).
    
  • Quantification of total removals (CR_total) and associated GHG emissions (GHG_associated) with explicit formulas for segregated and non‑segregated CO₂ streams.
    

• Baseline and Additionality

  • Standardised baseline of 0 t CO₂ eq / yr for all three activity types.
    
  • Additionality ensured by market‑failure analysis and by requiring that any captured CO₂ be stored permanently in a geological site with a valid permit.
    

• Sustainability Requirements

  • Biomass sourcing must comply with Directive (EU) 2018/2001, avoid unsustainable demand, and respect the cascading use principle.
    
  • ILUC emissions are set to zero for on‑site heat/electricity derived from waste or residual biomass.
    
  • Biochar must meet strict heavy‑metal and contaminant limits (e.g., Pb ≤ 120 g t⁻¹, Cd ≤ 1.5 g t⁻¹) and have an H/Corg ratio ≤ 0.7.
    

• Liability and Permanence

  • Geological storage sites must be permitted under Directive (EU) 2009/31/EC and operators are liable for any CO₂ leakage.
    
  • Monitoring of transport and injection includes fugitive, vented, and leakage emissions, with mass‑balance rules for mixed CO₂ streams.
    

• Reporting and Monitoring

  • Mandatory activity plans, monitoring plans, and monitoring reports for each certification period.
    
  • Detailed data requirements for CO₂ flows, emissions, biomass feedstock, and financial sources.
    
  • Use of default emission factors and conservative uncertainty treatment (conservatism factor FC).
    

• Funding and Market Mechanisms

  • Public support and revenue from certified unit sales can be combined to overcome the funding gap.
    
  • Operators must disclose public financing and can purchase carbon farming sequestration units to offset biomass use.
    

• Periodic Review and Knowledge Sharing

  • Regulation to be reviewed at least every four years, incorporating technological progress and updates to related EU legislation (e.g., Directive (EU) 2018/2001).
    
  • Knowledge‑sharing events to collect feedback and best practices.
    

• Integration with EU Climate Policy

  • Aligns with the Paris Agreement, EU Climate Law (Regulation (EU) 2021/1119), and the EU Emissions Trading System (ETS).
    
  • Supports the EU’s climate‑neutrality objective by 2050 through a robust, transparent certification framework.

EU Tightens Trade Rules on Tin‑Plated Steel from China, Adding a New Company to the Duty List

Overview
In April 2026 the European Commission amended its anti‑dumping regulation on flat‑rolled iron or non‑alloy steel products plated or coated with tin that originate in China. The original 2025 regulation had imposed a definitive duty ranging from 13.1 % to 62.3 % depending on whether a Chinese exporter was sampled, cooperated, or was non‑cooperative. The amendment now adds Linqing Hengtai Metal Materials Co., Ltd to the list of cooperating exporters not sampled, subjecting it to a 24.6 % duty rate.

The company’s request for “new exporting producer treatment” (NEPT) was scrutinised through a questionnaire, industry comments, and a remote cross‑check. The Commission verified that Linqing Hengtai had not exported tin‑plated steel to the EU during the original investigation period, was unrelated to any already‑measured exporters, and had begun exporting after the period ended. Consequently, the company met all three NEPT conditions and was granted the 24.6 % duty rate.

The regulation entered into force the day after publication in the Official Journal, making the amended duty rates immediately binding across all EU Member States. The change reflects the Commission’s ongoing effort to level the playing field for EU steel producers while ensuring that new entrants to the market are subject to the same trade‑fairness standards.

Key Elements

• Anti‑dumping duty framework – definitive duties on tin‑plated steel from China, ranging from 13.1 % to 62.3 % based on sampling and cooperation status.
  
• Cooperating exporters not sampled – companies that did not participate in the sample but complied with the investigation receive a 24.6 % duty rate.
  
• New exporting producer treatment (NEPT) – a procedure allowing new entrants to be granted the cooperating‑producer duty rate if they meet three conditions: no exports during the original investigation period, no link to existing measured exporters, and subsequent exports to the EU.
  
• Linqing Hengtai Metal Materials Co., Ltd – added to the list of cooperating exporters not sampled; now subject to a 24.6 % duty rate.
  
• Regulatory amendment – Article 1 of the new regulation adds the company to Annex A of the original implementing regulation; Article 2 sets the effective date.
  
• Impact on trade – the amendment ensures that all Chinese exporters of tin‑plated steel, whether sampled or not, face consistent duty rates, potentially affecting supply chains, pricing, and competitiveness of EU steel producers.
  
• Transparency and consultation – the Commission opened a comment period to industry stakeholders, receiving no objections, and confirmed compliance with the Committee’s opinion under Regulation (EU) 2016/1036.

DOE Opens Window for U.S. LNG Re‑Exports to Non‑FTA Nations

Overview

Sabine Pass Liquefaction, LLC (SPL) has requested a short‑term blanket authorization from the Department of Energy (DOE) to export liquefied natural gas (LNG) that was previously imported into the United States. The proposed authorization would allow SPL to ship up to 500 billion cubic feet (Bcf) of LNG over a two‑year period, beginning June 7 2026, to any country that can import LNG via ocean‑going carriers and is not prohibited by U.S. law or policy. The request specifically targets non‑Free Trade Agreement (FTA) countries, while SPL already holds blanket re‑export authority for FTA partners.

DOE will evaluate the application under the Natural Gas Act (NGA) § 3(a) and must also satisfy National Environmental Policy Act (NEPA) requirements before issuing a final decision. The notice invites protests, comments, or motions to intervene, with a 30‑day comment period ending May 18 2026. The authorization is intended to replace an existing blanket re‑export order that expires on June 6 2026.

This move reflects the U.S. strategy to maintain flexibility in LNG trade, ensuring that imported LNG can be re‑exported to a broad range of global markets while adhering to legal and environmental safeguards.

Key Elements

• Volume & Duration: Up to 500 Bcf of LNG over a two‑year period (June 7 2026 – June 6 2028).
  
• Export Scope: LNG may be shipped to any non‑FTA country capable of receiving LNG by sea, provided U.S. law or policy does not prohibit trade.
  
• Source Facility: Exports would originate from the Sabine Pass LNG terminal in Cameron Parish, Louisiana.
  
• Legal Basis: Authorization sought under NGA § 3(a), with DOE’s review guided by federal regulations and NEPA.
  
• Existing Authority: SPL’s current blanket re‑export order (DOE/FECM Order No. 5125) expires on June 6 2026; the new request is timed to commence immediately thereafter.
  
• Domestic Gas Exclusion: The request does not cover domestically produced natural gas or LNG.
  
• Agency Role: SPL seeks authority on its own behalf and as agent for other title holders of the LNG at the time of export.
  
• Public Participation: Comment, protest, or intervention filings must be submitted by May 18 2026; DOE will consider all submissions before issuing a final order.
  
• Environmental Review: DOE must complete NEPA analysis before finalizing the authorization.
  
• Contact & Filing: Electronic filings encouraged at fergas@hq.doe.gov; physical mail to the Office of Global Energy Security, Forrestal Building, Washington, DC.

Wisconsin Hydropower Relicensing: Federal Review Begins

Overview

Wiscons8, LLC has applied to relicense the 210‑kilowatt Weyauwega Hydroelectric Project on the Waupaca River in Weyauwega, Wisconsin. The Federal Energy Regulatory Commission (FERC) has determined that the project is ready for environmental analysis and will prepare an Environmental Assessment (EA) to evaluate the potential impacts of the relicensing.

The EA will be circulated for public comment, with a 30‑day comment period beginning on December 28, 2026. FERC will consider all comments before making its final licensing decision. The agency has indicated that, based on current information and comments received, the relicensing is unlikely to constitute a major federal action that significantly affects the quality of the human environment.

Stakeholders—including local communities, environmental groups, and industry participants—can submit interventions, comments, or requests for rehearing through FERC’s Office of Public Participation. The process follows the National Environmental Policy Act (NEPA) schedule, with the EA’s unique identification number EAXX‑019‑20‑000‑1770895453.

Key Elements

• Project Details: 210‑kW Weyauwega Hydroelectric Project, Waupaca River, Weyauwega, Waupaca County, Wisconsin.
  
• Relicensing Application: Filed by Wiscons8, LLC on November 29, 2024; project number 2550‑030.
  
• Environmental Assessment: FERC will prepare an EA; no major federal action anticipated.
  
• Comment Period: 30 days starting December 28, 2026; public comments will influence the final decision.
  
• Public Participation: Contact Office of Public Participation (202) 502‑6595 or email for interventions, comments, or rehearing requests.
  
• NEPA Tracking: Document ID EAXX‑019‑20‑000‑1770895453.
  
• Schedule: EA issuance on December 28, 2026; revisions to the schedule may occur as needed.
  
• Contact for Questions: Arash Barsari, (202) 502‑6207 or email; Secretary Debbie‑Anne A. Reese, FERC.

Flathead National Forest Pulls the Plug on Mid‑Swan Landscape Restoration Project

Overview

The U.S. Forest Service has officially withdrawn its notice of intent to prepare an Environmental Impact Statement (EIS) for the Mid‑Swan Landscape Restoration and Wildland Urban Interface Fuels Project in Montana’s Flathead National Forest. The withdrawal also cancels the draft and final EIS documents, as well as the draft Record of Decision (ROD) that had been prepared.

This decision follows recent field work that reassessed resource conditions in the project area. The Forest Service concluded that the data no longer support proceeding with the proposed restoration and fuel‑management activities, leading to the cancellation of the regulatory process.

For stakeholders, the withdrawal means that no new management plan will be adopted for the Mid‑Swan area under this project, and the forest will continue to operate under existing policies. The Forest Service remains open to future studies or alternative projects that may better align with current ecological and community needs.

Key Elements

• Withdrawal of all regulatory documents: Notice of intent, draft EIS, final EIS, and draft ROD are all canceled.
  
• Reason for withdrawal: Recent field assessments indicated resource conditions that do not justify the original project scope.
  
• No immediate replacement: The Forest Service has not announced a new plan or timeline for alternative actions in the Mid‑Swan area.
  
• Implications for wildfire risk: The project aimed to reduce fuels in the wildland‑urban interface; its cancellation may affect future wildfire mitigation strategies.
  
• Contact information: District Ranger Sarah Canepa (200 Ranger Station Road, Bigfork, MT 59911; (406) 837‑7500; email) is the point of contact for questions.
  
• Timeline of prior actions: Notice of intent (Oct 2018), draft EIS notice (Aug 2020), final EIS (Sep 2021).
  
• Regulatory context: The withdrawal is a formal notice under the National Forest System’s environmental review process, ensuring transparency and public record.

Glencoe Mill Project to Undergo Environmental Review as Dam Removal Considered

Overview
Glencoe Mill, LLC, a former power‑generation facility on the Haw River in Alamance County, North Carolina, has ceased operations for three years and surrendered its federal licensing exemption in July 2025. The plant’s generator is no longer operable, the powerhouse has been secured, and the company no longer holds a lease on the site. Ownership of the dam and mill race now rests with Preservation North Carolina, a nonprofit that manages the surrounding land.

The exemptee has expressed willingness to assist Preservation North Carolina in maintaining the mill race, and a letter from December 2025 indicates that Preservation is exploring a partnership with American Rivers to remove the dam and donate the property to the county as a public park. This potential transformation from a decommissioned power plant to a recreational asset has prompted the Federal Energy Regulatory Commission (FERC) to initiate an environmental assessment (EA) under the National Environmental Policy Act (NEPA).

FERC plans to issue the EA by September 14, 2026, followed by a 30‑day public comment period. All comments will be reviewed and considered in the Commission’s final decision. Stakeholders, including local residents, environmental groups, and industry participants, are invited to submit comments or intervene in the proceeding through the Office of Public Participation.

Key Elements

• Exemption Surrender – Glencoe Mill, LLC relinquished its FERC licensing exemption (Project No. 7404) in July 2025 after determining the plant was not financially viable.
• Project Status – The plant has been disconnected from the grid, the generator is inoperable, and the powerhouse has been secured; no federal lands are involved.
• Ownership Transfer – The dam and mill race are now owned by Preservation North Carolina; the exemptee no longer holds a lease.
• Potential Dam Removal – Preservation North Carolina is considering a partnership with American Rivers to remove the dam and donate the site as a public park.
• Environmental Assessment – FERC will prepare an EA under NEPA, with a draft to be released by September 14, 2026, and a 30‑day comment period thereafter.
• Public Participation – Comments, interventions, or protests can be filed through the Office of Public Participation (phone: (202) 502‑6595) or directed to Rebecca Martin (202‑502‑6012).
• Timeline – Notice issued April 14, 2026; EA expected September 2026; schedule subject to revision.

EPA Releases Comments on 10 Federal Environmental Impact Statements

Overview

The Environmental Protection Agency (EPA) has published a notice announcing the availability of its comment letters on ten federal Environmental Impact Statements (EISs) that were filed between April 6 and April 13, 2026. Under the Council on Environmental Quality (CEQ) guidance and Section 309(a) of the Clean Air Act, the EPA is required to review and publicly comment on EISs prepared by other federal agencies. The notice lists the projects, the agencies involved, and the contact persons for each comment.

These comments cover a diverse set of projects—from defense and energy infrastructure to wilderness management and forest resilience—highlighting the EPA’s role in ensuring that environmental considerations are integrated into a wide range of federal decisions. The public can access the full comment letters through the EPA’s website or by contacting the listed individuals.

Key Elements

• Legal Basis: CEQ guidance on 42 U.S.C. 4332 and Section 309(a) of the Clean Air Act mandate EPA’s public comments on other agencies’ EISs.
  
• Availability Window: Comments were filed from April 6 to April 13, 2026, and are now publicly available.
  
• Projects Covered:
  
  • Draft Plutonium Pit Production Programmatic EIS (Defense)
    
  • Expansion of the Foreign Military Sales F‑35 Pilot Training Center (Defense)
    
  • ST LNG Deepwater Port Development Project (Energy)
    
  • High Uintas Wilderness Domestic Sheep Analysis (Wilderness)
    
  • Dell Creek Forest Park Elk Feedgrounds (Forest Management)
    
  • Pilgrim Creek Timber Sale Project (Timber)
    
  • Mokelumne Amador Calaveras Forest Resilience Project (Forest Resilience)
    
  • Interstate Bridge Replacement Program (Infrastructure)
    
  • Castle Mountain Mine (Mining)
    
• Contact Information: Each comment lists a primary contact (name, phone, and sometimes email) for follow‑up or inquiries.
  
• Public Access: The full comment letters are available on the EPA website; the notice also provides a phone number for general inquiries (202‑993‑3272).
  
• Agency Involved: The notice is issued by the EPA’s Office of Federal Activities, General Information, under Deputy Director Nancy Abrams.

Russia’s Phosphate Subsidies Uncovered: U.S. Imposes Countervailing Duties on Russian Fertilizers

Overview
The U.S. Department of Commerce’s International Trade Administration has finalized an administrative review of phosphate fertilizers exported from the Russian Federation during 2023. The review focused on Joint Stock Company Apatit (JSC Apatit) and its cross‑owned affiliates, determining that the company received countervailable subsidies that give it an unfair advantage in the U.S. market.

The final decision calculates a net countervailable subsidy rate of 12.71 % for the 2023 period, based on a detailed analysis of subsidy programs, cross‑ownership structures, and benchmark pricing. The assessment will be applied to all U.S. imports of the covered fertilizers, and Customs will collect cash deposits equal to the estimated duties until the case is resolved.

The review process experienced several delays due to a federal shutdown and backlog of electronic filings, resulting in multiple tolling and deadline extensions. Despite these procedural setbacks, the Department has issued clear instructions for duty assessment and enforcement, ensuring that U.S. farmers and industry stakeholders are protected from subsidized competition.

Key Elements

• Subsidy Rate: 12.71 % net countervailable subsidy for JSC Apatit (2023).
  
• Cross‑Owned Affiliates: Includes 15 PhosAgro‑related entities, all subject to the same duty assessment.
  
• Duty Assessment: Customs will assess duties on all eligible imports and collect cash deposits equal to the estimated countervailing duties.
  
• Enforcement Timeline: Assessment instructions to be issued 35 days after publication; cash deposits required immediately upon publication.
  
• Procedural Delays: Multiple tolling periods (47 days, 21 days, 53 days, 7 days) due to a federal shutdown and filing backlog.
  
• Administrative Protective Order: Parties must return or destroy proprietary information disclosed under APO; non‑compliance triggers sanctions.
  
• Implications for Geoscience & Natural Resources: The decision underscores the importance of transparent subsidy analysis for mineral resource exports and protects U.S. agricultural and industrial sectors from unfair foreign competition.

Lockville Dam to Be Removed: A Clean Slate for North Carolina’s Deep River

Overview

The U.S. Department of Energy and the Federal Energy Regulatory Commission (FERC) have released an Environmental Assessment (EA) for the Lockville Dam Hydroelectric Project in North Carolina. Brooks Energy, LLC, the owner of the dam, has determined that the facility is no longer economically viable, has not operated since 2020, and was breached in 2023. Consequently, the company is requesting to surrender its exemption from FERC licensing, effectively ending its legal status as a licensed hydroelectric facility.

The EA proposes that, following the surrender, the dam be removed by American Rivers and Resource Environmental Solutions as part of the American Rivers’ Watershed Restoration of the Upper Cape Fear and Lower Deep Rivers Project. The removal effort will receive financial and collaborative support from the National Oceanic and Atmospheric Administration (NOAA) and the U.S. Fish and Wildlife Service (USFWS). No new construction or ground‑disturbing activities are planned; the project focuses solely on dismantling the existing structure to restore natural river flow and improve habitat for fish and wildlife.

FERC’s assessment concludes that the surrender and removal will not constitute a major federal action under the National Environmental Policy Act, meaning it is unlikely to significantly affect the quality of the human environment. The public is invited to submit comments by May 14, 2026, 5:00 p.m. Eastern Time through FERC’s electronic filing system or by mail. The EA and related documents are available on FERC’s website via the eLibrary link.

Key Elements

• Exemption Surrender – Brooks Energy is relinquishing its FERC licensing exemption for Lockville Dam, acknowledging the project’s economic obsolescence.
  
• Dam Removal – The dam will be dismantled by American Rivers and Resource Environmental Solutions, restoring the Deep River’s natural flow.
  
• No New Construction – The plan includes no modifications to existing structures or ground‑disturbing activities.
  
• Environmental Assessment Outcome – The EA finds the action unlikely to be a major federal action, indicating minimal adverse environmental impact.
  
• Funding & Partnerships – NOAA and USFWS provide financial and collaborative support for the watershed restoration effort.
  
• Public Participation – Comments are due by May 14, 2026; submissions can be made electronically or by mail.
  
• Location – The project sits on the Deep River at the Chatham–Lee county border in North Carolina.
  
• Ecological Benefits – Removal is expected to enhance fish passage, improve water quality, and restore riparian habitats.
  
• Regulatory Context – The action is governed by FERC’s 18 CFR part 380 and the National Environmental Policy Act of 1969.

Gulf of America Seismic Surveys Get New 5‑Year Rule to Protect Marine Mammals

Overview

On April 17 2026 the National Marine Fisheries Service (NMFS) finalized a rule that extends the existing incidental‑take regulations for marine mammals during oil‑and‑gas geophysical surveys in U.S. waters of the Gulf of America (formerly the Gulf of Mexico) through April 19 2031. The rule allows operators to obtain Letters of Authorization (LOAs) that permit the incidental, non‑intentional disturbance of small numbers of marine mammals, provided that the cumulative impact over the five‑year period is negligible and that mitigation, monitoring, and reporting requirements are met.

The regulation preserves the same detection‑based mitigation measures, time‑area restrictions, vessel‑strike avoidance, and acoustic‑source shutdown protocols that were in place under the 2021 rule, while updating the geographic scope to exclude the Gulf of Mexico Energy Security Act leasing moratorium area. By re‑implementing the existing framework, NMFS avoids a lapse in regulatory certainty while new, industry‑specific rules are pending.

The rule is designed to balance the economic interests of the offshore energy sector with the conservation of marine mammals. It requires operators to conduct rigorous visual and acoustic monitoring, enforce immediate shutdowns when animals enter exclusion zones, and submit detailed annual reports. The negligible‑impact determination is based on species‑specific risk assessments that combine exposure estimates with population vulnerability, ensuring that any incidental take does not jeopardize subsistence uses or long‑term population health.

Key Elements

• Letters of Authorization (LOAs) – Legal permits that authorize incidental Level A or Level B harassment of marine mammals during geophysical surveys, subject to mitigation, monitoring, and reporting conditions.
  
• Negligible‑Impact Requirement – The total projected take over the five‑year period must be unlikely to affect annual recruitment or survival rates of any species or stock.
  
• Small‑Numbers Standard – Each LOA must limit take to no more than one‑third of the best‑available abundance estimate for the species, applied on a per‑LOA basis.
  
• Detection‑Based Mitigation – Visual and passive acoustic monitoring (PAM) must be conducted continuously; shutdown of acoustic sources is triggered when a marine mammal enters the exclusion zone.
  
• Exclusion and Buffer Zones – 500 m exclusion zone for deep‑penetration surveys (1 km total with pre‑clearance buffer), 100 m for shallow surveys (200 m total); extended 1,500 m shutdown for sensitive species such as Rice’s whales, sperm whales, and beaked whales.
  
• Time‑Area Restrictions – Airgun surveys are prohibited 90°–84° W and shoreward of the 20‑m isobath during January–May to protect the northern coastal bottlenose dolphin stock.
  
• Monitoring and Reporting – Operators must submit detailed 90‑day draft reports and annual synthesis reports, including vessel tracks, environmental conditions, sightings, acoustic detections, and take estimates.
  
• Adaptive Management – Annual reports feed into NMFS’s adaptive‑management cycle; LOAs can be modified if mitigation or monitoring changes, subject to public comment.
  
• Stakeholder Engagement – The rule was developed after a 30‑day comment period that included industry associations, conservation groups, and the public; it incorporates industry‑requested lower‑impact acoustic source estimates and maintains robust protection for marine mammals.
  
• Economic Context – The rule is deemed economically significant, with projected compliance costs of $31–$90 million (2019 dollars) but offers substantial savings compared to a baseline that includes recent BOEM biological‑assessment conditions.

Breathe Easier: Congress Proposes Grants to Build Clean‑Air Centers for Wildfire Smoke

Overview
The Cleaner Air Spaces Act of 2025 seeks to protect low‑income households in wildfire‑prone areas by funding local “clean‑air” programs. The bill directs the Environmental Protection Agency (EPA) to award grants—up to $3 million each—to state and local air‑pollution control agencies, with at least one grant earmarked for tribal agencies. These funds will help agencies establish clean‑air centers, distribute high‑efficiency air‑filtration units, and partner with community organizations to educate residents about smoke‑mitigation practices.

The program requires agencies to set up at least one clean‑air center in a high‑risk area, make it freely accessible during smoke events, and provide free filtration units and replacements to 1,000 covered households. Agencies must also conduct surveys to gauge user understanding and effectiveness, and submit detailed reports to Congress within three years of enactment. The bill authorizes $30 million for 2026‑2028, with no more than 10 % spent on administration.

Key Elements

• Grant Limits & Eligibility

  • Maximum grant per agency: $3 million.
    
  • At least one grant must go to a tribal air‑quality agency.
    
  • Grants available only if appropriations are available.

• Application Requirements

  • Agencies submit proposals detailing partnership with a community‑based organization, responsibilities, target populations, distribution plans, and cost estimates.
    
  • Proposals must include plans for clean‑air centers and educational outreach.

• Clean‑Air Center & Unit Distribution

  • Centers must be located in wildfire‑smoke‑risk zones, accessible to covered households, and staffed during smoke events.
    
  • Agencies must distribute a minimum of 1,000 eligible air‑filtration units at no cost, plus one replacement filter per unit.
    
  • Units must meet strict certification standards (Clean Air Delivery Rate ≥ 97, Energy Star, HEPA 99.97 % for 0.3 µm particles, no ozone emission).

• Community Engagement & Education

  • Mandatory partnership with at least one community‑based organization.
    
  • Distribution of educational materials on creating clean‑air rooms and proper unit use.
    
  • Public advertising of center availability and program details during smoke events.

• Monitoring & Reporting

  • Agencies must collect data on unit types, quantities, and costs.
    
  • Conduct anonymous surveys within six months of unit distribution to assess usage, barriers, and perceived air quality improvements.
    
  • EPA to submit a comprehensive report to Congress within three years, including program outcomes and expansion recommendations.

• Funding & Administration

  • $30 million authorized for fiscal years 2026‑2028.
    
  • No more than 10 % of these funds may be used for administrative expenses.
    

• Definitions

  • Clarifies terms such as “clean‑air center,” “clean‑air room,” “covered household,” and “eligible air‑filtration unit” to ensure consistent implementation across agencies.

Green Mountain Power’s Water‑Quality Certification Deadline Set by FERC

Overview
On April 6 2026, the Federal Energy Regulatory Commission (FERC) announced that Green Mountain Power Corporation (GMP) had submitted a Clean Water Act Section 401(a)(1) water‑quality certification request to the Vermont Department of Environmental Conservation (DEC) for a project under consideration by FERC. The request, received by DEC on April 1 2026, requires the state agency to evaluate whether the project will comply with federal water‑quality standards before it can proceed.

FERC’s notice establishes a one‑year window for DEC to act. If the DEC fails to approve or deny the certification by April 1 2027, the agency’s authority to certify the project is deemed waived under the Clean Water Act, effectively allowing GMP to move forward without a formal state certification. This procedural step is a routine part of the federal approval process for energy projects that may affect water resources.

The notice underscores the importance of timely environmental review in the permitting of energy infrastructure. It also highlights how federal and state agencies coordinate to ensure that projects meet water‑quality requirements, with potential implications for local ecosystems, water users, and the broader energy supply chain.

Key Elements

• GMP submitted a Section 401(a)(1) water‑quality certification request to Vermont DEC on April 1 2026.
  
• FERC notified DEC of the request and set a deadline of April 1 2027 for DEC to act.
  
• If DEC does not approve or deny the certification by the deadline, the agency’s authority is deemed waived, allowing GMP to proceed without state certification.
  
• The notice is part of FERC’s regulatory framework for ensuring compliance with the Clean Water Act during the approval of energy projects.
  
• The process involves coordination between federal (FERC) and state (Vermont DEC) environmental authorities to protect water resources while facilitating energy development.

Indiana Faces Severe Storms: SBA Declares Disaster, Opens Door to Relief Loans

Overview

On April 9, 2026 the U.S. Small Business Administration (SBA) issued an administrative declaration of disaster for the state of Indiana, citing widespread damage from severe storms and tornadoes. The declaration authorizes the SBA to provide low‑interest disaster assistance loans to homeowners, businesses, and non‑profit organizations that suffered physical damage or economic injury during the event.

The notice makes clear that the declaration is active and that affected counties—including Jasper, Newton, and several neighboring counties in Indiana and Illinois—are eligible for assistance. Applicants can submit loan requests online through the MySBA Loan Portal or at designated local sites, with contact information provided for further support.

The policy’s primary goal is to accelerate recovery by offering affordable financing for repairs, replacement, and business continuity, thereby helping communities rebuild infrastructure, protect livelihoods, and restore economic stability after the storm season.

Key Elements

• Administrative Declaration – SBA’s official disaster declaration (Disaster Numbers 21495C for physical damage, 214960 for economic injury).
  
• Affected Areas – Jasper, Newton, and contiguous counties in Indiana (Benton, LaPorte, Lake, Porter, Pulaski, Starke, White) plus Illinois counties (Iroquois, Kankakee).
  
• Loan Eligibility – Homeowners, small businesses, agricultural cooperatives, and private non‑profits with or without existing credit.
  
• Interest Rates –
  
  • Physical Damage: 5.750 % (homeowners with credit), 2.875 % (homeowners without credit), 8.000 % (businesses with credit), 4.000 % (businesses without credit), 3.625 % (non‑profits).
    
  • Economic Injury: 4.000 % (businesses and agricultural cooperatives without credit), 3.625 % (non‑profits).
    
• Application Process – Online via MySBA Loan Portal or in person at local SBA‑announced locations; assistance available through the SBA Disaster Assistance Customer Service Center.
  
• Contact Information – Sharon Henderson, Office of Disaster Recovery and Resilience, SBA; phone (202) 205‑6734, toll‑free 1‑800‑659‑2955.
  
• Purpose – Provide timely, affordable financing to repair physical damage, mitigate economic losses, and support community resilience following severe storms and tornadoes.

Louisiana Lands Set for Recreational Lease: BLM Seeks Public Input on 158‑Acres Wildlife Management Area

The Bureau of Land Management (BLM) has announced that it intends to classify about 158 acres of federal land in Rapides and LaSalle Parishes, Louisiana, for lease or conveyance under the Recreation and Public Purposes (R&PP) Act. The land, located within the Dewey W. Wills Wildlife Management Area, would be managed by the Louisiana Department of Wildlife and Fisheries (LDWF) for activities such as hunting, trapping, boating, camping, and bird‑watching. The proposal is part of the BLM’s Louisiana Approved Land Use Plan and follows an Environmental Assessment that found no significant impact.

The classification would separate the parcel from most other public‑land appropriation mechanisms, except for mineral and geothermal leasing. If the lease or conveyance is approved, the LDWF would be required to follow strict environmental and cultural‑resource safeguards, preserve invasive‑species control, and maintain public access. Mineral rights would remain with the United States, and the lease would include indemnification and reversion clauses to protect federal interests.

Public comment is invited until June 1, 2026. Stakeholders can submit written statements to the BLM Southeast States District Office. If no adverse comments are received, the classification becomes effective 60 days after publication. The process underscores the balance between expanding recreational opportunities and preserving environmental and cultural values on federal lands.

Key Elements

• Land Classification: 158.41 acres earmarked for lease/conveyance under the R&PP Act.
  
• Recreational Uses: Hunting, trapping, boating, camping, bird‑watching, with planned infrastructure (parking lot, boat launch).
  
• Mineral Rights: Reserved for the United States; mineral leasing remains possible under separate statutes.
  
• Environmental Safeguards:
  
  • Invasive species control and soil stability measures.
    
  • No adverse impacts on native vegetation or endangered species.
    
  • Vehicle power‑washing to prevent weed spread.
    
• Cultural‑Resource Protection:
  
  • Immediate halt of work if cultural resources are encountered.
    
  • Licensed archaeologist required during ground disturbance.
    
• Lease/Conveyance Conditions:
  
  • Indemnification of the U.S. against claims arising from use.
    
  • Reversion clauses if the property is misused or not maintained.
    
  • Compliance with the National Historic Preservation Act and Secretary of the Interior’s standards.
    
• Public Participation: Comments due by June 1, 2026; adverse comments may lead to modification or cancellation of the action.
  
• Administrative Context: Consistent with the 2002 Louisiana Approved Land Use Plan; supported by an Environmental Assessment and Finding of No Significant Impact.

Tucson Airport Superfund Site to Get PFAS Treatment System Under New EPA Settlement

Overview

The U.S. Environmental Protection Agency (EPA) has announced a proposed settlement with the City of Tucson to address contamination at the Tucson International Airport Area Superfund Site. The site has been identified as a source of per‑ and polyfluoroalkyl substances (PFAS), a group of chemicals linked to health and environmental risks. Under the settlement, the city will construct a treatment system at the Tucson Area Remediation Plant to capture and treat PFAS‑laden water before it enters the broader water system.

The agreement, governed by the Comprehensive Environmental Response, Compensation and Liability Act (CERCLA), also includes a covenant not to sue and contribution protection for the city. These provisions aim to streamline remediation efforts and protect the municipality from future litigation related to the cleanup work. The EPA will review public comments and may modify or withdraw the settlement if new information indicates it is inappropriate or inadequate.

Comments on the proposed settlement are due by May 18 2026. The EPA invites stakeholders—including scientists, local residents, and industry representatives—to submit feedback through the designated docket (CERCLA‑09‑2026‑007). The outcome will shape how PFAS contamination is managed at a key transportation hub and could set a precedent for similar Superfund sites nationwide.

Key Elements

• PFAS Focus: Settlement requires construction of a PFAS treatment system at the Tucson Area Remediation Plant.
  
• CERCLA Basis: Agreement is entered under the Comprehensive Environmental Response, Compensation and Liability Act (1980, amended).
  
• Covenant Not to Sue: City of Tucson agrees not to pursue legal action against the EPA for the cleanup work.
  
• Contribution Protection: City receives protection from liability for contributions made to the remediation effort.
  
• Public Comment Period: Comments must be submitted by May 18 2026 under docket ID CERCLA‑09‑2026‑007.
  
• EPA Region 9 Oversight: The settlement is managed by the EPA’s Region 9 office in San Francisco.
  
• Potential Modifications: EPA may alter or withdraw consent if new facts render the settlement inappropriate or inadequate.
  
• Superfund Context: The site is designated as a Superfund location, indicating significant contamination requiring federal oversight.

Maine’s New Energy‑Storage Project Gets the Green Light for Traditional Licensing

Overview

Western Maine Energy Storage, LLC (WMES) has formally requested to use the Federal Energy Regulatory Commission’s (FERC) traditional licensing process for a new energy‑storage facility that will sit on tributaries of the Androscoggin River in Dixfield, Oxford County. The company filed a pre‑application document (PAD) on February 13, 2026, and the Commission approved the request on April 13, 2026, allowing the project to proceed under the standard, detailed review framework rather than the streamlined “small‑hydro” pathway.

The project will harness hydroelectric potential in the region, storing excess renewable energy and improving grid reliability. As part of the licensing process, WMES is engaging in required environmental consultations: the U.S. Fish and Wildlife Service and the National Marine Fisheries Service under the Endangered Species Act and the Magnuson‑Stevens Fishery Conservation and Management Act, and the Maine State Historic Preservation Office under the National Historic Preservation Act. These steps ensure that the project’s impacts on wildlife, fisheries, and historic resources are carefully evaluated.

For stakeholders and the public, the notice signals that the project is moving forward, but also that opportunities exist to review the PAD, submit comments, or intervene in the licensing process. The Commission’s website hosts the PAD and related documents, and interested parties can register for updates or contact FERC’s Office of Public Participation for assistance.

Key Elements

• Traditional Licensing Path – WMES has been granted permission to use FERC’s standard licensing process, which involves comprehensive environmental and technical reviews.
  
• Pre‑Application Document (PAD) – Filed on February 13, 2026, the PAD outlines the proposed project design, schedule, and environmental mitigation measures.
  
• Environmental Consultations –
  
  • Endangered Species Act (ESA): Informal consultation with the U.S. Fish and Wildlife Service.
    
  • Magnuson‑Stevens Act: Consultation with the National Marine Fisheries Service under section 305(b).
    
  • National Historic Preservation Act (NHPA): Consultation with the Maine State Historic Preservation Officer.
    
• Public Notice and Participation – Public notice of the request was issued on March 4, 2026; the PAD is available on FERC’s eLibrary (docket P‑15410).
  
• Contact Points – Corporate Environmental Manager Lauren Walsh and FERC liaison Justin Robbins are primary contacts; the Office of Public Participation handles interventions and comments.
  
• Implications for Geoscience and Natural Resources – The project will alter river flow regimes, potentially affecting sediment transport, aquatic habitats, and local hydrology, while also contributing to renewable energy storage capacity in the region.

Northern Natural Gas Eyes Pipeline Swap and Expansion: Public Gets First Look at Environmental Impact

Overview

The Federal Energy Regulatory Commission (FERC) has opened a scoping period to gather public input on the environmental implications of two interlinked projects proposed by Northern Natural Gas Company. The Ventura to Farmington A‑Line Abandonment and Capacity Replacement Project (V2F) will retire 131 miles of aging pipeline and replace lost capacity with three new extensions. The Northern Lights 2027 Expansion Project (NL27) will add 28.5 miles of pipeline and upgrade a compressor station, boosting firm service by 79.3 dekatherms per day. Together, the projects span parts of Iowa and Minnesota, affecting 1,000+ acres of land and multiple counties.

The scoping notice invites comments on potential environmental effects, reasonable alternatives, and mitigation measures. FERC will use this input to focus its forthcoming environmental document—an Environmental Assessment (EA) or Environmental Impact Statement (EIS)—under the National Environmental Policy Act (NEPA). The goal is to identify the most significant issues in geology, water resources, wildlife, cultural sites, and air quality, while also considering land‑use impacts and the rights of landowners.

Key stakeholders include landowners, state and local agencies, environmental groups, and Native American tribes. The notice explains the eminent domain authority that may be invoked if easement agreements cannot be reached, and it outlines how comments can be submitted electronically or by mail. The deadline for comments is May 13, 2026.

Key Elements

• Project Scope

  • Abandonment of ~131 mi of 16‑ and 18‑inch pipelines (Ventura to Farmington).
    
  • Construction of 3 new extensions (8.3 mi, 2.1 mi, 7.5 mi).
    
  • Addition of 28.5 mi of variable‑diameter pipeline and compressor upgrade (NL27).
    
  • Total land use: ~1,000 acres; permanent operation footprint: ~254 acres.

• Environmental Focus Areas (NEPA)

  • Geology & soils, water resources & wetlands, vegetation & wildlife, threatened species, cultural resources, land use, air quality & noise, reliability & safety.
    
  • Evaluation of reasonable alternatives and mitigation strategies.

• Public Participation

  • Scoping period ends May 13, 2026.
    
  • Comments accepted via eComment, eFiling, or paper mail.
    
  • FERC will consider all written comments in the environmental document.

• Eminent Domain & Landowner Rights

  • Northern may negotiate easements; if none, eminent domain can be exercised under the Natural Gas Act.
    
  • Landowners receive a fact sheet explaining rights and procedures.

• Agency Cooperation

  • FERC seeks cooperating agencies (state, local, tribal) to assist in preparing the environmental document.
    
  • Section 106 consultation with historic preservation offices is underway.

• Next Steps

  • After scoping, FERC will decide whether to prepare an EA or EIS.
    
  • Draft documents will be released for public comment before final decisions on the projects.

U.S. Imposes Countervailing Duties on Silicon Metal from Laos to Protect Domestic Industry

Overview

The U.S. Department of Commerce has issued a countervailing duty (CVD) order on silicon metal imported from the Lao People’s Democratic Republic (Laos). The order follows affirmative final determinations by both the Commerce Department and the U.S. International Trade Commission (ITC) that Lao producers receive subsidies and that these subsidized imports materially injure U.S. silicon metal producers.

The order requires U.S. Customs and Border Protection to assess countervailing duties on all relevant entries of Lao silicon metal entered or withdrawn from warehouses for consumption from September 26 2025 onward. It also suspends the liquidation of these imports and mandates cash deposits equal to the subsidy rates until the ITC’s final injury determination is published. The duties apply to all forms of silicon metal containing 85–99.99 % silicon, excluding semiconductor‑grade silicon.

For U.S. manufacturers, the order aims to level the playing field by offsetting the advantage gained by Lao subsidies. For Lao exporters, it introduces additional costs and administrative requirements, potentially affecting trade flows and the broader supply chain for silicon‑based products.

Key Elements

• Subsidy Determination: Lao silicon metal producers receive countervailable subsidies, as confirmed by Commerce and ITC.
• Material Injury: ITC found that subsidized imports are materially injuring the U.S. silicon metal industry.
• Duty Assessment: Countervailing duties will be imposed on all relevant entries from September 26 2025 onward, with rates of 69.10 % for Lao Silicon Co., Ltd and the same rate for all other exporters.
• Suspension of Liquidation: Liquidation of Lao silicon metal imports is suspended until the ITC’s final injury determination is published, after which liquidation resumes without duty assessment.
• Cash Deposits: Importers must deposit cash equal to the subsidy rate at the time of entry, in addition to normal customs duties.
• Scope: Covers silicon metal with 85–99.99 % silicon and less than 4 % iron; excludes semiconductor‑grade silicon (≥ 99.99 % silicon).
• Administrative Procedures: Annual inquiry service lists and entry of appearance requirements for petitioners and the Lao government to participate in the order’s oversight.
• Implications for Trade: The order may increase costs for U.S. importers of Lao silicon metal, potentially shifting sourcing decisions and affecting downstream industries such as electronics, solar, and automotive manufacturing.

FERC Staff Protest Over Pipeline Project’s Historic Preservation Gap

Overview
The U.S. Federal Energy Regulatory Commission (FERC) staff has formally protested a proposed blanket certificate application by Transwestern Pipeline Company, LLC. The protest centers on the company’s failure to provide a required finding from the New Mexico State Historic Preservation Office indicating that no historic properties would be affected by the planned 17.8‑mile, 24‑inch natural‑gas pipeline and associated facilities in Doña Ana County. Under FERC’s Part 157 regulations, this documentation is essential to demonstrate compliance with the National Historic Preservation Act.

The protest effectively treats the blanket certificate request as a case‑specific application, subjecting it to the same scrutiny and procedural requirements. If the protest is not withdrawn within 30 days, the project’s approval could be delayed or denied until the missing historic‑preservation evidence is supplied. The protest period expires on April 13, 2026, placing a tight deadline on Transwestern to address the deficiency.

For stakeholders in geoscience, energy, and natural resource fields, this case highlights the importance of thorough environmental and historic‑preservation assessments in pipeline development. It also underscores how regulatory oversight can pause large infrastructure projects when critical compliance documentation is absent.

Key Elements

• Protest Filed: FERC staff protested Transwestern’s blanket certificate request on April 13, 2026.
  
• Project Scope: 17.77‑mile, 24‑inch natural‑gas transmission pipeline lateral, two metering facilities, and related appurtenances for the Green Chile Project.
  
• Missing Documentation: No copy of the New Mexico State Historic Preservation Office’s “no historic properties” finding, required under Part 157.206(b)(3)(ii) and 157.208©(9).
  
• Regulatory Basis: Part 157, subpart F of FERC regulations; Section 157.205(f) treats a protested blanket certificate as a case‑specific application.
  
• Protest Deadline: 30‑day window to withdraw the protest; otherwise, the project faces potential delay or denial until compliance is demonstrated.
  
• Implications: Highlights the critical role of historic preservation compliance in pipeline approvals and the potential for regulatory action to halt projects lacking required documentation.

FERC Opens the Floor to Public Input on WBI Energy’s Planned Abandonment of Montana Gas Wells

Overview

On April 2 2026, WBI Energy Transmission, Inc. filed a request with the Federal Energy Regulatory Commission (FERC) to abandon five natural‑gas storage wells, roughly 4.12 mi of three‑ and four‑inch pipelines, and two above‑ground measurement facilities at its Baker Storage Field in Fallon County, Montana. The company argues that the abandonment is necessary to preserve the integrity of the storage field and to comply with safety and environmental standards.

FERC has published the full request and is inviting public participation. Interested parties may file protests, motions to intervene, or comments through the Commission’s e‑filing system or by mail. All submissions must be received by 5:00 p.m. Eastern Time on June 12 2026. Protests and interventions are governed by the Natural Gas Act regulations (18 CFR 157.205 and 157.216), while comments are considered in the Commission’s decision‑making process.

For geoscientists, energy and mineral resource professionals, and local stakeholders, this notice highlights the regulatory pathway for decommissioning gas infrastructure and the opportunity to influence how abandoned wells are managed to protect subsurface resources, surface land use, and community interests.

Key Elements

• Project Scope: Abandonment of 5 storage wells, ~4.12 mi of 3‑inch and 4‑inch pipelines, and 2 measurement facilities at Baker Storage Field, Fallon County, MT.
  
• Regulatory Basis: Request filed under FERC’s blanket authorization (Docket CP82‑487‑000) and NGA sections 157.205(b) and 157.216(b).
  
• Public Participation:
  
  • Protests: Any person may protest; if none filed or withdrawn within 30 days, the abandonment is authorized.
    
  • Interventions: Motion to intervene grants party status, enabling rights to challenge orders and seek rehearing.
    
  • Comments: Open to all; do not confer party status unless accompanied by intervention.
    
• Deadlines: All protests, interventions, and comments due by 5:00 p.m. ET on June 12 2026.
  
• Filing Methods: e‑filing via FERC’s website (eFiling and eComment) or paper mail to the Commission’s Secretary.
  
• Access to Documents: Full request available in PDF and Word on FERC’s eLibrary; ongoing updates and filings can be tracked through eSubscription.
  
• Implications for Geoscience: The abandonment plan will affect subsurface integrity, potential groundwater interactions, and long‑term monitoring of abandoned wells. Stakeholders can influence how monitoring and safety measures are implemented.

Washington Faces Major Disaster: Federal Assistance Opens for Storm‑Damaged Communities

Overview

On April 7, 2026 the President declared a major disaster for public assistance only in the state of Washington, following a series of severe storms, straight‑line winds, flooding, landslides, and mudslides. The declaration activates federal aid through the Small Business Administration (SBA), enabling public infrastructure and essential services to receive financial support.

The notice names 27 primary counties—ranging from Asotin to Yakima—and a broad coalition of tribal nations, including the Yakama, Chehalis, and Lummi, among those adversely affected. Eligible recipients include private non‑profit organizations and public entities that can secure disaster assistance loans at a fixed interest rate of 3.625 % for both physical damage and economic injury. Applications may be submitted online via the MySBA Loan Portal or in person at designated SBA locations.

The declaration is currently active, with disaster numbers 21503 and 21504 (Washington Disaster Number WA‑20028) and a catalog assistance number of 59008. Contact details for the SBA Disaster Recovery & Resilience office are provided, and the notice clarifies that assistance is limited to public entities and private non‑profits with credit availability.

Key Elements

• Declaration Date & Scope: April 7, 2026; public assistance only for Washington.
  
• Disaster Types: Severe storms, straight‑line winds, flooding, landslides, mudslides.
  
• Affected Areas: 27 primary counties (e.g., King, Pierce, Snohomish) and numerous tribal nations.
  
• Loan Eligibility: Private non‑profits and public entities; no private property coverage.
  
• Interest Rate: Fixed 3.625 % for both physical damage and economic injury.
  
• Disaster Numbers: 21503, 21504 (WA‑20028); physical damage 215036, economic injury 215040.
  
• Application Process: MySBA Loan Portal or local SBA offices; contact SBA Disaster Recovery & Resilience.
  
• Contact Information: Jennifer Talarico, SBA Disaster Recovery & Resilience, 1‑800‑659‑2955 (or 7‑1‑1 for relay services).
  
• Catalog Assistance: 59008 (Catalog of Federal Domestic Assistance).
  
• Legal Authority: 13 CFR 123.3(b).
  
• Public Assistance Focus: Infrastructure, essential services, and public works—no private property loans.

Washington Faces Major Disaster: SBA Opens Disaster Loan Window After Record Storms

Overview
On April 7, 2026 the President declared a major disaster for the State of Washington in response to severe storms, straight‑line winds, flooding, landslides, and mudslides that struck the region. The Small Business Administration (SBA) issued a notice to inform residents, businesses, and tribal communities that disaster assistance loans are now available to help repair physical damage and recover from economic injury.

The declaration covers 12 Washington counties—including King, Pierce, and Whatcom—as well as numerous tribal nations such as the Lummi and Puyallup Tribes. A separate list of contiguous counties is eligible for economic‑injury loans only. Applicants can apply online through the MySBA Loan Portal or at local SBA‑announced locations, with assistance available via phone, email, or telecommunications relay services for those with disabilities.

The SBA has set specific interest rates for different borrower categories, ranging from 2.875 % for homeowners without other credit to 8.000 % for businesses with other credit. The program is authorized under 13 CFR 123.3(b) and is part of the federal assistance catalog (59008). The goal is to provide timely, low‑cost financing to help Washington’s communities rebuild and recover.

Key Elements

• Declaration Date & Scope

  • Presidential major disaster declaration: April 7, 2026 (FEMA‑4906‑DR).
    
  • Affected counties: Chelan, Grays Harbor, King, Lewis, Pacific, Pierce, Skagit, Snohomish, Thurston, Whatcom.
    
  • Affected tribal nations: Lummi, Muckleshoot, Nisqually, Nooksack, Puyallup, and others.
    
  • Contiguous counties eligible for economic‑injury loans: Cowlitz, Douglas, Island, Jefferson, Kitsap, etc.

• Loan Availability

  • Disaster assistance loans for physical damage and economic injury.
    
  • Application portal: MySBA Loan Portal (online) or local SBA‑announced sites.
    
  • Contact: Sharon Henderson, Office of Disaster Recovery & Resilience, SBA.

• Interest Rates

  • Physical Damage
    
  • Homeowners with credit elsewhere: 5.750 %
    
  • Homeowners without credit elsewhere: 2.875 %
    
  • Businesses with credit elsewhere: 8.000 %
    
  • Businesses without credit elsewhere: 4.000 %
    
  • Private non‑profits (any credit status): 3.625 %
    
  • Economic Injury
    
  • Businesses and small agricultural cooperatives without credit elsewhere: 4.000 %
    
  • Private non‑profits without credit elsewhere: 3.625 %

• Timeline & Contact

  • Application period: December 5–19, 2025; June 10, 2026; January 7, 2027.
    
  • SBA disaster assistance customer service: 1‑800‑659‑2955 or email.
    
  • Telecommunications relay for deaf/hard‑of‑hearing: 7‑1‑1.

• Program Authority

  • Authorized under 13 CFR 123.3(b).
    
  • Catalog of Federal Domestic Assistance Number: 59008.

Forest Service Extends Key Application Form for Federal Land Projects – Your Input Needed

The Forest Service, under the Department of Agriculture, has announced that it will continue to use the SF‑299 form—“Application for Transportation, Utility Systems, Telecommunications and Facilities on Federal Lands and Property”—without changes. The request is made in accordance with the Paperwork Reduction Act of 1995, which requires agencies to seek public comment before extending or revising information‑collection procedures. The SF‑299 is the primary tool the agency uses to evaluate proposals for special use authorizations on National Forest System lands, covering everything from roads and power lines to telecommunications infrastructure.

The notice invites comments on whether the continued collection of SF‑299 data is necessary, the accuracy of the agency’s burden estimate (about 8 hours per response, 2,753 expected responses, totaling roughly 22,000 hours of work), and ways to improve the form’s clarity and reduce respondent burden. Comments are due by June 15, 2026 and can be submitted by mail or email. The agency will make all comments publicly available, so respondents should avoid including confidential or proprietary information.

This extension matters to geoscientists, energy and mineral resource professionals, and anyone involved in planning or operating infrastructure on federal lands. The data collected help the Forest Service assess technical and financial feasibility, support environmental reviews, and administer authorizations that can impact land use, resource extraction, and ecosystem management.

Key Elements

• Extension without revision of the SF‑299 information collection, effective until January 31, 2027.
  
• Purpose: evaluate proposals for transportation, utilities, telecommunications, and facilities on National Forest lands; support environmental review and statutory compliance.
  
• Burden estimate: 8 hours per response; 2,753 expected responses; 22,024 total hours of public effort.
  
• Comment topics: necessity of the collection, burden accuracy, data quality, and ways to reduce respondent effort (e.g., electronic submission).
  
• Submission deadline: June 15, 2026.
  
• Contact: Mark Chandler, Realty Specialist, Lands, National Forest Systems (phone 202‑205‑1117, email [not provided]).
  
• Relevant statutes: FLPMA, National Forest Roads and Trails Act, Mineral Leasing Act, and others governing special use authorizations.
  
• Public record: All comments will be publicly available; avoid confidential or proprietary details.
  
• Impact: Affects planning and permitting for infrastructure projects that intersect with natural resource management, environmental protection, and land‑use policy.

EEA Updates Energy Efficiency Rules, Exempts Icelandic Geothermal Cogeneration

Overview

The European Economic Area (EEA) Joint Committee has amended Annex IV of the EEA Agreement to incorporate the EU’s Commission Delegated Regulation (EU) 2015/2402. This regulation revises the harmonised efficiency reference values for separate production of electricity and heat—essentially the standards for cogeneration plants—while repealing an earlier implementing decision (2011/877/EU). The amendment aligns the EEA’s energy rules with the EU’s Directive 2012/27/EU on energy efficiency, ensuring a common framework for assessing and improving cogeneration performance across member states.

A key feature of the decision is an exemption for Iceland. Because Iceland’s heating demand is largely met by geothermal energy and the country actively promotes geothermal cogeneration, the new regulation will not apply to Icelandic geothermal cogeneration facilities. This allows Iceland to continue developing its unique geothermal energy sector without being bound by the EU‑wide efficiency reference values that apply to other cogeneration technologies.

The decision entered into force on 6 December 2025, following the necessary notifications under Article 103(1) of the EEA Agreement. It will be published in the Official Journal of the European Union and the EEA Supplement, and the amended Annex IV will be updated accordingly.

Key Elements

• Incorporation of Regulation (EU) 2015/2402 – sets harmonised efficiency reference values for separate electricity and heat production (cogeneration).
  
• Repetition of 2011/877/EU – the earlier implementing decision is repealed and removed from the EEA Agreement.
  
• Icelandic Exemption – geothermal cogeneration in Iceland is excluded from the new efficiency reference values, preserving its current development trajectory.
  
• Amendment to Annex IV (Energy) – the text of point 24b is replaced to reflect the new regulation and its Icelandic exemption.
  
• Entry‑into‑Force – effective 6 December 2025, contingent on required notifications.
  
• Publication – decision published in the Official Journal of the EU and the EEA Supplement, with authentic Icelandic and Norwegian language versions.
  
• Alignment with EU Energy Efficiency Directive – ensures the EEA’s energy rules remain consistent with EU policy on improving cogeneration efficiency.

Harmonizing Environmental Data Verification Across the EEA

Overview

The European Economic Area (EEA) Joint Committee has adopted a decision to amend Annex XX of the EEA Agreement, formally incorporating Commission Implementing Regulation (EU) 2024/1321. This regulation updates the framework for verifying environmental data and accrediting verifiers, ensuring that all EEA member states and associated countries apply a consistent, transparent methodology for environmental monitoring.

The amendment strengthens the legal basis for data verification in key environmental domains—air quality, water resources, and biodiversity—by embedding the new verification standards directly into the EEA Agreement. It also clarifies the procedural steps for publishing the regulation in the Official Journal and sets a clear entry‑into‑force date, thereby providing certainty for national authorities, research institutions, and industry stakeholders.

For geoscientists, energy and mineral resource managers, and natural‑resource professionals, the decision means that data used in environmental impact assessments, resource extraction permits, and climate‑related reporting will now be subject to a harmonized verification regime. This promotes greater comparability of data across borders and supports more robust decision‑making in environmental policy and resource management.

Key Elements

• Incorporation of Regulation (EU) 2024/1321: The regulation, which revises the verification of environmental data and accreditation of verifiers, is now part of the EEA Agreement’s Annex XX.
• Amendment to Annex XX: A new clause (point 21apk) references the regulation, ensuring that all EEA parties recognize and apply its provisions.
• Entry‑into‑Force: The decision becomes effective on 6 December 2025, once notifications under Article 103(1) of the EEA Agreement are completed.
• Publication Requirements: The regulation’s Icelandic and Norwegian texts will be published in the EEA Supplement to the Official Journal, guaranteeing authentic, multilingual access.
• Implications for Environmental Monitoring: The updated verification framework enhances data reliability for air, water, and biodiversity monitoring, benefiting research, policy, and industry across the EEA.

Protecting Our Headwaters: A New Act to Safeguard Watersheds and Water Quality

The Headwaters Protection Act of 2025 seeks to strengthen the federal Water Source Protection Program by reauthorizing it through 2033 and expanding its scope to include adjacent non‑Federal lands. The bill emphasizes collaborative stewardship, requiring that projects on neighboring private or public lands be undertaken only with the explicit support of landowners and that non‑Federal partners lead planning and implementation. It also sets clear priorities—risk management for drought, wildfire, and flooding; restoration of aquatic ecosystems; and climate resilience—while mandating the use of nature‑based solutions such as wetland and riparian restoration.

Funding provisions are a key feature of the Act. Each fiscal year from 2025 to 2033, the program will receive $30 million, with at least 10 % earmarked for technical assistance and capacity building for non‑Federal partners. The legislation also authorizes $30 million annually for watershed condition monitoring and management, ensuring that federal activities do not degrade watershed health or lower watershed classifications.

Importantly, the Act clarifies that it does not alter existing state or federal water laws, interstate compacts, or treaty obligations, nor does it grant the federal government authority to acquire or control non‑Federal land. Instead, it promotes partnership, transparency, and science‑based decision making to protect the nation’s vital water resources.

Key Elements

• Reauthorization of the Water Source Protection Program through 2033 with expanded responsibilities.
• Inclusion of adjacent non‑Federal lands in watershed projects, contingent on landowner support and partnership.
• Priority criteria: risk mitigation for drought, wildfire, flooding; aquatic restoration; climate resilience; nature‑based solutions.
• Leadership by non‑Federal partners in assessment, planning, design, and implementation.
• Funding: $30 million per year (2025‑2033) for program activities; $30 million per year (2025‑2029) for watershed condition monitoring.
• Partner participation set‑aside: at least 10 % of program funds for technical assistance and capacity building.
• No federal acquisition or control of non‑Federal land; respects existing water laws and agreements.
• Enhanced watershed condition framework to prevent long‑term degradation and maintain watershed classifications.

U.S. Law Aims to Clean Up Gold Trade and Protect Communities

Overview

The United States Legal Gold and Mining Partnership Act (S. 797) establishes a multi‑year strategy to curb the environmental, social, and security harms caused by illicit gold mining across the Western Hemisphere. The bill directs the Secretary of State, in coordination with Treasury, Homeland Security, Justice, Interior, and USAID, to develop a comprehensive plan that targets the linkages between artisanal and small‑scale mining (ASM), transnational criminal networks, and the financing of illicit actors. It also seeks to strengthen environmental safeguards, promote responsible sourcing, and support the formalization of ASM operations.

The Act requires the strategy to be submitted to Congress within 180 days of enactment, with semiannual briefings for three years, and mandates a classified briefing on Venezuelan gold trafficking within 90 days. It authorizes $10 million for the State Department to implement the strategy and calls for international cooperation, including public‑private partnerships modeled on Switzerland’s Better Gold Initiative, to trace and certify gold supply chains.

By combining law‑enforcement, financial‑sanctions, capacity building, and market‑based incentives, the legislation aims to reduce the flow of illicit gold, protect vulnerable communities, and restore confidence in the global gold market.

Key Elements

• Multi‑agency coordination: State, Treasury, DHS, DOJ, Interior, and USAID jointly develop and implement the strategy.
  
• Targeting illicit actors: Interruption of ASM linkages to criminal groups, drug traffickers, and terrorist organizations; sanctions on Venezuelan officials involved in gold trafficking.
  
• Environmental safeguards: Prevention of mining in protected areas; reduction of mercury, cyanide, and other hazardous substances; protection of water, soil, and forest ecosystems.
  
• Formalization of ASM: Licensing, training, financing, and compliance assistance for miners to transition from informal to regulated operations.
  
• Responsible sourcing and due diligence: Promotion of traceability, certification, and adherence to OECD and other international standards for gold supply chains.
  
• Anti‑money‑laundering measures: Strengthening customs, financial intelligence units, and customs enforcement to detect and disrupt gold‑related money laundering.
  
• Public‑private partnership: Collaboration with Swiss Better Gold Initiative and regional governments to build transparent, responsible gold value chains.
  
• Reporting and oversight: 180‑day strategy submission, semiannual congressional briefings, and a 90‑day classified briefing on Venezuelan gold trafficking.
  
• Funding: $10 million authorized for the State Department to support strategy implementation.

Utah Wildfire Research Institute Act of 2025: Building a State‑Level Hub for Fire Science

Overview

The Utah Wildfire Research Institute Act of 2025 amends the Southwest Forest Health and Wildfire Prevention Act of 2004 to create a new research institute dedicated to wildfire science in Utah. By adding Utah to the list of states that can host a federally funded institute, the bill expands the national network of wildfire research centers, enabling closer collaboration between federal agencies, universities, and local stakeholders.

The act’s primary goal is to strengthen Utah’s capacity to study fire behavior, forest health, and mitigation strategies. It will facilitate data sharing, technology development, and training programs that help communities adapt to increasingly frequent and intense wildfires. The legislation also aligns with broader climate‑adaptation efforts, ensuring that research resources are directed toward the most vulnerable ecosystems.

At present, the bill has been read twice in the Senate and has been referred to the Committee on Energy and Natural Resources. It awaits further deliberation and potential amendments before it can become law.

Key Elements

• Creation of a Utah Wildfire Research Institute – Establishes a new federally funded research center focused on wildfire science and forest health within Utah.
• Amendment of the 2004 Act – Adds Utah to the list of states eligible to host a wildfire research institute, expanding the national network.
• Enhanced Collaboration – Encourages partnerships among federal agencies (e.g., USDA Forest Service), state agencies, universities, and local communities.
• Research Focus Areas – Includes fire behavior modeling, ecosystem resilience, mitigation technologies, and climate‑impact assessments.
• Funding and Oversight – Provides a framework for federal funding allocation and oversight, ensuring accountability and alignment with national wildfire prevention goals.
• Policy Alignment – Supports broader climate adaptation and land‑use planning initiatives by integrating scientific findings into policy and practice.

Expanding Sloan Canyon Conservation Area While Granting Pipeline Rights‑of‑Way

The Sloan Canyon Conservation and Lateral Pipeline Act seeks to enlarge the Sloan Canyon National Conservation Area in Nevada by nearly 9,300 acres, while simultaneously allowing the Southern Nevada Water Authority to construct and operate a water pipeline that runs adjacent to the expanded boundary. The bill amends the original conservation act to replace the 2002 boundary map with a 2024 proposal and increases the protected acreage from 48,438 to 57,728 acres. It also creates a new right‑of‑way provision that permits the water authority to excavate, use, and dispose of materials from the pipeline construction without paying rents, subject to a memorandum of understanding with the Bureau of Land Management.

Key provisions balance conservation goals with infrastructure needs. The pipeline right‑of‑way is limited to the area outside the conservation boundary, and the authority may only use materials from the tunneling process under a negotiated agreement. Conditions require that construction not permanently damage surface resources, avoid wilderness areas, and respect existing utility corridors. Importantly, the act preserves the management framework of the conservation area, ensuring that the expanded land remains subject to the same stewardship rules as before.

Key Elements

• Boundary Expansion: Increase from 48,438 to 57,728 acres; new 2024 map replaces the 2002 map.
  
• Pipeline Right‑of‑Way: Grants the Southern Nevada Water Authority a temporary and permanent right‑of‑way for a water pipeline outside the conservation area, with no rent or charge.
  
• Material Use: Authority may excavate, use, or dispose of sand, gravel, minerals, or other materials from pipeline tunneling without payment.
  
• Memorandum of Understanding: Must be signed within 30 days to identify federal lands where disposal is allowed.
  
• Protection Conditions:
  
  • Must include reasonable terms to protect conservation resources.
    
  • Construction cannot permanently harm surface resources.
    
  • Right‑of‑way cannot traverse wilderness areas.
    
• Utility Corridor Preservation: Existing utility transmission corridors and rights‑of‑way remain valid; new facilities may be authorized under NEPA and other laws.
  
• Management Continuity: The act does not alter the overall management of the conservation area beyond the specified amendments.

Boosting Farmers and Forests: New Emergency Conservation Funding Rules

Overview
The Emergency Conservation Program Improvement Act of 2023 seeks to streamline how agricultural producers and private forest landowners access federal emergency conservation funds. By amending the Agricultural Credit Act of 1978, the bill removes procedural hurdles and expands the types of emergency measures that qualify for assistance, including repairs to fencing, replacement of farmland or conservation structures, and wildfire‑related damage. The legislation also clarifies what constitutes an eligible wildfire, ensuring that both natural and federally caused fires can trigger payments.

The act introduces a more flexible payment structure: producers can receive up to 75 % of the cost for replacement work and 50 % for repair or restoration before the work begins. For private forest owners, the bill allows advance payments of up to 75 % of the cost of emergency measures, with a 180‑day window to spend the funds or return them. These changes aim to reduce administrative delays, provide quicker financial relief, and encourage timely restoration of critical agricultural and forest resources.

Overall, the bill is designed to enhance resilience against natural disasters and other emergencies that threaten farmland and forest lands, thereby supporting the sustainability of the nation’s food and timber supplies.

Key Elements

• Expanded Eligibility

  • Adds “other emergency conservation measures” to Section 401, covering replacement or restoration of farmland or conservation structures beyond fencing.
    
  • Redefines wildfire eligibility to include fires not caused naturally but spread by natural causes, and fires caused by the federal government.

• Payment Structure

  • Producers may receive 75 % of replacement costs and 50 % of repair/restoration costs before work starts, based on fair‑market values from state Field Office Technical Guides.
    
  • Private forest owners can receive advance payments of up to 75 % of emergency measure costs, with a 180‑day spending deadline.

• Administrative Simplification

  • Removes the “option of receiving” clause that previously required producers to wait for approval before beginning work.
    
  • Introduces clear guidelines for payment determination and fund return timelines.

• Wildfire Clarifications

  • Section 407 now explicitly includes wildfires that spread due to natural causes and those caused by federal actions, ensuring broader coverage for wildfire‑related damages.

• Funding Accountability

  • Funds not spent within the 180‑day period must be returned, promoting responsible use of emergency resources.

Boosting Farmers’ and Forest Owners’ Rapid Response to Emergencies

Overview
The Emergency Conservation Program Improvement Act of 2022 seeks to streamline how agricultural producers and private forest landowners access federal funds for emergency conservation measures. By amending the Agricultural Credit Act of 1978, the bill removes procedural hurdles and expands the types of emergency actions that qualify for assistance, including the replacement or restoration of farmland and conservation structures and wildfire‑related damage. The legislation also clarifies the definition of wildfire damage, ensuring that both naturally spread and federally caused fires are covered.

The Act introduces a new payment structure that allows producers to receive a portion of the cost—75 % for replacement and 50 % for repair or restoration—before they carry out the work. For private forest landowners, the bill provides advance payments of up to 75 % of the cost of emergency measures, with a 60‑day window to use the funds or return them. These provisions aim to reduce delays, lower financial risk, and accelerate recovery efforts across the country’s agricultural and forest landscapes.

Key Elements

• Expanded Eligibility: Adds “other emergency conservation measures” and wildfire damage (including non‑natural spread and federally caused fires) to the list of qualifying actions.
  
• Pre‑Work Payments: Farmers can receive 75 % of replacement costs or 50 % of repair/restoration costs before beginning work, based on fair‑market values from state Field Office Technical Guides.
  
• Advance Payments for Forest Owners: Non‑industrial private forest landowners may receive up to 75 % of emergency measure costs upfront, with a 60‑day period to spend or return the funds.
  
• Wildfire Clarifications: Defines wildfire damage to include both naturally spread fires and those caused by federal actions, ensuring broader coverage.
  
• Simplified Administration: Removes the “option of receiving” clause and other procedural language that previously slowed the approval process.
  
• Financial Accountability: Requires unused advance payments to be returned within a reasonable timeframe, maintaining fiscal responsibility.

EU Urges Rapid Relief and Gender Equality After Afghanistan’s Devastating Earthquake

Overview

In October 2025 the European Parliament adopted a resolution demanding urgent humanitarian assistance for the communities in Kunar, Nangarhar and surrounding provinces after a 6.0‑magnitude earthquake on 31 August 2025. The disaster killed more than 2 200 people, destroyed over 6 700 homes and left at least 11 000 families living in tents as winter approaches, creating a severe risk of hypothermia and food insecurity.

The resolution highlights how the Taliban’s strict gender restrictions have amplified the tragedy. Women and girls are disproportionately affected because male volunteers are barred from providing care, and Afghan women are prevented from entering UN compounds or working in humanitarian roles. The lack of female medical professionals and travel restrictions have contributed to a high death toll and hindered medical and psychosocial support.

The Parliament’s resolution calls for the Taliban to lift all restrictions on women, for the EU and Member States to increase humanitarian funding and to coordinate a comprehensive response that includes earthquake‑resistant housing, local health systems, and livelihood support. It also urges accountability measures—sanctions, an independent investigative mechanism, and enforcement of ICC arrest warrants—while stressing the importance of non‑refoulement for displaced Afghans.

Key Elements

• Earthquake impact: 6.0‑magnitude quake, >2 200 deaths, >6 700 homes destroyed, 11 000 families in tents.
• Gender‑based vulnerability: Taliban restrictions on women’s movement and work impede rescue, medical care, and psychosocial support.
• Humanitarian aid: EU has allocated €161 million in 2025; calls for additional emergency funding and flexible, multi‑annual support.
• Infrastructure resilience: Urges investment in earthquake‑resistant housing, local health facilities, and food security programmes.
• Policy and legal actions: Calls for lifting Taliban restrictions, targeted sanctions, asset freezes, and travel bans on Taliban leaders.
• Accountability mechanisms: Supports an independent UN investigative body and the execution of ICC arrest warrants for crimes against humanity.
• Non‑refoulement: Demands that Iran and Pakistan halt deportations of Afghans and respect international refugee law.
• Support for human rights defenders: Encourages assistance for Afghan journalists, activists, and civil society workers seeking protection abroad.
• Regional coordination: Calls for EU engagement with neighboring countries and trusted NGOs to bypass Taliban interference in aid delivery.

Plug Offshore Wells Act: Making Decommissioning Transparent

The Plug Offshore Wells Act requires the U.S. Secretary of the Interior to produce an annual, publicly accessible report on the decommissioning of offshore oil and gas wells, platforms, and pipelines. The bill, introduced in the 119th Congress and referred to the Committee on Energy and Natural Resources, aims to increase transparency and accountability in the offshore energy sector. By mandating detailed data on applications, approvals, and enforcement actions, the Act seeks to inform policymakers, industry stakeholders, and the public about the progress and challenges of retiring offshore infrastructure. The report will cover a range of metrics, including the number of decommissioning applications submitted and received, the count of facilities that have not met required decommissioning deadlines, and the status of enforcement actions such as penalties or disqualifications. It will also detail the lengths of pipelines that have been decommissioned in place or removed. The information will be posted on the Department of the Interior’s website, ensuring that stakeholders can track compliance and identify areas needing regulatory attention.

Key Elements

- Annual Reporting Requirement: The Secretary must submit a comprehensive report each year, starting within two years of enactment. - Scope of Data: The report covers wells, platforms, and pipelines, including application counts, approvals, and non‑compliance incidents. - Enforcement Status: Details on notices of noncompliance, orders, citations, civil penalties, and future operation disqualifications are included. - Pipeline Lengths: Lengths of pipelines decommissioned in place and those removed are reported. - Public Accessibility: All reports are made publicly available on the Department of the Interior’s website. - Regulatory Alignment: The Act references existing federal regulations (e.g., 30 CFR § 250.1700) to define decommissioning and reporting standards.

Dakota Water Resources Act Amendments of 2026: A $1.2 Billion Boost for Tribal and Rural Water Infrastructure

Overview

The Dakota Water Resources Act Amendments of 2026 revise the 1975 Public Law 89‑108 to reauthorize and expand federal funding for water supply projects across North Dakota, with a particular focus on tribal, rural, and industrial needs. The bill earmarks roughly $1.2 billion in new appropriations, indexed for inflation, to complete major water treatment, pipeline, and distribution projects that have been pending for decades.

The amendments also streamline the allocation process by allowing authorized funds to be transferred among projects, subject to a 50 % cap on increases, and require the Secretary of the Interior to produce final engineering reports within two years. These reports will define the scope and technical requirements of each project, ensuring that construction proceeds efficiently and within budget.

In addition to the new appropriations, the bill amends the Natural Resources Trust provisions to broaden the scope of federal support for tribal water systems, reinforcing the commitment to improve drinking water access for Native American communities in the region.

Key Elements

• Total Authorized Funding: Approximately $1.2 billion, indexed for construction cost inflation.
  
• Major Projects
  
  • Northwest Area Water Supply Biota Water Treatment Plant & Pump Station – $120 million.
    
  • McClusky Canal & Missouri River North Alternative – $404 million.
    
  • Southwest Pipeline Project – $50 million for intake, pump station, transmission upgrades, and rural distribution.
    
  • North Dakota Rural Water Districts – $63 million for treatment and distribution expansion.
    
• Tribal Water Systems
  
  • Spirit Lake – up to $118 million.
    
  • Three Affiliated Tribes – up to $275 million.
    
  • Standing Rock – up to $240 million.
    
  • Turtle Mountain – up to $98 million.
    
  • Lake Traverse Feasibility Study & Potential System – $12 million.
    
• Transfer Provisions: Funds may be reallocated among projects, but no single project’s initial authorization may increase by more than 50 %.
  
• Engineering Reports: The Secretary must complete final engineering reports for the Southwest Pipeline and rural water systems within two years of enactment.
  
• Indexing and Cost Adjustments: All major appropriations are indexed to engineering cost indices to account for inflation and construction cost changes.
  
• Natural Resources Trust Amendment: Expands the trust’s authority to include additional tribal water projects, ensuring broader federal support for Native American water infrastructure.

Exploring New Water Horizons: Feasibility Study for Lewis & Clark Regional Water System Expansion

Overview

The Lewis & Clark Regional Water System Expansion Feasibility Study Act directs the U.S. Secretary of the Interior to evaluate whether a new water supply project can extend the Lewis & Clark Rural Water System’s reach into Iowa, Minnesota, and South Dakota. The study will assess technical, environmental, and financial feasibility, and will recommend whether construction should proceed and how costs should be shared between federal and non‑federal partners.

If approved, the project could provide reliable municipal, rural, and industrial water to communities that currently lack adequate supply, potentially boosting local economies and supporting regional development. The bill also establishes a framework for collaboration with state, tribal, and local authorities, ensuring that environmental and land‑use impacts are carefully considered.

The legislation is currently under review by the Senate Committee on Energy and Natural Resources and the House Committee on Natural Resources, with hearings already held. A $10 million appropriation is authorized to fund the study, and the authority to conduct the study expires ten years after enactment.

Key Elements

• Study Mandate: The Secretary of the Interior must conduct a comprehensive feasibility study in partnership with the Lewis & Clark Regional Water System (a non‑federal entity).
  
• Feasibility Report: The report must recommend whether to authorize construction and determine the non‑federal share of construction costs, which must be at least 25 % of total costs, based on the entity’s financial capacity.
  
• Cost‑Sharing for the Study: Federal and non‑federal parties may enter a cost‑sharing or financial assistance agreement, with the federal share capped at 50 % of the study’s total cost.
  
• Funding: Up to $10 million is authorized for the Secretary to carry out the study.
  
• Consultation: The Secretary must consult with federal, state, tribal, regional, and local authorities throughout the study and report preparation.
  
• Time‑Limited Authority: The study authority expires 10 years after the act’s enactment.
  
• Public Availability: The feasibility report and related documents must be made publicly available.
  
• Legislative Status: The bill has passed initial readings and is currently in committee hearings, awaiting further consideration.

Extending the Safe Stash: Mesa County’s Uranium Tailings Site Gets a New Lease

The Responsible Containment Reauthorization Act of 2026 is a concise amendment to the 1978 Uranium Mill Tailings Radiation Control Act. It extends the federal authorization for a uranium mill tailings disposal site in Mesa County, Colorado, beyond its original sunset date. The extension remains in force until the site reaches its designed capacity, ensuring that the site can be fully utilized without interruption.

By removing the fixed expiration clause, the bill guarantees continuous oversight and regulatory compliance for the disposal facility. It preserves the framework for monitoring radiation levels, maintaining containment integrity, and protecting surrounding ecosystems and communities. The legislation also signals Congress’s commitment to responsible stewardship of legacy radioactive waste sites while allowing for orderly completion of the disposal mission.

Key Elements

• Authorization Extension – The bill amends the 1978 Act to keep the Mesa County disposal site authorized until it is filled to its designed capacity, eliminating the previous sunset date.
  
• Continued Regulatory Oversight – The site remains subject to the same federal monitoring, reporting, and safety standards set by the Department of Energy and the Environmental Protection Agency.
  
• Geoscience and Environmental Protection – The extension supports ongoing geologic containment measures, ensuring that tailings are securely isolated from groundwater and surface water pathways.
  
• Stakeholder Confidence – By providing a clear, long‑term authorization, the Act reassures local communities, industry, and environmental groups that the site will be managed responsibly until its purpose is fully met.
  
• Future Flexibility – The amendment allows for potential future adjustments or decommissioning plans once the site reaches capacity, maintaining a pathway for eventual closure and remediation.

Mesa County’s Uranium Tailings Site Gets a New Lease on Life

Overview

The Responsible Containment Reauthorization Act (H.R. 7811) seeks to extend the federal authorization for a uranium mill tailings disposal site in Mesa County, Colorado. By amending the 1978 Uranium Mill Tailings Radiation Control Act (UMTCA), the bill allows the site to remain operational until it reaches its designed capacity, rather than being shut down by a fixed date. This extension is intended to provide a clear, long‑term framework for managing the site’s radioactive waste, ensuring that containment standards are maintained throughout the remaining lifespan of the facility.

The proposal reflects a broader effort to balance the need for responsible waste management with the practical realities of decommissioning and land use. By keeping the site authorized until it is fully utilized, the bill aims to avoid abrupt closures that could compromise environmental safeguards or create uncertainty for local stakeholders. It also underscores the federal commitment to uphold UMTCA’s rigorous safety and monitoring requirements while allowing for a more flexible, capacity‑based approach.

The bill has been referred to the House Committee on Energy and Commerce, where it will be reviewed for its technical merits, environmental impact, and alignment with national radiation protection standards. If approved, it would set a precedent for how other legacy uranium tailings sites might be managed under a capacity‑driven authorization model.

Key Elements

• Extension of Authorization: The bill amends UMTCA to allow the Mesa County disposal site to remain authorized until it reaches its designed capacity, removing the previous fixed expiration date.
  
• Compliance with UMTCA Standards: All existing radiation control, monitoring, and containment requirements remain in force, ensuring continued protection of public health and the environment.
  
• Capacity‑Based Closure: The site will only close when physically filled to its intended capacity, providing a clear, measurable endpoint for site management.
  
• Oversight and Reporting: The Act maintains federal oversight, requiring periodic reporting on site conditions, radiation levels, and compliance with environmental regulations.
  
• Implications for Land Use: By extending the site’s operational period, the bill influences future land‑use planning in Mesa County, potentially affecting local development, agriculture, and recreation.
  
• Precedent for Other Sites: Successful implementation could serve as a model for reauthorizing other uranium tailings disposal sites nationwide, promoting a consistent, science‑based approach to radioactive waste management.

Rural Water 2.0: The FLOWS Act Aims to Digitally Future‑Proof Rural Water Systems

Overview
The Futureproofing Local Operations for Water Systems Act of 2026 (FLOWS Act) establishes a federal grant program to bring advanced digital infrastructure—remote sensing, real‑time monitoring, AI analytics, and industrial control systems—to rural water utilities. By funding design, construction, operation, and maintenance of these technologies, the Act seeks to reduce water loss, improve asset condition assessments, and enhance the overall efficiency of drinking water, wastewater, and stormwater systems in sparsely populated areas.

The legislation earmarks $50 million annually for fiscal years 2027‑2031, prioritizing systems that serve fewer than 3,300 people and those owned or operated by community members or local public bodies. Grants also cover workforce training and cybersecurity measures to protect critical infrastructure from cyber‑attacks.

Beyond funding, the FLOWS Act mandates a five‑year study by the Comptroller General to evaluate the impact of digital technologies on rural water management, followed by a 2030 report to Congress detailing findings and program outcomes. The Act does not alter existing federal or state water laws, ensuring compatibility with current regulatory frameworks.

Key Elements

• Grant Program – Administrator of the EPA will award grants for installing and maintaining digital infrastructure in rural water systems, including drinking water, wastewater, stormwater, desalination, and aquifer recharge projects.
  
• Eligible Entities – Public water system owners/operators, rural areas, and state or tribal governments acting on behalf of these entities.
  
• Prioritization – Focus on systems serving ,300 people and those owned by community members or local public bodies.
  
• Funding – $50 million per year (2027‑2031) available until expended.
  
• Software Acquisition – Grants may cover initial purchase and ongoing maintenance of digital software tools.
  
• Cybersecurity & Training – Grants support on‑site cybersecurity training and workforce development for managing digital infrastructure.
  
• Comptroller General Study – Within five years, assess water loss, fire flow capacity, sewer bottlenecks, and model effectiveness; recommend planning, interoperability, cost reduction, and affordability strategies.
  
• Reporting – 2030 report to Senate and House committees on study results and program performance.
  
• Legal Compatibility – The Act does not waive or limit other applicable federal or state water laws.

Charting New Waters: Study to Expand the Lewis & Clark Regional Water System

Overview

The Lewis and Clark Regional Water System Expansion Feasibility Study Act directs the U.S. Secretary of the Interior to conduct a comprehensive assessment of a proposed project that would extend the Lewis & Clark water system’s reach across Iowa, Minnesota, and South Dakota. The goal is to determine whether the system can be expanded to supply municipal, rural, and industrial users with reliable water, thereby supporting regional growth and resilience.

The Act requires the Secretary to collaborate closely with the non‑Federal project entity—Lewis & Clark Regional Water System, Inc.—and to engage federal, state, tribal, regional, and local partners. After completing the study, the Secretary must produce a feasibility report recommending whether construction should proceed and specifying the non‑Federal share of construction costs, which must be at least 25 % of total expenses. The federal share of the study itself is capped at 50 % of the total cost, with a maximum appropriation of $10 million.

This legislation establishes a 10‑year window for the study and its findings, ensuring that the project’s viability is evaluated within a clear timeframe. The report and related documents will be made publicly available, promoting transparency and stakeholder engagement in the decision‑making process.

Key Elements

• Study Mandate: Secretary of the Interior must conduct a feasibility study in partnership with the Lewis & Clark Regional Water System, Inc.
  
• Feasibility Report: Must recommend whether to authorize construction and determine the non‑Federal share of construction costs (minimum 25 % of total).
  
• Cost‑Sharing Framework:
  
  • Federal share of the study’s costs limited to 50 %.
    
  • Non‑Federal share of construction costs at least 25 %, based on financial capability analysis.
    
• Financial Assistance: Secretary to enter a cost‑sharing or financial assistance agreement with the non‑Federal entity, complying with reclamation feasibility standards.
  
• Appropriations: Up to $10 million authorized for the study.
  
• Consultation: Secretary must coordinate with federal, state, tribal, regional, and local authorities throughout the study.
  
• Public Availability: Feasibility report and related documents must be publicly accessible.
  
• Term: Authority expires 10 years after enactment, providing a defined window for study completion and decision‑making.

DEEP Act: Streamlining Nationwide Dredging Permits to Boost Port Capacity

The Dredging to Ensure the Empowerment of Ports Act (DEEP Act) seeks to simplify and accelerate the permitting process for dredging projects that maintain, expand, or deepen U.S. ports and navigation channels. By authorizing the Secretary of the Army—through the Chief of Engineers—to issue a single nationwide permit (NWP) under the Federal Water Pollution Control Act, the bill replaces a patchwork of state‑level approvals with a unified, streamlined framework. The NWP is designed to be valid for up to ten years, with a clear timeline for proposal, environmental review, and final issuance.

Key implications of the DEEP Act include faster access to port infrastructure improvements, which can enhance trade competitiveness and support economic growth in coastal communities. The bill also maintains environmental safeguards: it requires a concise National Environmental Policy Act (NEPA) review, mandates mitigation standards that are technically and economically feasible, and preserves state water‑quality certification processes with strict response deadlines. By balancing expedited permitting with environmental oversight, the DEEP Act aims to support both infrastructure development and ecological protection.

Key Elements

• Nationwide Permit (NWP): Proposed within 60 days of enactment, valid for up to 10 years, covering all federal and non‑federal dredging projects in navigable waters.
• NEPA Compliance: One environmental impact statement or assessment required; mitigation standards must be feasible and within the Secretary’s jurisdiction.
• State Certification Timelines: Certifying authorities must respond within 14 days; incomplete applications must be clarified within 14 days, and final decisions must be made within one year.
• Permittee Process: Permittees must notify the Secretary of proposed activities; the Secretary must respond within 14 days, approve or deny within 30 days, and provide reasons for denial if applicable.
• Mitigation Flexibility: The Secretary can tailor mitigation requirements to each activity, ensuring they are technically and economically viable.
• Dredged Material Handling: Repeals and amends specific sections of the U.S. Code to exclude dredged material from certain transportation requirements, simplifying disposal logistics.
• Administrative Efficiency: The bill removes the need for separate permits under the Rivers and Harbors Act of 1899, reducing duplication of regulatory oversight.

DEEP Act: Streamlining Nationwide Dredging Permits to Boost Port Operations

The Dredging to Ensure the Empowerment of Ports Act (DEEP Act) seeks to simplify and accelerate the permitting process for dredging projects that maintain, expand, or deepen U.S. ports and navigation channels up to 60 feet. By requiring the Secretary of the Army, through the Chief of Engineers, to propose a single nationwide permit (NWP) under the Federal Water Pollution Control Act, the bill replaces a patchwork of local and regional approvals with a unified framework that still preserves environmental safeguards.

The Act sets a 60‑day window for the Secretary to draft the NWP and a 10‑year validity period, ensuring predictability for port operators and investors. It mandates a streamlined National Environmental Policy Act (NEPA) review—no more than one environmental impact statement or assessment per NWP—while allowing the Secretary to tailor mitigation measures that are technically and economically feasible. State and interstate water quality certification requirements are tightened, with a 14‑day response window and a clear process for incomplete applications, to prevent delays without compromising water‑quality standards.

Overall, the DEEP Act aims to balance rapid port development with responsible stewardship of navigable waters, providing clearer timelines for dredging projects while maintaining rigorous environmental and water‑quality oversight.

Key Elements

• Nationwide Permit (NWP): Proposed within 60 days of enactment; valid up to 10 years; replaces multiple local permits.
  
• NEPA Streamlining: One environmental impact statement or assessment per NWP; mitigation standards must be technically and economically feasible.
  
• Certification Process: State or interstate water quality agencies must respond within 14 days; incomplete applications trigger a 14‑day list of required items.
  
• Permittee Workflow: Notify Secretary of proposed activity; receive completion status within 14 days; final approval or denial within 30 days.
  
• Mitigation Flexibility: Secretary can tailor mitigation requirements per activity, provided they are feasible and within the Secretary’s jurisdiction.
  
• Disposal Guidelines: Secretary issues guidelines for dredged or filled material; EPA may consult but cannot override the Secretary’s determinations.
  
• Legal Clarifications: Clarifies that full compliance with section 404 equates to a grant of permission under the Rivers and Harbors Act of 1899; no additional permits required under section 10 of that Act.
  
• Revisions to Existing Law: Repeals and amends sections of the U.S. Code related to dredged material transportation and disposal to align with the new nationwide framework.

Energy Freedom Act: Fast‑Tracking U.S. Energy Production While Protecting Federal Lands

Overview
The Energy Freedom Act seeks to boost domestic energy output, stabilize prices, and provide regulatory certainty for producers and exporters. By streamlining approvals for natural‑gas pipelines, transmission projects, and offshore leasing, the bill aims to create jobs and strengthen the U.S. energy economy. The Act also emphasizes the importance of predictable leasing on federal lands, including the Outer Continental Shelf, to maintain competition and keep energy costs low.

The legislation introduces a suite of procedural reforms: it mandates annual oil and natural‑gas lease sales in key states, shortens the permitting timeline for drilling, and requires the Secretary of the Interior to approve or deny applications within a fixed period. It also eliminates the need for presidential permits for cross‑border pipelines and sets clear deadlines for the approval of natural‑gas export applications. The bill further prohibits the President from imposing moratoria on new energy leases or withdrawing federal lands from development without congressional authorization.

To balance rapid development with environmental stewardship, the Act reinstates several EPA and NEPA rules, protects navigable waters, and preserves methane emission standards. It also establishes categorical exclusions for certain geothermal exploration projects and allows for non‑competitive hardrock mineral licensing on the Outer Continental Shelf, while maintaining a framework for royalty determination.

Key Elements

• Accelerated approvals for natural‑gas transmission projects and interstate pipelines, with a one‑year deadline for the Federal Energy Regulatory Commission and the Army Corps of Engineers.
  
• Expedited export process: all natural‑gas export applications filed between 2020 and 2025 are deemed approved; new applications receive a 60‑day review period.
  
• Mandatory lease sales: at least four annual oil and natural‑gas lease sales in each of ten key states, with replacement sales if a sale is delayed.
  
• Streamlined drilling permits: a 30‑day decision window, with a 60‑day default approval if no decision is made, and a $6,500 processing fee.
  
• Prohibition on moratoria: the President cannot halt new energy leases or withdraw federal lands from development without congressional approval.
  
• Designation of priority areas for geothermal, solar, and wind leasing on federal lands, with criteria based on economic viability and existing transmission infrastructure.
  
• Reinstated environmental rules: Navigable Waters Protection Rule, Methane Rule, ONRR Valuation Reform, NEPA procedural rule, and Nationwide Permit 12, all protected from modification for 15 years.
  
• Hardrock mineral licensing on the Outer Continental Shelf: non‑competitive licenses with royalty rates set by the Secretary, potentially at 0 % to encourage competition.
  
• No presidential permit required for cross‑border pipelines or electric transmission facilities, reducing executive bottlenecks.
  

These provisions collectively aim to accelerate U.S. energy development while maintaining clear environmental safeguards and federal land protections.

North Dakota Trust Lands Completion Act: A New Chapter for Tribal Land and Mineral Rights

The North Dakota Trust Lands Completion Act of 2026 (H.R. 2252) is a comprehensive land‑exchange framework that allows the state to relinquish its land‑grant parcels—particularly those within Indian reservations—in exchange for federal land of equal value. The act seeks to restore land and mineral resources to North Dakota’s Indian tribes while ensuring that all exchanges are conducted fairly, transparently, and with respect for environmental and tribal rights. By establishing clear procedures for valuation, environmental review, and tribal consultation, the legislation aims to balance state interests, federal land management, and the sovereignty of tribal nations.

Key provisions of the act include a structured process for selecting federal land, mandatory appraisals to guarantee equal value, and safeguards that protect existing mineral leases and grazing agreements. The act also requires hazardous‑materials inspections, public disclosure of appraisals, and the continuation of grazing permits on transferred lands. Importantly, the legislation preserves treaty‑reserved rights and existing trust lands, ensuring that the exchange does not undermine tribal sovereignty or alter pre‑existing legal arrangements.

Key Elements

• Relinquishment & In‑Lieu Selection

  • State may relinquish land‑grant parcels within reservations in exchange for federal land of substantially equal value.
    
  • Exchanges can occur in single or multiple phases, with the Secretary approving selections within 180 days.

• Valuation & Appraisal

  • Independent appraisers jointly selected by the Secretary and the State determine land values.
    
  • Equalization payments or ledger accounts may be used if values differ, capped at 25 % of the federal land’s value.

• Environmental & Hazardous‑Material Review

  • The Secretary may conduct environmental reviews; hazardous‑material certifications are required before conveyance.
    
  • Public inspection of final appraisals is mandated 30 days before exchange.

• Tribal Consultation & Trust

  • The Secretary and State must consult affected tribes under Executive Order 13175.
    
  • Portions of relinquished land within reservations can be taken into trust for tribal benefit.

• Grazing Permits & Land Use

  • Existing grazing leases and permits continue for the remainder of their terms.
    
  • Grazing rights may be canceled or modified if land is transferred for non‑grazing purposes.

• Withdrawal of Federal Land

  • Selected federal land is withdrawn from public‑land, mining, and mineral‑leasing statutes during the exchange process.

• Protection of Indian Rights

  • The act does not alter treaty‑reserved rights, existing trust lands, or individual allotments.
    
  • All conveyed lands remain subject to applicable federal, state, and tribal laws.

• Miscellaneous Provisions

  • Hazardous‑material records must be made available for inspection.
    
  • The act includes a savings clause preserving ongoing litigation over land ownership.

Unlocking Paducah Land: A New Path for Community Use

Overview

The Senate has approved a bill that will lift deed restrictions on a 3.6‑acre parcel of land in Paducah, Kentucky, currently held by the U.S. government and transferred to the city in 2012. The move is intended to streamline future use of the property while preserving its public‑service character.

The Secretary of the Interior will execute the necessary legal instruments to remove all easements, covenants, and other restrictions recorded in the 2012 quitclaim deed. However, the removal is conditional: the city may not sell the parcel to any entity other than the Oscar Cross Boys & Girls Club of Paducah, and if the club acquires it, it must first offer the land back to the Secretary before transferring it elsewhere. The land must also remain suitable for public use or recreation.

This action reflects a broader trend of repurposing federal lands for local community benefit, balancing development potential with safeguards that keep the property aligned with public interests.

Key Elements

• Removal of Deed Restrictions – The Secretary of the Interior will eliminate all easements, covenants, and conditions recorded in the 2012 quitclaim deed.
  
• Conditional Transfer – The city may only sell or transfer the parcel to the Oscar Cross Boys & Girls Club of Paducah.
  
• Re‑offer Clause – If the club acquires the land, it must first offer it back to the Secretary without payment before any other transfer.
  
• Public‑Use Reservation – Any new development must remain compatible with public use or recreation purposes.
  
• Land Description – The parcel is approximately 3.62 acres at 2956 Park Avenue, part of the Paducah Memorial Army Reserve Center, including existing improvements.
  
• Legislative Status – The bill has been reported favorably by the Committee on Energy and Natural Resources and is pending final passage.

Reauthorizing Earthquake Resilience: 2025 Act Strengthens Building Safety, Early Warning, and Tribal Partnerships

The National Earthquake Hazards Reduction Program Reauthorization Act of 2025 updates and expands the 1977 law that governs U.S. efforts to reduce earthquake damage. The bill broadens the program’s geographic scope to include tribal jurisdictions, revises findings to reflect the high economic risk of earthquakes, and adds new data on annual losses and exposure. It also clarifies that the program’s purpose now explicitly covers “buildings and infrastructure” and “housing and care facilities for vulnerable populations,” underscoring a shift toward protecting the most at‑risk communities.

Key programmatic changes focus on proactive risk reduction. The Act requires comprehensive inventories of high‑risk buildings and lifeline infrastructure, promotes retrofitting and performance‑based design, and expands the National Seismic System and early‑warning capabilities. It mandates coordination with FEMA, the U.S. Geological Survey, NOAA, the National Science Foundation, and the National Institute of Standards and Technology, and introduces new guidance on post‑earthquake functional recovery and fire mitigation. The bill also establishes biennial reporting requirements and a prioritized work plan to ensure agencies implement recommendations from recent studies.

Funding for the next five fiscal years is explicitly authorized, with $8.5 million annually for the general program and $92.4 million annually for the U.S. Geological Survey’s Advanced National Seismic System. Additional appropriations are set for the National Science Foundation ($54 million) and NIST ($5.9 million). The Act includes funding controls and deficit‑reduction provisions, ensuring that allocated resources are used strictly for the program’s purposes.

Key Elements

• Expanded jurisdiction: Includes tribal governments in all program activities and findings.
  
• Risk inventory and retrofitting: Requires states, localities, and tribes to inventory high‑risk buildings and lifelines, and to develop cost‑effective retrofitting plans.
  
• Early‑warning system upgrades: Enhances detection, expands coverage, and mandates rapid, multilingual broadcast of alerts in coordination with the FCC.
  
• Functional recovery focus: Introduces new definitions and standards for post‑earthquake reoccupancy and service restoration.
  
• Interagency coordination: Strengthens roles for FEMA, USGS, NOAA, NSF, and NIST, and creates advisory and technical‑assistance committees that include tribal representation.
  
• Seismic performance standards: Replaces “safety” with “performance” in housing standards to reduce damage and accelerate recovery.
  
• Biennial reporting: Requires agencies to submit progress reports every two years, including a prioritized work plan and budget needs.
  
• Funding: Authorizes $8.5 million per year for the program and $92.4 million per year for the Advanced National Seismic System, with additional appropriations for NSF and NIST.
  
• Funding controls: Limits use of funds to authorized amounts and mandates transfer to the Treasury for deficit reduction if appropriations are canceled.

North Dakota Trust Lands Completion Act: A New Path for Land and Mineral Stewardship

Overview

The North Dakota Trust Lands Completion Act of 2025 gives the state the authority to exchange its own land grant parcels—particularly those within Indian reservations—with federal unappropriated land of comparable value. The goal is to restore land and mineral rights to North Dakota tribes while ensuring that the state’s relinquishment is balanced, transparent, and environmentally sound.

The exchange process begins when the state selects a federal parcel. The Secretary of the Interior must approve the selection within 180 days, and the land is then conveyed to the state by patent or deed, not as a sale. In return, the state must relinquish its land grant parcel, which may be taken into trust for the tribe if it lies within reservation boundaries. The act requires environmental reviews when warranted, hazardous‑materials inspections, and consultation with affected tribes under Executive Order 13175.

For the parties involved, the act establishes strict appraisal standards, limits value adjustments to 25 % of the federal parcel’s value, and allows ledger accounts to reconcile any remaining imbalances. Grazing permits and existing leases continue uninterrupted, and the act protects tribal treaty rights and existing trust holdings. Overall, the legislation seeks to balance federal, state, and tribal interests while safeguarding environmental and resource‑management concerns.

Key Elements

• Relinquishment & Selection: State may relinquish a land grant parcel within a reservation in exchange for federal unappropriated land of equal value.
  
• Approval & Conveyance: Secretary must approve the selection within 180 days; federal land is conveyed by patent or deed within 60 days of approval.
  
• Environmental & Hazardous‑Material Review: Optional environmental review; mandatory hazardous‑materials inspection and certification before conveyance.
  
• Tribal Consultation: State and Secretary must consult with affected tribes, and any portion of the relinquished parcel within reservation boundaries is taken into trust for the tribe.
  
• Valuation & Appraisal: Independent appraisals using Uniform Appraisal Standards; low‑value parcels (<$500,000 or <$500/acre) may use simplified appraisals.
  
• Value Equalization: If values differ, the party with the lesser value may pay up to 25 % of the federal parcel’s value or use a ledger account to balance the difference.
  
• Grazing & Lease Continuity: Existing grazing permits, leases, and contracts remain in force; grazing may continue under the same terms for the remainder of the lease.
  
• Protection of Tribal Rights: The act does not alter treaty rights, existing trust holdings, or individual allotments.
  
• Savings Clause: Ongoing litigation over land or mineral ownership is unaffected by the act.

West Texas Wildlife Refuge Plan Stopped: The No FED Act

Overview

The “No FED in West Texas Act” (H.R. 839) seeks to halt the implementation of the 2023 Land Protection Plan for the Muleshoe National Wildlife Refuge in West Texas. By prohibiting the Secretary of the Interior from finalizing, administering, or enforcing the plan, the bill effectively blocks any federal expansion or designation of additional protected land within the refuge’s boundaries.

The legislation was introduced by Representative Arrington on January 31, 2025, and has been referred to the Committee on Natural Resources. It was reported with an amendment on January 8, 2026 and is now placed on the Union Calendar (No. 374), awaiting further consideration by the full House.

For stakeholders in geoscience, energy, and natural resource management, the bill represents a significant shift in land‑use policy. It preserves the current land status for local ranchers, oil and gas operators, and other users, while limiting federal oversight that could restrict development or alter habitat management practices.

Key Elements

• Prohibition Scope: The Secretary of the Interior may not finalize, implement, administer, or enforce the 2023 “Final Land Protection Plan & Environmental Assessment” for Muleshoe National Wildlife Refuge.
  
• Targeted Plan: The bill specifically references the U.S. Fish and Wildlife Service’s published plan, which outlined proposed expansions and conservation measures.
  
• Agency Impact: The U.S. Department of the Interior and its sub‑agencies (e.g., Fish and Wildlife Service) are barred from carrying out any actions related to the plan.
  
• Land‑Use Consequences: Federal designation of additional protected land is halted, potentially allowing continued or expanded energy, mineral, and agricultural activities on the refuge’s surrounding lands.
  
• Conservation Implications: Wildlife habitat protection measures proposed in the plan—such as buffer zones, species monitoring, and habitat restoration—will not be enforced under federal authority.
  
• Legislative Status: Currently on the Union Calendar (No. 374) for the 119th Congress, second session, pending further House action.
  
• Local Stakeholder Effects: Ranchers, oil and gas companies, and local governments may experience fewer federal restrictions, while conservation groups may see a setback in habitat protection efforts.

Fast‑Track Firefighters: Direct Hire Authority to Strengthen Wildland Firefighting

Overview
The “Direct Hire To Fight Fires” bill amends federal law to give the Secretaries of Agriculture and Interior the power to appoint qualified individuals directly to wildland firefighting and support roles in the Forest Service and other Interior agencies, bypassing the usual competitive hiring process. The move is aimed at filling critical gaps in the workforce that has struggled to keep pace with increasing wildfire activity across the United States.

The legislation also requires the Secretaries, in partnership with the Office of Personnel Management, to implement streamlined hiring policies within one year of enactment. These policies are designed to cut hiring time, eliminate redundant steps, and make it easier for firefighters to transfer between agencies, thereby improving readiness and flexibility on the front lines.

To ensure accountability, the bill mandates annual reports to relevant congressional committees and public disclosure of workforce needs, hiring plans, vacancies, and barriers. These reports will help Congress monitor progress, identify challenges, and recommend further reforms to support the nation’s wildland fire management efforts.

Key Elements

• Direct Hire Authority – Secretaries can appoint individuals to specified firefighting and support positions without following standard competitive hiring rules.
  
• Covered Positions – Includes forestry technicians, aircraft operators, administrative support, natural resource managers, aviation specialists, equipment operators, dispatchers, and other series tailored for wildland firefighting.
  
• Streamlined Hiring Timeline – Policies to reduce hiring time and eliminate redundancies must be in place within one year of the bill’s enactment.
  
• Transfer Facilitation – Measures to lower barriers for firefighters moving between agencies are required.
  
• Annual Reporting – Each Secretary must submit a detailed report (by February 1 each year) covering staffing needs, hiring events, current personnel, vacancies by state, implementation status, and recommendations.
  
• Transparency – Reports are to be published on a public website and made available to Congress, ensuring oversight and public access to workforce data.
  
• Stakeholder Coordination – Implementation involves collaboration with the Office of Personnel Management and oversight by multiple House and Senate committees.

U.S. Tax Bill Aims to Ease Double‑Tax Burden for Taiwanese Residents

The United States‑Taiwan Expedited Double‑Tax Relief Act (S. 199) seeks to reduce the U.S. tax burden on residents of Taiwan who earn income from U.S. sources. The bill amends the Internal Revenue Code to create a new section—Section 894A—that provides lower withholding rates and special tax treatment for interest, dividends, royalties, wages, and certain entertainment or athletic income. It also establishes a framework for negotiating a formal U.S.–Taiwan tax agreement, ensuring that the relief is consistent with U.S. tax law and that reciprocal benefits are granted.

Key provisions include a 10 % withholding rate on most U.S. source income for qualified Taiwanese residents, with a 15 % rate for dividends that meet specific ownership criteria. Qualified wages earned by Taiwanese employees who are not U.S. residents—or who work on international ships or aircraft—are exempt from U.S. withholding. Income from entertainment or athletic activities that does not exceed $30,000 in a year is also exempt, unless it is effectively connected to a U.S. permanent establishment.

For businesses, the bill simplifies the treatment of U.S. permanent establishments owned by Taiwanese entities. It reduces the branch‑profit tax rate from 30 % to 10 % for qualified Taiwanese corporations and adjusts the calculation of effectively connected income. The legislation also sets out procedures for the President to negotiate a formal tax agreement, with required congressional notifications, approvals, and implementation steps.

Key Elements

• Special withholding rates

  • 10 % on most U.S. source interest, dividends, royalties, and other income for qualified Taiwanese residents.
    
  • 15 % on qualifying dividends that meet ownership thresholds; 10 % for dividends paid to Taiwanese corporations.

• Exemptions for wages and services

  • No withholding on wages earned by Taiwanese residents who are not U.S. residents or who work on international vessels or aircraft.
    
  • Entertainment or athletic income under $30,000 per year is exempt, unless effectively connected to a U.S. permanent establishment.

• Treatment of U.S. permanent establishments

  • Qualified Taiwanese corporations with a U.S. permanent establishment are taxed at a 10 % branch‑profit rate instead of 30 %.
    
  • Income effectively connected with the permanent establishment is calculated under a simplified formula.

• Framework for a U.S.–Taiwan tax agreement

  • President authorized to negotiate an agreement that mirrors U.S. model tax conventions.
    
  • Requires congressional notification, briefing, approval legislation, and implementing legislation before the agreement can take effect.

• Reciprocity and implementation

  • The bill applies only if Taiwan provides reciprocal benefits to U.S. persons.
    
  • The Treasury must issue regulations to clarify definitions, record‑keeping, and withholding procedures.

• Impact on trade and investment

  • Lower withholding and simplified tax rules are intended to encourage Taiwanese investment in U.S. energy, mineral, and natural‑resource sectors, as well as broader trade and service activities.

Florida’s Myakka River Gains National Wild & Scenic Status

The Myakka Wild and Scenic River Act of 2025 proposes to add a 34‑mile stretch of the Myakka River in Sarasota County, Florida, to the National Wild and Scenic Rivers System. The bill, currently referred to the House Committee on Natural Resources, builds on a prior study that found the river eligible for federal protection and follows Florida’s own state‑level designation and protection act. By designating the river as a national resource, the Act seeks to preserve its ecological integrity, enhance recreational opportunities, and strengthen coordination among federal, state, and local agencies. If enacted, the designation would establish a comprehensive management plan developed by the Myakka River Management Coordinating Council, a partnership that includes state and local governments, landowners, and environmental groups. The plan would guide land‑use decisions, habitat restoration, and public access while ensuring that existing public and private land management authorities remain unchanged. The federal role would be limited to cooperative agreements and technical assistance, with no acquisition of land by condemnation.

Key Elements

- Designation: 34 miles of the Myakka River in Sarasota County added to the National Wild and Scenic Rivers System. - Segment Classification: Portions labeled as scenic, wild, or recreational to reflect varying levels of protection and use. - Management Plan: A comprehensive plan developed by the Myakka River Management Coordinating Council satisfies federal requirements. - Cooperative Agreements: The Secretary of the Interior may enter agreements with Florida’s Department of Environmental Protection, local governments, and nonprofits to administer the river. - Limited Land Acquisition: The federal government may only acquire land by donation or consent; condemnation is prohibited. - Technical Assistance: Federal support for updating and implementing the management plan, including staff and funding. - Council Structure: The National Park Service adds a representative to the existing council; additional stakeholders may join under state law. - Public and Private Land Management: Existing land‑ownership and management arrangements remain unaffected by the federal designation.

Boosting Farmers and Forests: New Act Lowers Funding Hurdles for Emergency Conservation

Overview
The Emergency Conservation Program Improvement Act of 2025 seeks to streamline how agricultural producers and private forest landowners access federal funds for emergency repairs and restoration. By amending the Agricultural Credit Act of 1978, the bill removes procedural barriers and introduces advance payment options, enabling quicker, more flexible responses to crises such as wildfire damage, flooding, or infrastructure failure. The legislation also expands the scope of eligible emergency measures, adding “Other Emergency Conservation Measures” to the fencing category and clarifying wildfire coverage.

The Act’s provisions allow producers to receive up to 75 % of the fair‑market value of replacement costs or 50 % of repair costs before the work is completed, reducing the upfront financial burden. For private forest owners, the bill introduces a 75 % advance payment for emergency forest restoration, with a 180‑day window to use the funds or return them. These changes aim to enhance resilience in rural landscapes, protect soil and water resources, and support sustainable land management practices.

Key Elements

• Expanded Eligibility – “Other Emergency Conservation Measures” added to the fencing category, broadening the types of projects that can receive federal support.
  
• Advance Payment Options –
  
  • Fencing & Replacement: Producers may receive up to 75 % of the fair‑market value before replacement.
    
  • Repair: Producers may receive up to 50 % of the fair‑market value before repair.
    
  • Forest Restoration: Nonindustrial private forest owners can receive up to 75 % of the cost of emergency measures, with a 180‑day return period if unused.
    
• Wildfire Coverage Clarification – Wildfires not caused naturally, including those initiated by federal agencies, are now explicitly covered under the emergency conservation program.
  
• Administrative Simplification – The bill redesignates and reorganizes subsections of Sections 401 and 407 of the Agricultural Credit Act, making the application and payment process more straightforward for landowners.
  
• Policy Status – The motion to reconsider was laid on the table and agreed to without objection, indicating bipartisan support and a clear path toward enactment.

Colorado Lands Get Official Survey Filing: What It Means for Resource Management

Overview
The U.S. Bureau of Land Management (BLM) has announced the official filing of several cadastral plats of survey in Colorado. These surveys, completed at the request of the BLM, the National Telecommunications and Information Administration, and the U.S. Forest Service, provide precise boundary data for public lands that are critical for managing natural resources, infrastructure, and environmental protection. The filing process ensures that the survey records are formally recorded in the BLM’s land management system, making them available for future planning, permitting, and legal use.

The notice sets a firm filing date of May 15, 2026, and invites any interested parties to submit protests by that deadline. Protests must be filed with the BLM Colorado State Office and must identify the specific plat(s) in question. If a protest is received on time, the filing is paused until the protest is resolved; otherwise, the plat(s) will be officially recorded the following business day. This procedure safeguards the rights of landowners, developers, and other stakeholders while maintaining the integrity of the land management record.

Access to the survey records is straightforward: copies can be requested from the BLM’s public room in Lakewood, CO, for a fee, while the plats themselves can be viewed free of charge at the Denver Federal Center. The notice also provides contact information for the BLM’s Chief Cadastral Surveyor and details on how to file a protest, ensuring transparency and public participation in the land management process.

Key Elements

• Official Filing Date: May 15, 2026 (with a pause for any timely protests).
  
• Lands Covered:
  
  • Sixth Principal Meridian: Section 20, Township 8 S, Range 91 W; Section 2 N, Range 70 W.
    
  • New Mexico Principal Meridian: Section 46 N, Range 12 E; Sections 7 and 18, Township 35 N, Range 8 W.
    
• Agencies Involved: BLM, National Telecommunications and Information Administration, U.S. Forest Service.
  
• Protest Process: Written notice required by May 15, 2026; must specify the plat(s) and include reasons within 30 days.
  
• Public Access: Survey records available for purchase; plats viewable free at the BLM public room.
  
• Contact: David W. Ginther, BLM Chief Cadastral Surveyor for Colorado (phone: 970‑826‑5064, email: provided).
  
• Legal Basis: Authority under 43 U.S.C. Chap. 3.

Texas LNG Expansion Seeks 25‑Year Export License to Global Markets

Overview

The U.S. Department of Energy (DOE) has received an application from Corpus Christi Liquefaction Stage IV (CCL Stage IV) to obtain a long‑term authorization to export liquefied natural gas (LNG) to countries that are not part of U.S. free‑trade agreements. The proposed expansion—known as the Stage 4 Project—would add four new liquefaction trains, two storage tanks, a third marine berth, and additional infrastructure to the existing Corpus Christi LNG terminal in San Patricio and Nueces Counties, Texas. CCL Stage IV seeks permission to export LNG at a volume equivalent to approximately 1,200 billion cubic feet per year (Bcf/yr) for a 25‑year term beginning when the facility becomes commercially operational.

The application is filed under the Natural Gas Act (NGA) and will be evaluated by DOE’s Hydrocarbons and Geothermal Energy Office. DOE must also satisfy the National Environmental Policy Act (NEPA) requirements, meaning an environmental review will accompany the licensing decision. The public comment period for the application runs until 4:30 p.m. Eastern Time on June 15, 2026, after which DOE will consider protests, motions to intervene, and written comments before issuing a final order.

If approved, the expansion would significantly increase U.S. LNG export capacity, potentially boosting trade revenues and creating jobs in the Gulf Coast region. However, stakeholders—including environmental groups and local communities—will scrutinize the project’s environmental impacts, such as coastal ecosystem effects, greenhouse‑gas emissions from flaring, and the broader implications of expanding fossil‑fuel infrastructure.

Key Elements

• Export Volume & Term: 1,200 Bcf/yr of LNG, 25‑year authorization starting commercial operation.
  
• Project Scope: Four new liquefaction trains, two storage tanks, a third marine berth, and supporting infrastructure on land owned by Cheniere Land Holdings.
  
• Location: San Patricio and Nueces Counties, Texas, adjacent to the existing Corpus Christi LNG terminal.
  
• Legal Basis: Application filed under the Natural Gas Act (NGA) § 3(a) for non‑FTA countries; separate review for FTA countries.
  
• Environmental Review: DOE must comply with NEPA, assessing impacts on coastal ecosystems, emissions, and other environmental factors.
  
• Public Participation: 60‑day comment period ending June 15, 2026; protests and motions to intervene are allowed.
  
• Stakeholders: CCL Stage IV, Cheniere Marketing, Cheniere Land Holdings, DOE Hydrocarbons and Geothermal Energy Office.
  
• Economic Implications: Potential for increased export revenue, job creation, and enhanced U.S. energy security.
  
• Potential Concerns: Environmental effects of expanded LNG operations, greenhouse‑gas emissions, and regulatory compliance.

FERC Opens Public Review of New Natural‑Gas Pipeline to Power Missouri’s Big Hollow Energy Center

Overview
The Federal Energy Regulatory Commission (FERC) has released an Environmental Assessment (EA) for the Ameren‑EMRT Big Hollow Project, a proposed 9.6‑mile, 20‑inch natural‑gas pipeline that would run from EMRT’s existing mainlines in Monroe County, Illinois, to the Big Hollow Energy Center in Jefferson County, Missouri. The pipeline is intended to deliver roughly 200,000 million standard cubic feet of natural gas per day to support a new gas‑fired generation facility that will replace the retired Rush Island Energy Center.

The EA, prepared under the National Environmental Policy Act (NEPA), concludes that the project would not constitute a major federal action significantly affecting the quality of the human environment. It evaluates potential impacts, explores reasonable alternatives, and recommends mitigation measures, but it is not a decision document. FERC will use the EA’s findings, along with economic and public‑convenience considerations, to decide whether to issue a Certificate of Public Convenience and Necessity for the pipeline.

Stakeholders—including federal, state, and local agencies, elected officials, environmental groups, Native American tribes, and landowners—have been notified and are invited to submit comments. The public comment period closes at 5:00 p.m. Eastern Time on May 11, 2026. Comments should focus on the EA’s discussion of environmental effects, alternatives, and mitigation options.

Key Elements

• Project scope: 9.6‑mile, 20‑inch lateral pipeline plus a measurement and regulation station and associated appurtenant facilities.
  
• Purpose: Supply 200,000 Mcf/d of natural gas to Ameren’s Big Hollow Energy Center, enabling new gas‑fired generation to replace the retired Rush Island plant.
  
• Environmental assessment outcome: Project deemed not a major federal action under NEPA; no significant adverse environmental impacts identified.
  
• Alternatives considered: EA evaluates alternative routes, pipeline sizes, and generation options, recommending the chosen design as the most balanced solution.
  
• Mitigation measures: Includes construction best practices, habitat restoration plans, and monitoring protocols to minimize impacts on water, wildlife, and land use.
  
• Public participation: Comments due by May 11, 2026; FERC encourages electronic filing via eComment or eFiling, with paper options available.
  
• Regulatory context: FERC is the lead federal agency for interstate natural‑gas transmission under the Natural Gas Act of 1938 and for preparing the EA. The final decision will weigh both economic necessity and environmental effects.

Savannah River Site Opens Doors: Community Advisory Board Meets to Shape Cleanup and Land Use

Overview

The U.S. Department of Energy’s Environmental Management Site‑Specific Advisory Board (EM SSAB) for the Savannah River Site has announced an open meeting scheduled for May 19, 2026. The gathering will take place in person at the Advanced Manufacturing Collaborative in Aiken, South Carolina, and will also be streamed live on YouTube, allowing broad public participation without the need for prior registration.

The EM SSAB serves as a forum for local residents, stakeholders, and experts to provide advice and recommendations on a range of environmental management activities at the Savannah River Site. These include ongoing cleanup operations, waste management and disposition, the future use of excess facilities, long‑term stewardship plans, and budget priorities. By convening this board, the Department of Energy fulfills public‑participation requirements under key environmental statutes such as CERCLA, RCRA, and various federal facility agreements.

The meeting is fully open to the public, with a dedicated 15‑minute window for oral or written comments. Written submissions received at least two working days before the meeting will be shared with board members and incorporated into the minutes. The Department has also committed to accommodating participants with disabilities and has provided contact information for special accommodations and further inquiries.

Key Elements

• Meeting Date & Time: Tuesday, May 19, 2026, 9 a.m.–4 p.m. EDT
  
• Location & Livestream: Advanced Manufacturing Collaborative, 4345 Trolley Line Road, Aiken, SC; live stream on YouTube (link on the DOE website)
  
• Agenda Topics (subject to change):
  
  • Chair update
    
  • Agency updates
    
  • Program presentations to the board
    
  • Board business
    
  • Public comments
    
• Public Participation:
  
  • 15‑minute oral comment period (minimum 2 minutes per speaker)
    
  • Written comments accepted up to 2 working days before or after the meeting
    
  • No prior registration required
    
• Accessibility & Accommodations:
  
  • Designated Federal Officer ensures orderly conduct and accessibility
    
  • Special accommodations for disabilities must be requested at least 7 days in advance
    
• Legal Frameworks:
  
  • Board fulfills public‑participation obligations under CERCLA, RCRA, Federal Facility Agreements, Consent Orders, and Settlement Agreements
    
• Contact Information:
  
  • James Tanner, Office of External Affairs, Savannah River Operations Office (phone: (803) 646‑2167)
    
  • Additional agenda details via Juanita Campbell (contact not provided in the excerpt)
    
• Minutes & Records:
  
  • Meeting minutes will be posted on the DOE website following the session
    
• Signatories:
  
  • Document signed by David Borak, Committee Management Officer, and authorized by the Secretary of Energy; published in the Federal Register on April 14, 2026.

Texas Eastern Plans $39 Million Gulf Pipeline Decommissioning – Public Can Protest by June 9

Overview
Texas Eastern Transmission, LP has filed a request with the Federal Energy Regulatory Commission (FERC) to abandon a 13.45‑mile stretch of its 24‑inch Line 40‑B‑4‑D that lies in federal waters of the Gulf of Mexico near Louisiana. The line is currently idle and no longer required for gas transportation, so the company seeks to remove it in place, eliminating the ongoing maintenance and repair costs that would otherwise accrue. The abandonment is being pursued under FERC’s blanket authorization (Docket CP82‑535‑000) and the Natural Gas Act, with an estimated project cost of $39.6 million.

The notice invites public participation, allowing individuals, organizations, and businesses to file protests, motions to intervene, or comments on the project. All filings must be submitted by 5:00 p.m. Eastern Time on June 9, 2026. No fee is required for protests, interventions, or comments, and the process is designed to give stakeholders a voice before FERC makes a final decision.

Key Elements

• Project scope: Decommissioning 13.45 miles of a 24‑inch pipeline segment (Line 40‑B‑4‑D) in federal Gulf waters near Louisiana.
  
• Method: In‑place removal or capping of the pipeline, with no relocation.
  
• Cost: Estimated at $39.6 million, intended to save the company from future maintenance expenses.
  
• Regulatory basis: Request filed under FERC’s blanket authorization (Docket CP82‑535‑000) and NGA sections 157.²⁰⁵⁄₁₅₇.216.
  
• Public participation deadline: 5:00 p.m. ET, June 9, 2026 for protests, interventions, and comments.
  
• Filing options: Electronic filing via FERC’s eFiling/eComment system or paper submissions to the Commission’s Secretary.
  
• Intervention rights: Intervenors may request rehearing and appeal to U.S. Circuit Courts; they receive all proceeding documents.
  
• Contact points:
  
  • Texas Eastern: Arthur Diestel, Director, Regulatory, 915 North Eldridge Parkway, Houston, TX; phone (713) 627‑5116.
    
  • FERC Office of Public Participation: (202) 502‑6595.
    
• Transparency: Full notice and related documents are available on FERC’s eLibrary in PDF and Word formats.

NRC Streamlines Nuclear Licensing Hearings, Cutting Redundant Environmental Findings

Overview

The U.S. Nuclear Regulatory Commission (NRC) has issued a final rule that revises its rules of practice and procedure to give the agency greater flexibility in conducting mandatory hearings for nuclear licensing. The changes are driven by the Accelerating Deployment of Versatile, Advanced Nuclear for Clean Energy Act of 2024 (ADVANCE Act) and President Biden’s Executive Order 14300, which calls for a modernized, streamlined regulatory framework for nuclear power.

The rule removes two specific environmental‑finding provisions—§§ 51.105 and 51.107—from 10 CFR part 51 and makes corresponding conforming edits in parts 2, 50, 52, and 53. These sections had required presiding officers to make detailed environmental determinations in mandatory hearings, a requirement that the NRC now deems unnecessary because the Atomic Energy Act and the National Environmental Policy Act do not mandate such findings. The rule also clarifies that references to hearings in the regulations apply only to contested proceedings, not to the mandatory hearings required by statute.

The intended outcome is a more efficient licensing process that does not alter safety or environmental standards. The NRC estimates minimal implementation costs and expects the rule to shorten the time required to review and approve new nuclear projects. No new environmental impact assessment is required, and the rule does not impose backfits or issue‑finality constraints.

Key Elements

• Removal of mandatory environmental findings – §§ 51.105 and 51.107 are deleted, eliminating the requirement for presiding officers to make specific NEPA determinations in mandatory hearings.
  
• Clarification of hearing scope – references to hearings in parts 2, 50, 52, and 53 are limited to contested proceedings; mandatory hearings remain governed by the Atomic Energy Act.
  
• No change to safety or environmental standards – the rule does not relax existing safety requirements or alter environmental review processes.
  
• Streamlined procedural language – conforming edits simplify the regulatory text and reduce potential confusion about the role of the Atomic Safety and Licensing Board.
  
• Minimal cost and no backfit – the NRC certifies that the rule will not impose significant economic impacts on small entities and does not trigger backfit or issue‑finality provisions.
  
• No new paperwork or environmental impact assessment – the rule does not create new information collection requirements and is exempt from NEPA review.
  
• Alignment with federal policy – the rule supports the objectives of the ADVANCE Act and Executive Order 14300, promoting a more efficient, modern regulatory framework for nuclear energy.

EU Sets the Course for Smarter Inland Waterways: New River Information Services Directive

Overview

The European Parliament’s resolution on 7 October 2025 adopts a position on a proposed directive that will replace Directive 2005/44/EC, which governs harmonised river information services (RIS) across the EU. RIS is a digital framework that collects, standardises and shares data on inland waterways—such as water levels, flow rates, navigation conditions and environmental quality—to support safe, efficient and environmentally responsible transport.

The resolution confirms the Parliament’s support for the Commission’s proposal, while urging the Commission to bring the matter back to Parliament if it makes substantial changes. It also instructs the Parliament’s President to forward the adopted position to the Council, the Commission and national parliaments, signalling a coordinated legislative process that will culminate in Directive (EU) 2025/2482.

For geoscientists, energy and mineral resource professionals, and those involved in trade and environmental monitoring, the new directive promises a unified data platform that will enhance decision‑making, reduce operational costs, and improve compliance with environmental regulations across the continent’s inland waterway network.

Key Elements

• Adoption of Parliament’s Position – The resolution formally adopts the Parliament’s stance on the RIS directive at first reading.
  
• Conditional Review – Parliament requests the Commission to refer the proposal back to Parliament if it replaces, substantially amends, or intends to substantially amend the draft.
  
• Forwarding to Decision‑Makers – The resolution instructs the Parliament’s President to transmit the position to the Council, the Commission, and national parliaments, ensuring all EU institutions are aligned.
  
• Replacement of Directive 2005/44/EC – The new directive (EU 2025/2482) will supersede the 2005 framework, modernising data standards and interoperability.
  
• Harmonised Data Collection – Standardised protocols for measuring water levels, flow, quality, and navigation conditions across all member states.
  
• Digital Infrastructure – Establishment of a secure, cloud‑based platform for real‑time data sharing among operators, regulators, and stakeholders.
  
• Safety and Efficiency – Improved situational awareness for vessel operators, reducing accidents and delays on inland waterways.
  
• Environmental Monitoring – Enhanced capacity to track pollution, sediment transport and ecological impacts, supporting EU environmental targets.
  
• Trade and Economic Impact – Streamlined logistics and reduced administrative burdens for freight operators, boosting intra‑EU trade via inland routes.
  
• Stakeholder Engagement – Continued consultation with the European Economic and Social Committee, Committee of the Regions, and national parliaments to refine implementation details.

Idaho Cleanup Project Opens Doors: Public Meeting to Shape Environmental Restoration

Overview

The U.S. Department of Energy’s Office of Environmental Management has announced an open meeting of the Environmental Management Site‑Specific Advisory Board (EM SSAB) for the Idaho Cleanup Project (ICP). Scheduled for May 14, 2026, 9 a.m.–4:15 p.m. MDT, the session will take place at the Holiday Inn & Suites in Idaho Falls and will also be streamed via Zoom, allowing residents and stakeholders to participate from anywhere.

The EM SSAB serves as a bridge between the DOE and the local community, offering expert advice on cleanup activities, waste management, facility disposition, future land use, and long‑term stewardship. By convening this board, the DOE fulfills public‑participation requirements under key environmental statutes such as CERCLA, RCRA, and various federal facility agreements, ensuring that local voices help shape decisions that affect Idaho’s environmental health and economic future.

Public engagement is a cornerstone of the meeting. Attendees can submit oral or written comments—up to fifteen minutes of speaking time is reserved for public input. Written comments received at least two working days before the meeting will be shared with board members and incorporated into the minutes. The DOE is committed to accessibility, offering accommodations for participants with disabilities and ensuring that minutes and related documents are readily available after the session.

Key Elements

• Meeting Details

  • Date & time: May 14, 2026, 9 a.m.–4:15 p.m. MDT
    
  • Location: Holiday Inn & Suites, 3005 South Fork Boulevard, Idaho Falls, ID 83402
    
  • Virtual option via Zoom; contact Cecelia Hruska (ICP CAB Administrator) by May 11 to register

• Agenda Highlights

  • Recent public outreach initiatives
    
  • Idaho Cleanup Project progress updates
    
  • Presentations from DOE staff and contractors
    
  • Public comment period
    
  • Board business and future planning

• Public Participation

  • 15 minutes allocated for oral comments; minimum 2‑minute speaking slot
    
  • Written comments due at least two working days before the meeting
    
  • Minutes and documents available via the board’s website and by contacting the CAB Administrator

• Board Responsibilities

  • Provide community‑based advice on cleanup, waste disposition, excess facilities, land use, and stewardship
    
  • Ensure compliance with CERCLA, RCRA, and related federal agreements
    
  • Facilitate transparent communication between DOE and Idaho residents

• Accessibility & Accommodations

  • DOE will accommodate persons with physical disabilities or special needs; requests should be made at least seven days in advance

• Contact & Information

  • Cecelia Hruska, ICP CAB Administrator
    
  • Email: (not provided)
    
  • Phone: (208) 533‑3800
    
  • Board website for agenda, minutes, and additional resources

This meeting offers a vital opportunity for Idaho residents, scientists, and stakeholders to influence the direction of environmental restoration efforts and to stay informed about the DOE’s cleanup progress in the region.

Susquehanna Basin Grants 46 New Water‑Use Approvals for Oil & Gas Operations

Overview

The Susquehanna River Basin Commission (SRBC) has issued a public notice approving 46 oil‑and‑gas projects for consumptive water use during March 2026. “Consumptive use” means water is withdrawn from the basin’s aquifers or surface waters and not returned, thereby reducing the volume available for other uses such as agriculture, recreation, or ecological flow. The approvals, granted under 18 CFR 806.22(f), allow each project to withdraw up to 7.5 million gallons per day (mgd) of water, with several permits capped at 4.0 mgd or 6.0 mgd.

These renewals cover a wide geographic spread across Pennsylvania’s counties—Elk, Bradford, Sullivan, Wyoming, Tioga, Lycoming, Susquehanna, Clinton, and others—reflecting the region’s active hydrocarbon development. The companies involved include Expand Operating LLC, Seneca Resources, Repsol Oil & Gas USA, Coterra Energy, VEC Energy, BKV Operating, and S.T.L. Resources, among others. The notice underscores the SRBC’s role in balancing resource extraction with water‑resource stewardship, ensuring that each project meets federal and state water‑use regulations.

For stakeholders, the document signals that the basin’s water‑use capacity is being expanded to support ongoing energy production. It also highlights the regulatory framework that governs such withdrawals, the need for monitoring and compliance, and the potential cumulative impacts on local water supplies and ecosystems.

Key Elements

• Number of Approvals: 46 renewals for consumptive water use in March 2026.
  
• Water‑Use Limits: Individual permits range from 4.0 mgd to 7.5 mgd, with some at 5.0 mgd or 6.0 mgd.
  
• Geographic Distribution: Projects span 10 Pennsylvania counties, concentrating in the Susquehanna River Basin.
  
• Regulatory Basis: Approvals issued under 18 CFR 806.22(f) (Public Law 91‑575).
  
• Industry Participants: Major oil‑and‑gas operators—Expand Operating, Seneca Resources, Repsol, Coterra, VEC Energy, BKV Operating, and S.T.L. Resources.
  
• Consumptive Use Definition: Water withdrawn for drilling, processing, or other operations and not returned to the basin.
  
• Environmental Oversight: SRBC requires compliance with water‑quality monitoring, reporting, and mitigation measures to protect aquatic ecosystems.
  
• Implications for Water Resources: Potential reduction in available water for agriculture, recreation, and ecological flows; cumulative impacts assessed by the Commission.
  
• Public Transparency: Notice published in the Federal Register (FR Doc. 2026‑07199) and contact information provided for inquiries.
  
• Policy Context: Part of ongoing efforts to regulate water withdrawals in the face of expanding energy development while safeguarding the basin’s long‑term water sustainability.

Susquehanna River Basin Commission Grants Minor Modification: Well 10 Removed from Approved Sources

Overview

The Susquehanna River Basin Commission (SRBC) has issued a notice approving a minor modification to a previously approved water project. The modification concerns Well 10, located in East Cocalico Township, Lancaster County, Pennsylvania. Under the SRBC’s authority, the well is being removed from the list of approved sources, effective March 25, 2026.

This action reflects the Commission’s ongoing effort to keep its records current and to ensure that all water withdrawals remain compliant with federal regulations, specifically 18 CFR 806.18 and relevant Commission Resolutions. By removing the well from the approved sources list, the SRBC is acknowledging that the well no longer meets the criteria for an approved water supply, which may affect local water rights and usage permits.

For stakeholders—including local water users, environmental groups, and geoscience professionals—this notice signals a small but important update to the basin’s water resource inventory. It underscores the Commission’s role in monitoring and adjusting water use to protect the health of the Susquehanna River ecosystem.

Key Elements

• Agency: Susquehanna River Basin Commission
  
• Action: Notice of minor modification approval
  
• Date of Notice: April 10, 2026 (effective March 25, 2026)
  
• Modification: Removal of Well 10 (East Cocalico Township, Lancaster County) from the list of approved water sources
  
• Legal Basis: 18 CFR 806.18, Commission Resolutions Nos. 2013‑11 and 2015‑06
  
• Contact: Jason E. Oyler, General Counsel and Secretary to the Commission (phone: (717) 238‑0423 ext. 1312, fax: (717) 238‑2436, email: [not provided])
  
• Implications: Adjusts water rights and usage permits, updates basin water resource records, and maintains compliance with federal water regulations.

Susquehanna Basin Grants Mine‑Fire Permit to Restore Hanover Reservoir

Overview

The Susquehanna River Basin Commission has issued a General Permit Notice for the month of March 2026, approving a single project under federal water‑use regulations. The permit authorizes the Pennsylvania Department of Environmental Protection’s Bureau of Abandoned Mine Reclamation to extinguish a mine fire at the Hanover Reservoir site in Luzerne County, Pennsylvania. It also allows a limited consumptive water withdrawal of up to 0.068 million gallons per day (30‑day average) from Well 1 to support fire‑suppression activities.

This action demonstrates the Commission’s role in coordinating environmental remediation efforts that involve water resources. By granting the permit, the Commission ensures that the project complies with 18 CFR 806.17©(4) and related federal statutes, while balancing the need for water use with protection of the basin’s aquatic ecosystems.

The notice, published on April 14 2026, provides contact information for further inquiries and confirms the permit’s effective date of March 3 2026. It serves as a formal record of the Commission’s approval and the specific parameters governing the project.

Key Elements

• Permit Authority: 18 CFR 806.17©(4) – General permits for water withdrawals related to environmental remediation.
• Project: Hanover Reservoir Mine Fire extinguishment, Luzerne County, PA.
• Permit Number: GP‑02‑202603022.
• Water Use: Consumptive use up to 0.068 mgd (30‑day average) from Well 1.
• Approval Date: March 3 2026.
• Agency: Susquehanna River Basin Commission, Harrisburg, PA.
• Contact: Jason E. Oyler, General Counsel and Secretary to the Commission (phone: (717) 238‑0423, ext. 1312; fax: (717) 238‑2436; email: [email protected]).
• Implication: Enables controlled water withdrawal for mine‑fire suppression while ensuring compliance with federal water‑use regulations and protecting the Susquehanna River Basin’s environmental integrity.

Susquehanna Basin Grants Grandfathering Status to Two New Quarry Projects

Overview

The Susquehanna River Basin Commission has issued a notice confirming the grandfathering registration of two quarry operations for the month of March 2026. Grandfathering registration allows these projects to continue operating under existing permits without the need for new approvals, provided they meet the conditions set forth in 18 CFR part 806, subpart E. This action supports ongoing mineral extraction activities while maintaining compliance with federal water quality and environmental regulations.

The notice lists the specific projects and their assigned Grandfathering (GF) certificates: Heidelberg Materials Northeast LLC’s Salona Quarry in Lamar Township, Clinton County, and National Limestone Quarry, Inc.’s Paxtonville Facility in Franklin and Beaver Townships, Snyder County. Both certificates were issued in March 2026, with the Salona Quarry receiving its certificate on March 9 and the Paxtonville Facility on March 23. The Commission’s decision is grounded in Public Law 91‑575 and the relevant Code of Federal Regulations, ensuring that the projects continue to operate within the established legal framework.

This registration is part of the Commission’s ongoing effort to balance resource development with environmental stewardship. By grandfathering these operations, the Commission acknowledges the projects’ compliance history while reinforcing the requirement that they adhere to consumptive use and pit sump regulations. Stakeholders, including local communities and industry participants, can rely on this notice for clarity on the projects’ legal status and operational timelines.

Key Elements

• Grandfathering Registration Period: March 1–31, 2026.
  
• Projects Covered:
  
  • Heidelberg Materials Northeast LLC – Salona Quarry (Lamar Township, Clinton County) – GF Certificate GF‑202603312, issued March 9, 2026.
    
  • National Limestone Quarry, Inc. – Paxtonville Facility (Franklin & Beaver Townships, Snyder County) – GF Certificate GF‑202603313, issued March 23, 2026.
    
• Regulatory Basis: 18 CFR part 806, subpart E; Public Law 91‑575, 84 Stat. 1509.
  
• Permit Focus: Active pit sump and consumptive use compliance.
  
• Contact Information: Jason E. Oyler, General Counsel and Secretary, Susquehanna River Basin Commission, Harrisburg, PA.
  
• Implications: Projects may continue operations without new permits, provided they meet existing environmental and water‑quality standards.

US Trade Commission Flags Dumped, Subsidized Graphite Electrodes from China and India

Overview

The U.S. International Trade Commission (ITC) has issued a preliminary determination that large‑diameter graphite electrodes imported from China and India are likely being sold in the United States at less than fair value (dumping) and may also be subsidized by their respective governments. The investigation, initiated by petitions from Resonac Graphite America and Tokai Carbon GE, found that these imports are materially injuring the U.S. graphite electrode industry.

The ITC’s determination triggers the start of the final phase of both the antidumping and countervailing duty investigations. During this phase, the ITC will collect additional evidence, circulate draft questionnaires to interested parties, and ultimately decide whether to impose duties on future imports. The final phase will be scheduled after the U.S. Department of Commerce confirms preliminary findings or after the ITC issues final determinations.

For U.S. manufacturers, exporters, and industry stakeholders, the outcome could mean higher tariffs on imported graphite electrodes, potentially reshaping supply chains and influencing the cost of steel production, which relies heavily on these electrodes. The decision also signals heightened scrutiny of Chinese and Indian industrial exports in sectors critical to U.S. manufacturing and energy infrastructure.

Key Elements

• Preliminary Injury Determination: The ITC found that U.S. graphite electrode producers are materially injured by imports from China and India.
• Dumping and Subsidy Allegations: Imports are alleged to be sold below fair value and may receive government subsidies.
• Final Phase Commencement: The ITC will issue a final‑phase notice after confirmation from the Department of Commerce or upon final determinations.
• Participation Rights: Industrial users, consumer groups, and other parties can appear in the investigation; those who appeared in the preliminary phase need not re‑appear.
• Potential Duties: If the final determination confirms dumping or subsidies, the ITC may impose antidumping or countervailing duties on future imports.
• Impact on Energy and Manufacturing: Graphite electrodes are essential for steel production; higher duties could affect steel costs and downstream energy‑intensive industries.
• Timeline: Final‑phase scheduling will follow the ITC’s rules; parties will receive draft questionnaires via the Electronic Document Information System (EDIS).

USGS Seeks Public Input on Mineral Production Data Collection Renewal

Overview
The U.S. Geological Survey (USGS) has issued a notice to renew an existing information‑collection request under the Paperwork Reduction Act (PRA). The renewal, identified by OMB Control Number 1028‑0065, will continue to gather annual estimates of non‑fuel mineral production from businesses and other for‑profit institutions. The data will feed into the Mineral Commodity Summaries, a key publication that informs government agencies, congressional offices, researchers, industry stakeholders, and the public about the state of the U.S. mineral sector.

The notice invites comments from the public and other federal agencies by May 14, 2026. Respondents are encouraged to address whether the collection is necessary for the USGS’s mineral‑information mission, whether the burden estimate is accurate, and how the agency might improve data quality or reduce respondent effort—particularly through information‑technology solutions. The USGS emphasizes that the collection imposes a voluntary, 15‑minute annual burden and that no non‑hour cost is associated with it.

By soliciting feedback, the USGS aims to refine its data‑collection process, ensuring that the resulting reports remain timely, accurate, and useful for a broad spectrum of users—from policymakers and educators to industry analysts and environmental scientists.

Key Elements

• Renewal of OMB‑approved collection (Control No. 1028‑0065) for annual mineral production estimates.
  
• Target respondents: U.S. non‑fuel mineral consumers (businesses, for‑profit entities).
  
• Voluntary participation with an estimated 15‑minute annual burden and no non‑hour cost.
  
• Data purpose: Feed the Mineral Commodity Summaries, the first preliminary publication covering the previous year’s non‑fuel mineral industry.
  
• Public comment period: Open until May 14, 2026; comments can be submitted online via the Docket No. USGS‑2025‑0171 portal.
  
• Key comment topics: necessity of the collection, timeliness of data processing, burden accuracy, data quality improvements, and use of technology to reduce respondent effort.
  
• Legal authorities: Paperwork Reduction Act, National Materials and Minerals Policy, National Mining and Minerals Policy Act, and Strategic and Critical Materials Stock Piling Act.
  
• Contact: Shonta E. Osborne, USGS Information Collections Clearance Officer (email/phone provided).

HUD Unifies Housing Inspection Standards, Boosts Safety and Energy Efficiency Across HOME and HTF Programs

Overview

The U.S. Department of Housing and Urban Development (HUD) has issued guidance to align the Home Investment Partnerships (HOME) and Housing Trust Fund (HTF) programs with the National Standards for the Physical Inspection of Real Estate (NSPIRE). The goal is to replace the older Housing Quality Standards (HQS) and Uniform Physical Condition Standards (UPCS) with a single, comprehensive set of requirements that cover safety, health, accessibility, energy efficiency, and disaster resilience for all HUD‑assisted housing.

The notice extends the compliance deadline for the NSPIRE rule to October 1 2026 for HOME projects and April 14 2027 for HTF projects, giving jurisdictions and grantees a full year to revise written property standards, train inspectors, and update contracts. It also incorporates the 2025 HOME final rule’s updates—such as new energy‑efficiency mandates, broadband requirements, and expanded carbon‑monoxide and smoke‑detector provisions—into the unified framework.

For homeowners, tenants, and local governments, the change means that new and rehabilitated HUD‑assisted units must meet stricter safety and environmental criteria, be regularly inspected, and be documented in detailed records. The guidance clarifies how to develop written standards, conduct inspections, and maintain compliance records, ensuring that HUD’s investment translates into safer, more sustainable housing for low‑income families.

Key Elements

• Unified Standards – The older HQS and UPCS are replaced by the NSPIRE standards, which set minimum “decent, safe, sanitary, and in good repair” requirements for all HUD‑assisted properties.
  
• Extended Compliance Dates – HOME projects must comply by October 1 2026; HTF projects by April 14 2027, with a 12‑month implementation period for jurisdictions and grantees.
  
• Energy Efficiency – New construction and substantial rehabilitation must meet 2021 IECC or ASHRAE 90.1‑2019 standards (or approved alternatives) as required by Section 109 of the HOME statute, with a one‑year compliance window after the 2024 DOE determination.
  
• Carbon Monoxide & Smoke Detectors – From April 20 2026, all new or rehabilitated units must have hard‑wired smoke alarms (with hearing‑impaired options) and, where applicable, carbon‑monoxide alarms that meet HUD‑approved standards.
  
• Broadband Infrastructure – New multifamily projects must include broadband installation unless infeasible or unduly burdensome, with documented exemptions.
  
• Disaster Mitigation – Property standards must incorporate state or local codes for earthquake, flood, hurricane, and wildfire resilience, encouraging adoption of ICC building code provisions.
  
• Inspection Framework – Written procedures for initial, progress, final, and ongoing inspections are required, with specific frequencies (e.g., annual for TBRA units, every three years for rental projects) and sample‑based checks for larger portfolios.
  
• Recordkeeping & Owner Certification – Detailed inspection reports, cost estimates, and owner certifications of suitability must be maintained, with provisions for third‑party verification of non‑hazardous deficiencies.
  
• Life‑Threatening Deficiencies – Immediate correction is mandated for any health or safety hazard identified during inspections, with more frequent monitoring for affected units.
  
• Accessibility & Lead Paint – All units must meet ADA and Fair Housing Act accessibility requirements and comply with lead‑based paint regulations for pre‑1978 housing.
  

These provisions collectively aim to raise the quality, safety, and sustainability of HUD‑assisted housing while providing clear, enforceable standards for local governments, developers, and homeowners.

North Dakota Pipeline Expansion: WBI Energy Seeks FERC Approval for New 24‑inch Line

Overview

WBI Energy Transmission, Inc. has filed a formal application with the Federal Energy Regulatory Commission (FERC) to construct a 17‑mile, 24‑inch natural‑gas pipeline in North Dakota. The new line will connect WBI’s existing Line Section 32 to a proposed delivery station in Williams County and modify an interconnect at the Northern Border Pipeline in McKenzie County. The expansion is intended to provide an additional 190,000 dekatherms per day of firm transportation service to a new electric‑generation facility, with an estimated cost of $68 million.

The application triggers a comprehensive regulatory review under the Natural Gas Act and FERC’s Part 157 rules. Within 90 days of the notice, FERC staff will either complete an environmental review or issue a schedule for one, which will set the timeline for a final environmental impact statement or assessment. WBI must also secure a water‑quality certificate from the North Dakota Department of Environmental Quality, or demonstrate a waiver, before the pipeline can be authorized.

Public participation is a key component of the proceeding. Stakeholders—including residents, landowners, businesses, and environmental groups—can file comments, protests, or motions to intervene by April 30, 2026. Intervenors gain the right to challenge FERC orders and seek rehearing, while all participants will receive updates through FERC’s eLibrary and eSubscription services.

Key Elements

• Project Scope: 17 mi of new 24‑inch pipeline, new delivery station, and interconnect modification.
  
• Purpose: Deliver 190,000 dekatherms/day to a new power plant in Williams County.
  
• Estimated Cost: $68,087,052, to be financed using existing FT‑1 recourse rates.
  
• Regulatory Path: Application under NGA §7© and FERC Part 157; environmental review required within 90 days.
  
• Water‑Quality Certification: Must obtain a Section 401 Clean Water Act certificate from ND Dept. of Environmental Quality.
  
• Public Participation:
  
  • Comments, protests, and motions to intervene accepted until 5 p.m. ET, April 30, 2026.
    
  • No filing fee; electronic filing via eComment or eFiling, or paper submissions.
    
  • Intervenors can request rehearing and appeal to U.S. Circuit Courts.
    
• Contact Points:
  
  • WBI Regulatory Affairs: Lori Myerchin, (701) 530‑1563, email [not provided].
    
  • FERC Office of Public Participation: (202) 502‑6595.
    
• Tracking the Proceeding: Use FERC’s eLibrary and eSubscription for updates on filings, orders, and environmental documents.

⚡️ Lake Lynn Hydroelectric Project: A Virtual Meeting on Historic Preservation and Tribal Interests

Overview

The U.S. Department of Energy and the Federal Energy Regulatory Commission (FERC) have scheduled a virtual meeting on April 29, 2026, to discuss the Lake Lynn Hydroelectric Project (Project No. 2459‑279). The meeting will bring together representatives from the Advisory Council on Historic Preservation (ACHP), state historic preservation offices in West Virginia and Pennsylvania, Lake Lynn Generation, LLC, and interested Native American tribes. Its purpose is to address ACHP concerns about recent comments on the project and the execution of the Programmatic Agreement (PA) that governs the project’s environmental and cultural resource impacts.

The meeting is open to the public as observers, but only the designated stakeholders may participate in discussions. If any attendee discloses sensitive information about archaeological sites or Native American cultural resources, they will be excused from that portion of the meeting to protect those resources. A summary of the meeting will be posted in the public record, with a redacted version for sensitive details and an unredacted privileged version for internal use.

This notice reflects FERC’s commitment to balancing energy development with the protection of historic and cultural resources, ensuring that all relevant parties have a forum to discuss and resolve concerns before the project proceeds.

Key Elements

• Project Context: Lake Lynn Hydroelectric Project (Project No. 2459‑279) operated by Lake Lynn Generation, LLC.
• Meeting Date & Time: April 29, 2026, 1:00 – 2:00 p.m. EDT.
• Participants: ACHP, West Virginia SHPO, Pennsylvania SHPO, Lake Lynn Generation, LLC, interested tribes, and FERC staff.
• Virtual Format: Microsoft Teams; RSVP required by April 24, 2026.
• Public Observation: Open to the public, but participation limited to designated stakeholders.
• Sensitive Information Protocol: Attendees may be excused from discussing specific site locations to protect archaeological and cultural resources.
• Record Keeping: Meeting summary will be filed publicly, with redacted and unredacted versions to safeguard sensitive data.

Alaska Base Approves Year‑Round Artillery Training, Expands Impact Zone

Overview

On March 27 2026 the Department of the Air Force, together with the Department of the Army, finalized a Record of Decision (ROD) for the Final Environmental Impact Statement (EIS) concerning proposed mortar and artillery training at the Richardson Training Area of Joint Base Elmendorf‑Richardson in Alaska. The decision, announced in a federal notice, endorses the implementation of Alternative 1, which allows all‑season live‑fire exercises using 155‑mm artillery and expands the Eagle River Flats impact area.

The ROD follows a public review of the EIS, which was released on January 30 2026. Public comments, regulatory agency input, and the environmental analysis conducted under the National Environmental Policy Act guided the agencies’ choice. The decision is grounded in statutory authority (42 U.S.C. 4321) and the Department of Defense’s NEPA procedures.

Implications of the decision include increased training activity across diverse Alaskan seasons, potential impacts on local wildlife, soil, and water resources, and the need for mitigation measures to protect the fragile Arctic environment. The agencies have committed to monitoring and managing these effects in accordance with the EIS findings and regulatory requirements.

Key Elements

• Decision Authority: Joint action by the Department of the Air Force and the Department of the Army.
  
• Chosen Alternative: Alternative 1 – all‑season live‑fire training with 155‑mm artillery.
  
• Impact Area Expansion: Enlargement of the Eagle River Flats training zone.
  
• Public Participation: EIS made available on January 30 2026; public comments incorporated into the ROD.
  
• Environmental Considerations: Assessment of noise, soil disturbance, wildlife habitat, and water quality impacts.
  
• Mitigation Measures: Planned actions to minimize ecological disruption and comply with NEPA requirements.
  
• Regulatory Compliance: Decision based on 42 U.S.C. 4321 and DoD NEPA implementing procedures.
  
• Contact Information: NEPA Project Manager David Martin (210‑710‑3277) for further inquiries.

EPA Proposes Streamlined Rules for Coal Ash Disposal, Boosting Beneficial Use and Site‑Specific Flexibility

The Environmental Protection Agency (EPA) has issued a proposed rule to revise federal regulations governing coal combustion residuals (CCR), the by‑product of coal‑fired power plants. The rule seeks to simplify how utilities manage and dispose of CCR, while maintaining safeguards for groundwater, soil, and public health. It introduces new compliance pathways that allow site‑specific decisions on monitoring, cleanup levels, closure requirements, and post‑closure care, and it expands opportunities for beneficial use of CCR on land.

Key provisions include exemptions for CCR dewatering structures, clearer definitions of storage piles and beneficial use, and the removal of an environmental demonstration requirement for non‑roadway use of up to 12,400 tons of unencapsulated CCR. The EPA also plans to reopen the public comment period for a related permit program and will hold a virtual public hearing on May 28, 2026. Comments on the rule must be submitted by June 12, 2026.

Key Elements

• Exemption for CCR Dewatering Structures – Allows utilities to use dewatering facilities without meeting the full CCR regulatory framework.
  
• Site‑Specific Compliance Pathway – Permits tailored groundwater monitoring points, cleanup levels, closure requirements, and timeframes based on individual site conditions.
  
• Beneficial Use Expansion – Eliminates the need for an environmental demonstration for non‑roadway use of up to 12,400 tons of unencapsulated CCR on land; defines “CCR storage pile” and excludes certain uses from federal oversight.
  
• Post‑Closure Extraction – Enables extraction of CCR for beneficial use during the post‑closure care period, encouraging resource recovery.
  
• Revised Legacy CCR Provisions – Modifies surface impoundment and management unit rules for legacy CCR sites to improve consistency and clarity.
  
• Public Participation – 30‑day reopening of the comment period for the 2020 permit program and a virtual public hearing scheduled for May 28, 2026.

Wyoming Lands Shift: BLM Plans Direct Sale of 800 Acres in Converse County

Overview

The Bureau of Land Management (BLM) has announced a non‑competitive, direct sale of nine parcels of public land totaling 800 acres in Converse County, Wyoming. The move aims to resolve fragmented jurisdiction patterns and the uneconomic management of isolated parcels that are surrounded by private property and lack public access. If approved, the parcels will be sold to Kristi Bohlander for no less than the appraised fair‑market value of $540,000, while the mineral estate will remain under federal ownership.

The sale is governed by the Federal Land Policy and Management Act of 1976 (FLPMA) and BLM land‑sale regulations. A parcel‑specific Environmental Assessment has been prepared, and the BLM will publish the notice in a local newspaper for three consecutive weeks. Interested parties may submit written comments by May 28, 2026, and the land will not be offered for sale until after June 12, 2026.

Key provisions include the retention of all mineral rights by the United States, the reservation of existing federal rights (e.g., ditches, canals, pipelines, and telecommunications lines), and the requirement that the sale be conducted at fair market value. The BLM will segregate the land from other public‑land appropriations until the sale is finalized, and the sale will be subject to review by the Wyoming State Director and the public comment process.

Key Elements

• Direct sale under FLPMA §203: Nine parcels (800 acres) sold without competitive bidding.
  
• Buyer: Kristi Bohlander, with the sale price set at a minimum of $540,000.
  
• Mineral estate: Remains federal; only the surface estate is conveyed.
  
• Public access issue: Parcels are isolated, surrounded by private land, and lack public access, prompting the direct sale.
  
• Environmental assessment: Parcel‑specific EA (DOI‑BLM‑WY‑P060‑2025‑0010‑EA) completed; reports available at the Casper Field Office.
  
• Reserved federal rights: Ditches, canals, mining rights, telecommunications lines, and pipeline easements remain in place.
  
• Comment period: Written comments accepted until May 28, 2026; land not offered for sale until after June 12, 2026.
  
• Segregation of land: Until sale completion, the parcels are segregated from other public‑land appropriations, limiting land‑use applications.
  
• Sale conditions: Includes indemnification clauses, preservation of existing rights, and compliance with BLM regulations.
  
• Public notice: Weekly newspaper publication for three weeks; final determination pending review of adverse comments.

Keeping Refuges Safe: Renewing Oil & Gas Reporting Rules on National Wildlife Lands

Overview

The U.S. Fish and Wildlife Service (FWS) has issued a notice to renew an existing information‑collection program that governs non‑federal oil and gas operations on National Wildlife Refuge System (NWRS) lands. Under the Paperwork Reduction Act, the FWS is extending the current set of forms and reporting requirements without any changes to the content or scope of the collection.

The program requires operators—whether they own the rights or are leasing them—to submit detailed information about their activities, including permits, site plans, environmental monitoring, financial assurances, and emergency response plans. The data collected help the FWS evaluate proposed operations, enforce mitigation measures, and ensure compliance with federal wildlife and environmental statutes such as the Endangered Species Act, the Migratory Bird Treaty Act, and the National Environmental Policy Act.

Comments on the renewal are invited until June 12 2026. The FWS encourages stakeholders to provide feedback on the necessity, burden, and clarity of the information collection, as well as suggestions for improving its efficiency and effectiveness.

Key Elements

• Purpose & Authority

  • Renewing a Paperwork Reduction Act‑approved collection (OMB Control No. 1018‑0162).
    
  • Supports the FWS mandate to manage and protect wildlife resources on federal lands.

• Scope of Operations Covered

  • All non‑federal oil and gas activities on NWRS lands, including exploration, drilling, production, and hydraulic fracturing.
    
  • Applies to pre‑existing operations, new permits, and operator transfers.

• Core Forms & Permits

  • Form 3‑2469: Primary application for Temporary Access, Operations, and Modification permits.
    
  • Hard‑copy and electronic (ePermits) options for all permit types.
    
  • Financial Assurance: Required bond or insurance to cover potential environmental damage.

• Reporting & Monitoring Requirements

  • Third‑party monitor reports on compliance and environmental protection.
    
  • Incident notifications for injuries, wildlife mortality, spills, fires, and accidents.
    
  • Annual compliance verification and well‑plugging reports.

• Environmental & Safety Data

  • Detailed site maps, resource inventories (water bodies, wetlands, sensitive habitats).
    
  • Mitigation plans for impacts on wildlife, water quality, air quality, noise, and cultural resources.
    
  • Hydraulic fracturing fluid disclosure (CAS numbers, concentrations) via FracFocus.

• Confidentiality & Public Disclosure

  • Procedures for withholding proprietary information, including affidavits and confidentiality agreements.
    
  • Generic chemical name disclosure requirements to protect trade secrets while ensuring public safety.

• Stakeholder Engagement

  • Notice invites comments on burden estimates, data utility, and potential use of electronic submission tools.
    
  • Comments are public record; stakeholders can request copies of the collection forms.

• Administrative Details

  • Total of 938 forms, 17,167 pages of information, and an estimated annual burden of 2,250,000 $ for financial assurances.
    
  • Comments due by June 12 2026; contact information provided for submissions.

California’s South SWP Hydroelectric Project Gets New Timeline for Environmental Review

Overview
The California Department of Water Resources and the Los Angeles Department of Water and Power have filed a request to relicense the 1,350‑megawatt South SWP Hydroelectric Project, a key source of renewable power and water‑management infrastructure in the region. To assess the environmental consequences of continuing operation, the Federal Energy Regulatory Commission (FERC) is preparing an Environmental Impact Statement (EIS) under its regulatory mandate.

The Commission has revised the procedural schedule for the EIS. The Draft EIS will now be released on August 7, 2026, with a comment period ending September 21, 2026, and the Final EIS slated for March 31, 2027. These adjustments allow FERC to incorporate additional information submitted by the co‑licensees and to ensure a thorough review of potential ecological, hydrological, and socio‑economic impacts.

For stakeholders—including local communities, environmental groups, and water‑resource managers—this new timeline clarifies when they can access draft findings, submit feedback, and anticipate the final decision. The outcome will determine whether the South SWP Project can continue to operate, influencing California’s renewable energy portfolio, water supply reliability, and downstream ecosystem health.

Key Elements

• Revised EIS Schedule

  • Draft EIS release: August 7, 2026
    
  • Comment period deadline: September 21, 2026
    
  • Final EIS issuance: March 31, 2027

• Stakeholder Engagement

  • Public comment period allows input from environmental groups, local residents, and industry stakeholders.
    
  • Contact point: Quinn Emmering (202) 502‑6382 for questions.

• Scope of the EIS

  • Evaluation of relicensing impacts on water flow, fish and wildlife habitats, sediment transport, and downstream water users.
    
  • Assessment of energy generation benefits versus environmental trade‑offs.

• Regulatory Context

  • FERC’s authority under 18 CFR 2.1 governs the licensing and environmental review process.
    
  • The notice is part of the broader federal oversight of hydroelectric projects in California.

• Implications for Energy and Water Resources

  • Successful relicensing would maintain a significant renewable energy source while potentially affecting water allocation for agriculture, municipal use, and ecological conservation.
    
  • The EIS findings will guide future water‑resource planning and environmental protection measures in the region.

Dominion Energy Eyes Re‑licensing of Virginia’s Massive Pumped‑Storage Power Plant

Overview

Dominion Energy, through its Virginia Electric and Power Company, has submitted a re‑licensing application for the 2,484‑megawatt Bath County Pumped Storage Project. The project, located on Back Creek and Little Back Creek across Bath, Highland, Augusta, and Rockbridge counties, is a large‑scale hydroelectric facility that uses two earth‑and‑rock‑fill dams to create an upper and lower reservoir, with six reversible pump‑turbines housed in an underground powerhouse.

The facility covers 3,451 acres, including 1,122 acres of federal land within the George Washington and Jefferson National Forests. The upper reservoir spans 278 acres, while the lower reservoir covers 555 acres. The project’s infrastructure—two 2,000‑plus‑foot dams and a 6‑turbine powerhouse—provides a critical energy‑storage capability for Virginia’s power grid.

In accordance with the Federal Energy Regulatory Commission’s (FERC) procedures, the Commission has issued a Notice of Readiness for Environmental Analysis (REA). FERC staff has determined that licensing the project is unlikely to constitute a major federal action affecting the environment, and will therefore prepare an Environmental Assessment (EA). The EA will be released on November 20, 2026, and will invite public comments that will inform the final licensing decision.

Key Elements

• Re‑licensing Application: Dominion Energy seeks to renew the license for the 2,484‑MW Bath County Pumped Storage Project.
  
• Project Scope:
  
  • Upper reservoir: 278 acres, 2,250‑ft long, 460‑ft high dam.
    
  • Lower reservoir: 555 acres, 2,100‑ft long, 135‑ft high dam.
    
  • Underground powerhouse with six Francis reversible pump‑turbines.
    
• Land Use: Total project boundary of 3,451 acres, including 1,122 acres of federal land in the George Washington and Jefferson National Forests.
  
• Environmental Review: FERC has issued a Notice of Readiness for Environmental Analysis and will prepare an Environmental Assessment (EA) rather than a full Environmental Impact Statement.
  
• Public Participation: The EA will be circulated for review; all comments will be considered in the final licensing decision. Public inquiries and filings can be directed to the Office of Public Participation.
  
• Timeline: EA issuance scheduled for November 20, 2026, with potential schedule revisions as needed.
  
• Regulatory Context: The project falls under the National Environmental Policy Act (NEPA) and FERC’s 18 CFR 2.1 authority.

Saguaro Pipeline Seeks 2030 Deadline to Keep Mexico LNG Supply on Track

Overview

Saguaro Connector Pipeline, LLC has requested the Federal Energy Regulatory Commission (FERC) to extend the construction deadline for its Border Facility Project from February 15 2027 to February 15 2030. The project involves a 1,000‑foot, 48‑inch pipeline running from the U.S.–Mexico border at the Rio Grande River to a point 1,000 feet inland, about 18 miles southwest of Sierra Blanca in Hudspeth County, Texas. The pipeline is intended to feed a future LNG terminal in Mexico with natural gas sourced from the U.S. Waha Hub.

The extension is sought because construction has not yet begun, largely due to ongoing litigation, unresolved commercial negotiations, and delays in the downstream Mexican LNG terminal’s service start. With the Section 3 authorization and Presidential Permit now confirmed, Saguaro is negotiating with original and potential new shippers and needs additional time to secure financing and finalize agreements.

FERC will consider the request within 45 days if contested, or immediately if uncontested. The notice invites public comment and intervention for 15 calendar days, but it will not re‑evaluate the original certificate or permit issuance. Stakeholders—including shippers, local communities, and environmental groups—can submit comments electronically or by paper, and the Commission will publish the full docket on its eLibrary platform.

Key Elements

• Project scope: 1,000‑ft, 48‑inch pipeline from Rio Grande border crossing to inland point, 18 mi SW of Sierra Blanca, Hudspeth County, Texas.
  
• Original deadline: February 15 2027 (three years after the 2024 Order).
  
• Requested extension: February 15 2030, adding 3 years to the construction timeline.
  
• Reasons for delay:
  
  • Pending litigation and appeals concerning the project’s authorization.
    
  • Unresolved commercial negotiations with shippers.
    
  • Delays in the downstream Mexican LNG terminal’s commencement of service.
    
• Strategic purpose: Supply a future Mexican LNG terminal with natural gas from the U.S. Waha Hub, enhancing cross‑border energy trade.
  
• FERC’s role:
  
  • Will not re‑evaluate the original certificate or Section 3 permit.
    
  • Will issue an order on the extension within 45 days if contested; otherwise, it will act promptly.
    
• Public participation: 15‑day intervention and comment period; comments accepted electronically or by paper.
  
• Access to information: Full docket available on FERC’s eLibrary in PDF and Word formats; public inquiries handled by the Office of Public Participation.

US Forest Service Seeks Feedback on Nationwide Woodland Owner Survey Renewal

Overview

The U.S. Forest Service, under the Paperwork Reduction Act of 1995, is requesting public comments on extending the National Woodland Owner Survey (NWOS) through May 31 2027. The survey, which is part of the Forest and Rangeland Renewable Resources Planning Act, gathers detailed information on who owns and manages the nation’s 704 million acres of forestland (excluding interior Alaska). By understanding ownership patterns, motivations, and management practices, the Forest Service can better plan and evaluate forest policies, programs, and conservation efforts.

The upcoming 2024‑2028 survey cycle will target a statistically representative sample of 50 owners per state (or substate) each year, aiming for roughly 2,650 responses annually. In addition, the survey will include specialized science modules on wildfire, timber, recreation, carbon, and other high‑priority topics, expanding the total number of respondents to about 19,447 and estimating 3,090 hours of respondent burden. Data will be collected through a mix of mailed questionnaires, online responses, telephone follow‑ups, cognitive interviews, and focus groups, with results made publicly available at national, regional, and state levels.

Comments are due by June 12 2026 and can be submitted in writing, by fax, or via email to Brett Butler at the USDA Forest Service. The Forest Service encourages stakeholders—including landowners, researchers, and the general public—to provide input on the survey’s necessity, burden estimates, and ways to improve data quality and reduce respondent effort.

Key Elements

• Renewal Deadline: May 31 2027, covering the 2024‑2028 survey cycle.
  
• Scope of Forestland: 704 million acres nationwide (excluding interior Alaska).
  
• Ownership Breakdown: Over half owned by private entities (corporations, families, individuals); remainder managed by federal, state, local, and tribal agencies.
  
• Survey Objectives: Identify owners, motivations, land use, future intentions, and demographic characteristics.
  
• Target Populations: Family owners, corporate/private owners, tribal lands, public lands, urban landowners, and U.S. territories.
  
• Sample Size & Response Target: 50 respondents per state per year → ~2,650 responses; expanded to ~19,447 ownerships with science modules.
  
• Burden Estimate: 3,090 respondent hours annually; 25‑120 minutes per survey depending on ownership type.
  
• Methodology: Mixed‑mode approach—mail, online, telephone, cognitive interviews, focus groups, and participatory action research for tribal lands.
  
• Key Topics Covered: Wildfire, timber, recreation, afforestation, agroforestry, carbon, invasive species, land transfer, decision‑making, energy, heirs’ properties, wellbeing, sense of place.
  
• Data Availability: Results will be publicly released electronically at national, regional, and state levels.
  
• Purpose for Policy & Research: Provides benchmarks for ownership trends, informs sustainability assessments, supports forest‑land owner assistance programs, and aids in addressing fragmentation, timber economics, and climate‑related forest management.
  
• Comment Submission: Must be received by June 12 2026; can be written, faxed, or emailed to Brett Butler, USDA Forest Service, Amherst, MA.

Tennessee’s Winter Storm Fallout: SBA Opens Disaster Loan Window

Overview

On April 7, 2026 the U.S. Small Business Administration (SBA) issued an administrative declaration of disaster for the state of Tennessee in response to the severe winter storm “Fern.” The declaration authorizes the SBA to provide disaster assistance loans to businesses, homeowners, and non‑profit organizations that suffered physical damage or economic injury during the storm. The notice also identifies specific counties—Hardin, Chester, Decatur, Henderson, McNairy, Wayne, and neighboring counties in Alabama and Mississippi—that are considered adversely affected.

The SBA’s loan program offers two main categories: physical‑damage loans and economic‑injury loans. Interest rates vary by borrower type and credit availability, ranging from 2.875 % for homeowners without other credit to 8.000 % for businesses with other credit. Applicants can apply online through the MySBA Loan Portal or at local SBA‑announced locations. The declaration includes contact details for the Office of Disaster Recovery and Resilience and provides accessibility options for individuals with hearing or speech disabilities.

This administrative declaration is part of the broader federal response to the storm, which also includes disaster numbers TN‑20032 for Tennessee and similar designations for Alabama and Mississippi. The SBA’s assistance aims to help affected communities recover infrastructure, maintain economic activity, and mitigate long‑term impacts of the winter storm.

Key Elements

• Storm and Impact

  • Severe Winter Storm Fern (2026) triggered the declaration.
    
  • Affected counties: Hardin (TN), Chester, Decatur, Henderson, McNairy, Wayne (TN); Lauderdale (AL); Alcorn, Tishomingo (MS).
    

• SBA Disaster Numbers

  • Physical damage: 21484B (Disaster #21484).
    
  • Economic injury: 214850 (Disaster #21485).
    
  • Tennessee Disaster Number: TN‑20032.
    

• Loan Types & Interest Rates

  • Physical Damage
    
  • Homeowners with credit elsewhere: 5.750 %
    
  • Homeowners without credit elsewhere: 2.875 %
    
  • Businesses with credit elsewhere: 8.000 %
    
  • Businesses without credit elsewhere: 4.000 %
    
  • Private non‑profits (any credit status): 3.625 %
    
  • Economic Injury
    
  • Businesses & small agricultural cooperatives without credit elsewhere: 4.000 %
    
  • Private non‑profits without credit elsewhere: 3.625 %
    

• Application Process

  • Apply online via the MySBA Loan Portal or in person at SBA‑announced sites.
    
  • Contact: Sharon Henderson, Office of Disaster Recovery and Resilience, (202) 205‑6734.
    
  • Accessibility: Dial 7‑1‑1 for telecommunications relay services.
    

• Timeline

  • Declaration issued: April 7, 2026.
    
  • Relevant dates: Jan 22‑27, 2026; Jun 8, 2026; Jan 7, 2027.
    

• Scope

  • Affects Tennessee, Alabama, and Mississippi under Catalog of Federal Assistance No. 59008.
    
  • Authority: 13 CFR 123.3(b).
    

These provisions provide a framework for affected stakeholders to secure financial relief and support recovery efforts in the wake of the winter storm.

Oak Ridge Environmental Management Board Meets to Guide Cleanup and Future Land Use

Overview

The Department of Energy’s Office of Environmental Management (EM) has announced an open meeting of the Environmental Management Site‑Specific Advisory Board (EM SSAB) for Oak Ridge, Tennessee. The board, established under the Federal Advisory Committee Act, serves as a key advisory body that reviews and recommends actions on cleanup activities, waste and nuclear material management, excess facility disposition, and long‑term stewardship of the Oak Ridge site.

The meeting, scheduled for Wednesday, May 13 2026, 6–8 p.m. EDT, will be held in person at the DOE Information Center and simultaneously streamed online. Participants can request virtual access by emailing the board at least two days before the meeting. The agenda will include an Office of Environmental Management presentation, discussion, a public comment period, and board business.

Public participation is a core element of the board’s work. Fifteen minutes are set aside for oral or written comments, and written submissions received at least two working days before the meeting will be incorporated into the minutes. The board’s recommendations help satisfy public‑participation requirements under NEPA, CERCLA, RCRA, and related federal agreements, ensuring that community concerns shape the site’s environmental restoration and future land‑use decisions.

Key Elements

• Meeting details: May 13 2026, 6–8 p.m. EDT; in‑person at DOE Information Center, Oak Ridge, TN, and virtual.
  
• Virtual access: Email the board at least two days prior to receive link.
  
• Agenda: EM presentation → discussion → public comment → board business.
  
• Public comment: 15‑minute window; oral comments limited to 2 minutes each; written comments due ≥2 working days before.
  
• Board purpose: Advise on cleanup, waste & nuclear material management, excess facilities, future land use, and long‑term stewardship.
  
• Legal framework: Operates under the Federal Advisory Committee Act; fulfills NEPA, CERCLA, RCRA, and other federal public‑participation mandates.
  
• Contact: Melyssa P. Noe, Deputy Designated Federal Officer, EM Oak Ridge Office (Phone: 865‑241‑3315, Email: [email protected]).
  
• Accessibility: Board will accommodate persons with disabilities; request accommodations ≥7 days before the meeting.
  
• Minutes: Available on the DOE website after the meeting.
  
• Significance for geoscience & natural resources: Provides expert guidance on site remediation, waste disposition, and future land‑use planning—critical for sustainable resource management and environmental protection.

Southern Star’s New Pipeline to Power Kansas Power Plant: Environmental Review Timeline Set

Overview
Southern Star Central Gas Pipeline, Inc. has filed for a Certificate of Public Convenience and Necessity to construct the Viola Project in Sumner County, Kansas. The project will build a 19‑mile, 16‑inch natural‑gas pipeline (Line UA), a compressor station, a meter station, and a valve to supply up to 116,296 dekatherms per day to the 710‑megawatt Viola combined‑cycle power plant currently under construction by Evergy Kansas Central, Inc.

The Federal Energy Regulatory Commission (FERC) has scheduled the preparation of an Environmental Assessment (EA) for October 9, 2026, followed by a 30‑day public comment period. FERC’s 90‑day deadline for federal authorization decisions is set for January 7, 2027, giving other federal and state agencies a clear timetable to review and approve the project.

Public input has already been solicited through a Notice of Scoping, with concerns raised about air and noise emissions, compressor‑station safety, and proximity to residences. These issues will be addressed in the forthcoming EA, ensuring that environmental and community impacts are thoroughly evaluated before the project proceeds.

Key Elements

• Project Scope: 19.33 mi of new 16‑inch pipeline (Line UA), a 12,375‑hp compressor station, a mainline valve, and a meter station linking to the Viola Plant.
  
• Capacity: Designed to transport up to 116,296 dekatherms/day of natural gas to support a 710‑MW power plant.
  
• Timeline: EA issuance on Oct 9 2026; 30‑day comment period; federal authorization decision deadline Jan 7 2027.
  
• Regulatory Framework: FERC’s Notice of Application (CP26‑74‑000) and Notice of Scoping; compliance with the Natural Gas Act and NEPA.
  
• Public Participation: Notice of Scoping sent to landowners, agencies, tribes, and the public; comments on air, noise, safety, and residential proximity will be incorporated.
  
• Agency Coordination: Other federal and state agencies must meet the 90‑day decision deadline unless a different schedule is mandated by law.
  
• Tracking and Transparency: Unique NEPA ID EAXX‑019‑20‑000‑1774341286; eSubscription and eLibrary services available for public monitoring.

Building Safer Communities: The New Wildfire Resilience Grant Act

Overview

The Community Protection and Wildfire Resilience Act establishes a dedicated grant program to help local governments, tribes, and other eligible entities develop and implement comprehensive wildfire‑resilience plans. The legislation requires that plans be created in partnership with a broad range of stakeholders—including local law‑enforcement, fire managers, utilities, and community groups—to address early detection, evacuation, infrastructure hardening, and public education.

The Act sets clear funding limits: up to $10 million for project implementation and $250,000 for plan development, with a total appropriation of $1 billion per year for fiscal years 2025‑2029. Grants are prioritized for communities in high‑risk fire zones identified by state hazard maps. Recipients must use at least 25 % of project costs from non‑federal sources, except for plan‑development grants, which require no non‑federal share. Preference is given to local contractors and labor, and the program encourages partnerships with AmeriCorps and conservation corps.

Beyond funding, the Act mandates a series of oversight and reporting measures. The Government Accountability Office must publish a report on existing federal wildfire‑protection programs and identify funding gaps. It must also study certification of community resilience and its potential use by insurers. The Administrator will map at‑risk communities every five years, produce a radio‑communications report to address interoperability barriers, and amend the Community Wildfire Defense Grant Program to allow structure hardening projects.

Key Elements

• Grant Program Structure

  • Separate from the Stafford Disaster Relief Act.
    
  • Two grant types: project implementation ($≤ $10 M) and plan development ($≤ $250 k).
    
  • $1 billion authorized annually (2025‑2029).

• Eligibility & Prioritization

  • Eligible entities: states, tribes, local governments, volunteer fire departments, or collaborations of at least two such entities.
    
  • Priority to high‑risk communities identified by state wildfire hazard maps or federal hazard maps.

• Cost‑Sharing & Local Preference

  • 25 % non‑federal share required for project grants; none for plan‑development grants.
    
  • Preference for local contractors, labor, and partnerships with AmeriCorps or conservation corps.

• Plan Requirements

  • Must include early detection, evacuation, infrastructure hardening, defensible space, land‑use planning, and coordination with existing wildfire plans.
    
  • Must address vulnerable populations (elderly, children, disabled, homeless).

• Reporting & Oversight

  • GAO report on federal wildfire‑protection programs and funding gaps (≤ 1 year).
    
  • GAO study on resilience certification and insurance incentives (≤ 1 year).
    
  • Administrator to publish a map of at‑risk communities every five years.
    
  • Radio‑communications report on interoperability and frequency needs (≤ 2 years).

• Structure Hardening Amendment

  • Expands the Community Wildfire Defense Grant Program to include construction, modification, or maintenance of structures to resist flames or embers, and adjacent vegetation or structures.

• Definitions

  • Community protection and wildfire resilience plan: collaborative plan covering detection, evacuation, infrastructure, defensible space, and education.
    
  • Critical infrastructure: public safety, health, education, transportation, communications, utilities essential during wildfire threats.
    
  • Defensible space project: vegetation management within 100 ft of a structure.

This legislation equips communities with the financial tools, technical guidance, and accountability mechanisms needed to build resilience against the growing threat of wildfires.

Boosting the Great Lakes: $2.5 Billion to Restore and Protect the Region

Overview
The GLRI Act of 2025 extends the Great Lakes Restoration Initiative (GLRI), a federal program that coordinates efforts to improve water quality, restore habitats, and support economic development around the Great Lakes. By reauthorizing the initiative, Congress signals its continued commitment to safeguarding one of the world’s largest freshwater systems and ensuring that scientific research, industry, and local communities can thrive.

The bill amends the Federal Water Pollution Control Act to allocate an additional $500 million annually for each fiscal year from 2027 through 2031. This new funding stream will support projects ranging from invasive species control and shoreline restoration to advanced monitoring of water quality and ecosystem health. The allocation is designed to build on past successes while addressing emerging challenges such as climate change impacts and industrial pollution.

For geoscientists, environmental engineers, and natural resource professionals, the GLRI Act offers expanded opportunities for research partnerships, data sharing, and technology deployment. The increased budget will enable more comprehensive monitoring of sediment, nutrient loads, and contaminant pathways, fostering evidence‑based decision making that benefits both ecological integrity and regional economies.

Key Elements

• Reauthorization of GLRI – Extends the federal program’s mandate to protect and restore the Great Lakes ecosystem.
  
• $500 million annual funding (2027‑2031) – Adds a dedicated, multi‑year budget to support restoration projects, research, and stakeholder collaboration.
  
• Amendment to the Federal Water Pollution Control Act – Formalizes the new funding allocation within existing environmental legislation.
  
• Subcommittee referral – Sent to the Subcommittee on Water Resources and Environment for further review, ensuring focused oversight on water‑related issues.
  
• Broad stakeholder engagement – Encourages partnerships among federal agencies, state and local governments, academia, industry, and Indigenous communities.
  
• Enhanced monitoring and data integration – Supports advanced scientific studies on water quality, sediment dynamics, and climate resilience.
  
• Economic and community benefits – Aims to strengthen fisheries, tourism, and clean‑water infrastructure while safeguarding public health.

Cleaning Up the Past: DOJ Finalizes Superfund Settlement in Bankruptcy Case

Overview

On April 3 2026, the U.S. Department of Justice lodged a proposed consent decree to resolve environmental liabilities tied to the Chapter 11 bankruptcy of Whittaker, Clark and Daniels, Inc. and its affiliates. The decree addresses objections from the United States and other environmental creditors that the original bankruptcy settlement underestimated cleanup costs at three Superfund sites: Lockwood Solvent (Montana), Omega Chemical (California), and Cooper Drum (California).

The agreement allows the bankruptcy court to approve a general unsecured claim for the United States while requiring the National Indemnity Company (NICO), a Berkshire Hathaway subsidiary, to pay cash for cleanup expenses and establish an environmental response trust. By doing so, the decree seeks to ensure that responsible parties contribute fairly to the remediation of contaminated sites and that funds are available for long‑term monitoring and restoration.

The notice invites public comment for 30 days, giving stakeholders—including scientists, local communities, and industry groups—an opportunity to weigh in on the proposed terms before the court finalizes the decree.

Key Elements

• Parties Involved: Debtors (Whittaker, Clark and Daniels, Inc. and affiliates), alleged successors (DB US Holding Corp., Brenntag North America, NICO).
  
• Affected Sites:
  
  • Lockwood Solvent Superfund Site, Yellowstone County, Montana
    
  • Omega Chemical Superfund Site, Whittier, California
    
  • Cooper Drum Superfund Site, South Gate, California
    
• Liability Issue: U.S. and environmental creditors argued the original settlement underestimated CERCLA cleanup costs at these sites.
  
• Financial Provision: NICO is required to make a cash payment to cover cleanup costs and to fund an environmental response trust.
  
• Court Action: The consent decree will be reviewed by the U.S. Bankruptcy Court for the District of New Jersey (Case No. 23‑13575).
  
• Public Comment Period: 30 days from publication (April 10 2026) to submit written or electronic comments to the DOJ’s Environment and Natural Resources Division.
  
• Transparency: The consent decree is publicly available for download on the DOJ website, and comments may be filed on the court docket.

USDA Seeks Public Input on Expanded Farm Survey to Track Conservation Practices and Environmental Impact

Overview

The U.S. Department of Agriculture (USDA) has issued a notice inviting public comments on a proposed change to the National Agricultural Statistics Service’s Conservation Effects Assessment Project (CEAP) survey. Under the Paperwork Reduction Act, the agency must obtain Office of Management and Budget (OMB) clearance before adding new data‑collection elements. The proposed addition involves text and email reminder messages to respondents, which will increase the estimated burden hours for the survey.

The CEAP survey gathers detailed information from approximately 20,000 farm and ranch operators across the contiguous United States. It focuses on residue and tillage management, nutrient management, and other conservation practices. By combining this data with existing soil, climate, and cropping history records, the USDA aims to model how current farming practices influence broader environmental outcomes—such as soil health, water quality, and carbon sequestration.

For researchers and professionals in geoscience, atmospheric, ocean, and natural resource fields, the updated survey offers a richer, more timely data set to assess the effectiveness of conservation strategies. The USDA’s request for comments underscores the importance of balancing data quality with respondent burden, and it invites stakeholders to shape how this critical information is collected and used.

Key Elements

• OMB Review & Paperwork Reduction Act: The USDA must secure an OMB control number before implementing the survey changes.
  
• Comment Period: Public comments are due by May 11, 2026, with a 30‑day window from publication.
  
• Survey Scope: Personal interviews with farm operators in the 48 contiguous states; ~20,000 respondents annually.
  
• Proposed Change: Addition of text and email reminder messages to improve response rates, increasing estimated burden hours.
  
• Data Purpose: To quantify the environmental impacts of residue, tillage, and nutrient management practices, informing policy and conservation planning.
  
• Reporting: Results will be published annually, supporting research in soil science, climate change mitigation, and sustainable agriculture.
  
• Stakeholder Impact: Enhanced data will aid geoscientists, environmental scientists, and natural resource managers in modeling ecosystem services and assessing land‑use changes.

Turkey’s Aluminum Sheet Faces New U.S. Dumping Duties: What It Means for the Industry

Overview
The U.S. Department of Commerce has finalized its administrative review of common alloy aluminum sheet (CAAS) imported from Turkey for the period April 1 2023 – March 31 2024. The review concluded that Turkish producers sold CAAS in the United States at less than normal value, establishing weighted‑average dumping margins of 4.01 % for Assan Aluminyum Sanayi ve Ticaret A.S., 14.19 % for Teknik Aluminyum Sanayi A.S., and 9.10 % for the non‑examined company. These rates will be used to assess antidumping duties on future U.S. imports of Turkish CAAS.

The decision imposes new financial obligations on U.S. importers: they must pay antidumping duties equal to the calculated rates and provide cash deposits matching those rates (or the all‑others rate of 4.85 % if no specific rate applies). Customs will liquidate entries at the appropriate rate unless a statutory injunction is filed. The notice also reminds parties of their responsibilities under administrative protective orders and the requirement to file reimbursement certificates.

For the broader geoscience and natural‑resource community, the ruling underscores the importance of aluminum as a critical material in construction, transportation, and energy infrastructure. It highlights how trade policy can influence the supply chain, pricing, and competitiveness of aluminum products that are integral to sustainable development and technological innovation.

Key Elements

• Final Dumping Margins

  • Assan Aluminyum Sanayi ve Ticaret A.S.: 4.01 %
    
  • Teknik Aluminyum Sanayi A.S.: 14.19 %
    
  • Non‑selected company: 9.10 %
    

• Assessment Rates

  • Customs will assess duties on all entries of Turkish CAAS at the corresponding company‑specific rate.
    
  • Entries lacking a specific rate will be liquidated at the all‑others rate of 4.85 %.

• Cash Deposit Requirements

  • Importers must deposit cash equal to the applicable dumping margin (or 4.85 % for all‑others).
    
  • Deposits remain in effect until further notice.

• Timeline

  • Final results published April 6 2026.
    
  • Assessment instructions to Customs no earlier than 35 days after publication.
    
  • Statutory injunction period: 90 days from publication.

• Administrative Protective Order (APO) Reminder

  • Parties must return or destroy proprietary information disclosed under APO in accordance with regulations.

• Implications for the Aluminum Supply Chain

  • Higher duties may raise costs for U.S. manufacturers using Turkish CAAS.
    
  • Potential shift toward domestic or alternative suppliers, affecting trade balances and material sourcing strategies.

U.S. Tightens Metal Import Rules to Bolster National Security and Domestic Production

Overview

The President has issued a new proclamation under Section 232 of the Trade Expansion Act to strengthen the United States’ control over imports of aluminum, steel, and copper. Building on earlier proclamations from 2018 and 2025, the measure now applies additional duties to the full customs value of these metals and their derivative products, regardless of metal content. The intent is to protect national security by limiting the flow of strategic materials that could undermine U.S. defense and industrial capabilities.

Key tariff adjustments include a 50 % duty on most aluminum and steel articles, a 25 % duty on most copper articles, and a 10 % duty on derivative products that are fully sourced from U.S. smelting or casting. Reduced rates are available for certain United Kingdom products and for items made entirely from U.S.‑origin metals. The proclamation also terminates earlier inclusion processes, granting the Secretary of Commerce and the U.S. Trade Representative the authority to add new derivative articles on a rolling basis when they pose a national‑security risk.

The policy aims to accelerate domestic production, raise capacity utilization toward 80 % for aluminum and steel, and stimulate research and workforce development in strategic metal manufacturing. Continuous monitoring and periodic reviews will determine whether further adjustments are needed, ensuring the tariff regime remains responsive to evolving security and trade dynamics.

Key Elements

• Full‑value tariffs: Duties now apply to the entire customs value of aluminum, steel, and copper articles, eliminating loopholes that allowed lower‑valued imports to evade higher rates.
  
• Tariff rates:
  
  • 50 % on most aluminum and steel articles (25 % for UK‑origin products, 10 % for U.S.‑origin derivatives).
    
  • 25 % on most copper articles (15 % for UK‑origin products, 10 % for U.S.‑origin derivatives).
    
• Derivative inclusion: The Secretary and Trade Representative can add new derivative products to the tariff list on a rolling basis, with the option to remove them if they no longer pose a threat.
  
• Termination of prior inclusion processes: Existing mechanisms from earlier proclamations are ended, centralizing authority in the current executive framework.
  
• Special provisions:
  
  • 200 % duty on aluminum products involving Russian smelting or casting.
    
  • Products containing multiple metals are taxed only once under the applicable rate.
    
  • Exemptions for items lacking sufficient aluminum, steel, or copper content.
    
• Monitoring and reporting: The Secretary must review import flows, report to the President within 90 days, and advise on potential future adjustments or revocations.
  
• Trade‑partner considerations: Reduced rates for UK products and special treatment for trade‑agreement partners, while maintaining higher duties for non‑partner countries.
  
• Compliance requirements: Importers must provide smelt‑and‑cast origin data; Customs and Border Protection will enforce these rules and address tariff evasion.
  
• Impact on domestic industry: The policy is designed to boost U.S. production capacity, encourage R&D in advanced metal technologies, and create skilled jobs in the strategic metals sector.

Wyoming Proposes New Reclamation Bond Rules for Coal Mining

Overview

The U.S. Interior Department’s Office of Surface Mining Reclamation and Enforcement (OSM) has announced a proposed amendment to Wyoming’s coal program under the Surface Mining Control and Reclamation Act of 1977 (SMCRA). The amendment follows approvals by the Wyoming Environmental Quality Council and the Governor, and seeks to recognize a specific type of reclamation bond estimate adjustment that would not be treated as a bond release request.

The change aims to streamline the financial assurance process for coal operators by allowing certain bond adjustments to be made without the formal release procedure, potentially reducing administrative burdens while maintaining reclamation safeguards. It also clarifies how bond estimates can be modified during the life of a mining operation, ensuring that the state’s reclamation objectives remain protected.

Stakeholders—including mining companies, environmental groups, and local communities—are invited to submit written comments by May 11, 2026, and a public hearing may be held on May 4, 2026. The amendment is identified as Docket ID OSM‑2026‑0001 and is available for review at the OSM Casper Field Office and the Wyoming Department of Environmental Quality.

Key Elements

• Regulatory Context: Proposed rule under SMCRA, 1977, administered by OSM.
  
• Bond Adjustment Provision: Recognizes a specific reclamation bond estimate adjustment that is not considered a bond release request.
  
• State Approval: Wyoming’s Environmental Quality Council and Governor approved the changes in September and October 2025.
  
• Public Participation: Written comments accepted until 4:00 p.m. MT, May 11, 2026; public hearing possible on May 4, 2026.
  
• Contact & Docket: Docket ID OSM‑2026‑0001; comments submitted to OSM’s Casper Field Office or via phone/email.
  
• Implications for Mining Operations: Potentially reduces administrative steps for bond adjustments, while maintaining reclamation oversight.
  
• Availability of Documents: Full amendment text and related materials accessible at the OSM Casper Field Office and the Wyoming Department of Environmental Quality.

Marine Mammal Take Authorization for Deep‑Sea Seismic Survey in the Western Central Atlantic

Overview

The U.S. National Marine Fisheries Service (NMFS) is proposing to grant the Lamont‑Doherty Earth Observatory (L‑DEO) an incidental harassment authorization (IHA) for a high‑energy seismic survey off the Eastern North American margin in the Western Central Atlantic Ocean. The survey, scheduled for July–September 2026, will use a 36‑airgun array to collect seismic data that will help scientists understand the oceanic lithosphere and mantle dynamics. NMFS is seeking public comments on the proposed IHA and on a possible one‑year renewal if the survey is delayed or extended.

The authorization would allow the incidental “harassment” (temporary disturbance) of marine mammals, but no serious injury or mortality is expected. NMFS has determined that the impacts would be negligible and that the number of animals taken would be a small fraction of the populations present. The proposal includes detailed mitigation, monitoring, and reporting requirements to protect marine mammals and their habitat.

Key Elements

• Survey Scope

  • 36‑airgun array (6,600 in³ total discharge) towed at 12 m depth.
    
  • 4,264 km of trackline (691 km 2‑D reflection, 3,573 km OBS refraction).
    
  • Operates in 4,800–5,550 m water depth, 27–33° N, 67–75° W.
    
  • 42‑day duration (20 days seismic, 13 days OBS deployment, 4.5 days contingency, 4.5 days transit).

• Estimated Takes

  • Level B harassment (temporary disturbance) for 31 species, ranging from 0.01 to 2.09 individuals per species per day.
    
  • Level A harassment (potential permanent hearing injury) limited to five species (Bryde’s, sei, minke, dwarf sperm, pygmy sperm whales) with very low projected numbers.
    
  • Total takes are less than 3 % of modeled population sizes for all affected species.

• Mitigation Measures

  • Visual and Acoustic Monitoring: Two trained visual observers and two acoustic observers on board to detect marine mammals before, during, and after airgun firing.
    
  • Shutdown and Buffer Zones: 500 m shutdown zone (SZ) around the airgun array; 1,000 m buffer zone for pre‑start clearance.
    
  • Ramp‑Up Procedure: Gradual increase of airgun firing to give animals warning and time to leave the SZ.
    
  • Vessel‑Strike Avoidance: Speed limits and separation distances (≤10 kn for large whales, ≤50 m for other species).
    
  • Reporting: Draft report within 90 days of survey completion; final report within 30 days of comment period closure.

• Environmental and Regulatory Assessment

  • Negligible Impact: No serious injury or mortality expected; impacts are short‑term behavioral disturbances.
    
  • Small Numbers: Takes are well below one‑third of population estimates.
    
  • ESA Compliance: Consultation underway for ESA‑listed species (fin, blue, sei, sperm whales).
    
  • Renewal Option: One‑year renewal possible if activities are delayed, subject to public comment and unchanged mitigation.

• Public Comment Period

  • Comments due by May 11, 2026.
    
  • Address to NMFS Permits and Conservation Division, Office of Protected Resources.
    
  • Comments must not exceed 25 MB and should include supporting data or literature.

This proposal balances scientific research needs with marine mammal protection, ensuring that any incidental disturbance is minimized, monitored, and documented.

Streamlining Oil & Gas Royalty Reporting on the Outer Continental Shelf

Overview

The U.S. Interior Department’s Office of Natural Resources Revenue (ONRR) has announced the renewal of its information‑collection program for Outer Continental Shelf (OCS) Net Profit Share Lease (NPSL) reporting. Under the Paperwork Reduction Act, ONRR seeks to maintain its authority—under OMB Control Number 1012‑0009—to gather the data needed to calculate the United States’ share of net profits from offshore oil and gas production. The renewal is intended to keep the reporting framework current while minimizing the administrative burden on leaseholders.

The notice invites public comment until June 8, 2026, and outlines how stakeholders can submit feedback electronically or by mail. ONRR emphasizes that the collection is essential for accurate royalty accounting, audit readiness, and compliance with the Federal Oil and Gas Royalty Management Act of 1982. By renewing the collection, the agency aims to preserve a reliable fiscal and production accounting system that supports timely payment of royalties and other obligations to the federal government.

For geoscientists, energy companies, and natural‑resource professionals, the renewal confirms that the existing reporting requirements—annual, monthly, and final reports, as well as periodic inventories—remain in force. It also signals that ONRR will continue to audit and inspect records to ensure transparency and accountability in offshore resource development.

Key Elements

• Renewed Authority: OMB Control Number 1012‑0009 is extended to allow ONRR to collect NPSL reporting data.
  
• Reporting Requirements:
  
  • Annual reports on costs and capital account status.
    
  • Monthly reports detailing production volumes, revenues, costs, and net profit share calculations.
    
  • Final reports upon lease termination, summarizing remaining balances.
    
  • Inventory reports every 1–3 years, with reconciliation to capital accounts.
    
• Audit and Inspection Rights: ONRR may inspect records, audit accounts, and coordinate with non‑operator audits to verify compliance.
  
• Burden Estimate: ONRR projects a minimal burden (≈3 hours per respondent) due to the limited number of active NPSLs and the possibility of future adjustments.
  
• Public Comment Process: Comments must reference OMB Control Number 1012‑0009 and can be submitted via the ONRR docket portal or by email/letter before June 8, 2026.
  
• Compliance Context: The collection supports the Federal Oil and Gas Royalty Management Act, ensuring accurate determination of royalties, fines, and other payments owed to the United States.

PGE Seeks Temporary Flow Variance to Protect Salmon While Boosting Water Delivery

Overview

Pacific Gas and Electric Company (PGE) has requested a temporary relaxation of minimum flow requirements for the DeSabla‑Centerville Project on Butte Creek and its tributaries in Butte County, California. The company seeks to lower the instantaneous minimum flow from 15 cfs (normal year) and 7 cfs (dry year) to 7 cfs for 48 hours, and to adjust Philbrook Creek’s flow from 2 cfs to between 1 and 2 cfs for the same duration. These changes would take effect from May 4 to September 30 2026, with an earlier start possible if reservoir storage permits.

The goal is to streamline water releases from Philbrook Reservoir, preserve cold‑water storage, and increase flow to Butte Creek during the hot summer months. By reducing the need for buffer releases, PGE aims to lower water residence time in the DeSabla Forebay, thereby mitigating high‑temperature impacts on Central Valley spring‑run Chinook salmon and ensuring more reliable water availability later in the summer when demand is greatest.

The Federal Energy Regulatory Commission (FERC) has accepted the application and will prepare an Environmental Assessment (EA) under the National Environmental Policy Act. The EA is slated for release by May 29 2026, and the public is invited to comment, intervene, or protest through the Office of Public Participation.

Key Elements

• Temporary Flow Variance:
  
  • West Branch Feather River: 15 cfs → 7 cfs (48 h)
    
  • Philbrook Creek: 2 cfs → 1–2 cfs (48 h)
    
• Effective Period: May 4 – September 30 2026 (possible earlier start if reservoir storage ≥ 2,116 acre‑feet).
  
• Environmental Rationale:
  
  • Preserve cold‑water storage in Philbrook Reservoir.
    
  • Increase summer flow to Butte Creek via Hendricks Canal.
    
  • Reduce residence time in DeSabla Forebay to protect Chinook salmon from high temperatures.
    
• Regulatory Context:
  
  • Project on federal lands managed by U.S. Forest Service and BLM.
    
  • FERC to issue Environmental Assessment by May 29 2026.
    
• Stakeholder Coordination:
  
  • Requires support from California Department of Fish and Wildlife, National Marine Fisheries Service, and U.S. Fish and Wildlife Service.
    
• Public Participation:
  
  • Notice of Application Accepted issued February 26 2026.
    
  • Public can file comments, interventions, or protests via FERC’s Office of Public Participation.

Texas Eastern’s 10‑mile Pipeline Expansion Aims to Boost Gas Flow in Mississippi

Overview
Texas Eastern Transmission, LP has filed for a Certificate of Public Convenience and Necessity to construct a new 10.2‑mile, 36‑inch pipeline loop (Line 31) and a 1.6‑mile, 16‑inch lateral (Line 14‑P) in Madison County, Mississippi. The project will add up to 125,000 dekatherms per day of firm natural‑gas transport capacity and connect the mainline to Entergy Mississippi’s proposed Traceview Advanced Power Station. A new Ridgeland Compressor Station with three 1,500‑horsepower units and a meter‑and‑regulator station will support the expanded flow.

The Federal Energy Regulatory Commission (FERC) will issue an Environmental Assessment (EA) on June 15 2026, followed by a 30‑day public comment period. FERC’s 90‑day deadline for federal authorization decisions is set for September 13 2026, giving other federal and state agencies a clear timetable to review permits and approvals. The EA will address comments received during the scoping phase, including concerns about public safety, ecosystem impacts, soil compaction, property values, water resources, aquatic species, and cultural resources.

Key Elements

• Capacity boost: up to 125,000 dekatherms per day of additional firm gas transport.
• Infrastructure: 10.2 mi of 36‑inch pipeline, 1.6 mi of 16‑inch lateral, new compressor and meter‑regulator stations.
• Connection to power plant: links to Entergy Mississippi’s Traceview Advanced Power Station.
• Environmental review schedule: EA issuance June 15 2026; 30‑day comment period; federal authorization deadline September 13 2026.
• Stakeholder engagement: scoping notice sent to landowners, agencies, tribes, and public groups; comments on safety, ecosystems, and cultural resources to be incorporated.
• Regulatory framework: FERC’s Notice of Application (CP26‑75‑000) and compliance with the Natural Gas Act and NEPA.
• Public participation: eSubscription service for updates; Office of Public Participation contact for interventions or comments.

New Hydropower License in New Hampshire Opens the Door for Public Input on the Weston Dam Project

Overview

The U.S. Federal Energy Regulatory Commission (FERC) has accepted a hydroelectric license application from Powerhouse Systems, LLC for the Weston Dam Project on the Upper Ammonoosuc River in Coos County, New Hampshire. The project is a 220‑foot long, 15.5‑foot high concrete‑covered stone and timber crib dam that creates a 30‑acre reservoir with a storage capacity of 115 acre‑feet. Two Kaplan turbine‑generator units will produce an average of 2,357 megawatt‑hours per year, feeding power into the regional grid via a 34.5‑kV transmission line.

The application is now slated for environmental analysis under the Federal Power Act. Powerhouse proposes to operate the facility in a run‑of‑river mode, maintaining the impoundment at the existing flashboard crest elevation of 867.7 ft NGVD 29. This approach is intended to preserve fish and wildlife resources by ensuring that outflow approximates inflow, and no new pollution, mitigation, or environmental (PM&E) measures are being added to the project.

FERC is inviting public participation. Comments, protests, motions to intervene, and other filings must be submitted by 5:00 p.m. Eastern Time on June 5, 2026, with a final comment deadline of July 20, 2026. The agency encourages electronic filing through its eFiling and eComment systems, but paper submissions are also accepted. Applicants must also provide water‑quality certification or evidence of a waiver by the same June deadline.

Key Elements

• Project Scope: 220‑ft concrete‑covered dam, 30‑acre reservoir, 115 acre‑ft storage, two Kaplan turbines (50–550 cfs capacity).
  
• Run‑of‑River Operation: Maintains existing water levels; no new PM&E measures; designed to protect fish and wildlife.
  
• Environmental Review: Application accepted and ready for FERC’s environmental analysis under the Federal Power Act.
  
• Water‑Quality Certification: Must be filed by June 5, 2026, or a waiver must be documented.
  
• Public Participation Window:
  
  • Initial filings (comments, protests, motions to intervene) due June 5, 2026.
    
  • Final comments due July 20, 2026.
    
• Filing Channels: eFiling for documents, eComment for brief comments (≤10,000 characters); paper filings accepted at specified addresses.
  
• Intervention Rules: Only parties filing a motion to intervene become parties to the proceeding; all filings must be served on the applicant’s service list and relevant resource agencies.
  
• Contact Information: FERC Online Support (866‑208‑3676), Office of Public Participation (202‑502‑6595), and project contacts listed in the notice.
  
• Documentation Access: Full application available on FERC’s eLibrary; register online for email updates.

Texas Eastern Seeks FERC Approval to Revamp Pennsylvania Gas Lines Ahead of Mining Operations

Overview

Texas Eastern Transmission, LP has filed a formal request with the Federal Energy Regulatory Commission (FERC) to modify four existing natural‑gas pipelines in Greene County, Pennsylvania. The project—called the Longwall Mining Panel M2/M3 Project—will excavate, elevate, and replace segments of Lines 10, 15, 25, and 30 to ensure safe and efficient gas transport while CONSOL Energy conducts long‑wall mining starting in early 2028. No new right‑of‑way (ROW) will be created; the work will stay within the current ROWs, with Line 30 being relocated along abandoned pipeline corridors.

The estimated cost of the project is $142.2 million. FERC will conduct an environmental review, including a water‑quality certification under the Clean Water Act, and will issue a final environmental impact statement or assessment within 90 days of the review’s completion. The notice invites public participation—comments, protests, and motions to intervene—through April 27, 2026, giving stakeholders a chance to influence the decision before FERC moves forward.

Key Elements

• Pipeline modifications: 1.2 mi of Line 10 (30″), 1.1 mi of Line 15 (30″), 1.2 mi of Line 25 (36″), 0.9 mi of Line 30 (36″).
  
• Right‑of‑way: No new ROW; existing corridors maintained; Line 30 relocated along abandoned pipelines.
  
• Project purpose: Preserve safe, efficient operation during planned long‑wall mining by CONSOL Energy.
  
• Cost estimate: $142.2 million.
  
• Environmental review: FERC to issue a final environmental impact statement or assessment within 90 days of review completion.
  
• Water‑quality certification: Required under Section 401 of the Clean Water Act; Texas Eastern must submit PADEP certification or waiver.
  
• Public participation:
  
  • Comments, protests, and motions to intervene accepted until 5:00 p.m. ET on April 27, 2026.
    
  • No fee for filing; electronic filing encouraged via eComment or eFiling.
    
  • Intervenors gain the right to request rehearings and challenge FERC orders.
    
• Timeline:
  
  • Application filed March 23, 2026.
    
  • Intervention deadline April 27, 2026.
    
  • Environmental review milestones to follow within 90 days of FERC’s decision.

DOE Holds Secret Meetings to Shape the Future of Nuclear Fuel Under the Defense Production Act

Overview

The Department of Energy (DOE) announced a series of closed meetings under the Defense Production Act (DPA) to discuss the implementation of a voluntary agreement and related plans of action with key players in the nuclear fuel cycle. These meetings, held in March 2026, were deemed necessary to protect trade secrets and confidential commercial information, and therefore were not open to the public.

The closed sessions covered a broad spectrum of the nuclear fuel chain—from mining and milling of raw materials to the final stages of enrichment, conversion, and de‑conversion. Virtual (Teams) and hybrid formats were used, with the DPA Steering Committee meeting taking place both online and in person. The meetings were scheduled at regular intervals throughout March, allowing participants to review progress, address challenges, and coordinate actions across the entire supply chain.

For industry stakeholders, the notice signals a coordinated effort to streamline nuclear fuel production and ensure national security readiness. While the public cannot attend, the outcomes of these discussions will influence regulations, licensing, and investment decisions that shape the future of nuclear energy and its environmental footprint.

Key Elements

• Defense Production Act (DPA) Framework – Provides the legal basis for the DOE to convene closed meetings and enforce voluntary agreements.
• Voluntary Agreement & Plans of Action – A collaborative framework between DOE and nuclear fuel industry participants to align production, safety, and security goals.
• Closed Meetings – Restricted to protect trade secrets, commercial, and financial information; held under 5 U.S.C. § 552b©.
• Meeting Topics
  
  • Reactors – Design, licensing, and operational readiness.
    
  • Recycling & Reprocessing – Waste management and material recovery.
    
  • Mining & Milling – Extraction of uranium and other fissile materials.
    
  • Utilities – Power generation and grid integration.
    
  • Fabrication & Deconversion – Construction of fuel assemblies and dismantling of spent fuel.
    
  • Enrichment – Separation of isotopes for reactor use.
    
  • Conversion – Transformation of mined ore into usable fuel forms.
• Schedule & Format – Regular virtual meetings (Teams) throughout March 2026, with a hybrid DPA Steering Committee meeting on March 26.
• Contact & Oversight – Ms. Sarah McPhee‑Charrez, Chief of Staff, Nuclear Fuel Cycle, DOE, serves as the primary point of contact for further information.
• Implications – Outcomes will shape regulatory pathways, supply chain coordination, and national security priorities in the nuclear fuel sector.

Silicon Metal Trade Review: U.S. Industry Faces Import Challenges from Laos, Angola, and Thailand

Overview

The U.S. International Trade Commission (ITC) has concluded its investigations into silicon metal imports from Angola, Laos, and Thailand. The findings confirm that imports from Laos and Angola are sold in the United States at less than fair value (LTFV) and, in the case of Laos, are also subsidized by the Lao government. These conditions are deemed to materially injure or threaten injury to U.S. silicon metal producers. In contrast, imports from Thailand were found to be negligible, leading the ITC to terminate the countervailing duty investigation for that country.

The ITC’s determinations were made after a public hearing in February 2026 and a series of administrative reviews, including preliminary findings by the U.S. Department of Commerce. The final orders, issued on April 6 2026, will guide the application of duties and potential remedies to protect domestic silicon metal manufacturers. The outcome underscores the importance of monitoring international trade practices that affect critical materials used in electronics, solar panels, and other high‑tech industries.

Key Elements

• Material Injury from Laos and Angola – The ITC found that silicon metal from Laos and Angola is sold at LTFV, with Laos also receiving government subsidies, creating a competitive disadvantage for U.S. producers.
  
• Countervailing Duty Investigation Terminated for Thailand – Because imports from Thailand were negligible, the ITC concluded that a duty would not be warranted.
  
• Implications for U.S. Silicon Metal Industry – The determinations may lead to the imposition of duties on imports from Laos and Angola, potentially raising prices for U.S. consumers and altering supply chain dynamics.
  
• Trade Compliance and Enforcement – U.S. manufacturers and exporters must monitor tariff classifications (2804.69.10 and 2804.69.50) and ensure compliance with any new duty schedules.
  
• Broader Impact on Energy and Technology Sectors – Silicon metal is a key component in solar panels, batteries, and semiconductor manufacturing; changes in its import costs could influence renewable energy deployment and technological innovation.
  
• Future Monitoring – The ITC’s findings highlight the need for ongoing surveillance of foreign subsidies and pricing practices that may affect U.S. competitiveness in critical materials.

EPA Seeks Public Input on $600 K Settlement to Clean Up Bloomsburg Superfund Site

Overview

The U.S. Environmental Protection Agency (EPA) Region 3 has announced a proposed cost‑recovery settlement with Isolite Corporation for the Safety Light Corporation Superfund Site in Bloomsburg, Columbia County, Pennsylvania. Under the Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA), Isolite would pay the EPA $600,000 plus interest accrued through the notice’s publication date. In return, the EPA would agree not to pursue civil or administrative actions against Isolite related to the site’s contamination.

The settlement is intended to recover funds that can be used to remediate the site’s hazardous waste legacy, ensuring that cleanup proceeds without further legal delays. The EPA is inviting public comments on the proposal until May 11, 2026, and may adjust or withdraw the agreement if new information suggests it is inappropriate or inadequate. The process reflects the EPA’s commitment to transparency and stakeholder engagement in Superfund matters.

For geoscientists, environmental engineers, and natural resource professionals, this settlement illustrates how CERCLA’s cost‑recovery mechanisms can mobilize private sector resources for site remediation while protecting the agency’s ability to enforce cleanup standards.

Key Elements

• Parties Involved: EPA Region 3 (regulator) and Isolite Corporation (settling party).
  
• Financial Terms: Isolite to pay $600,000 plus interest calculated to the notice’s publication date.
  
• EPA Covenant: EPA will not sue or take administrative action against Isolite under CERCLA sections 106 and 107(a) concerning the site.
  
• Public Comment Period: 30 days (until May 11, 2026) for written comments; EPA may modify or withdraw the settlement based on feedback.
  
• Use of Funds: Proceeds earmarked for site cleanup and related remedial activities.
  
• Legal Framework: Settlement governed by CERCLA, 42 U.S.C. 9606 and 9607(a).
  
• Contact Information: Comments and requests for copies can be sent to EPA’s Regional Counsel, Jefferie Garcia, via email or phone.
  
• Transparency: EPA’s response to comments will be publicly available upon request.

Cove Point Seeks Permission to Re‑Export Imported LNG to New Markets

Overview

The U.S. Department of Energy (DOE) has received an application from Cove Point LNG, LP to obtain a short‑term blanket authorization to export liquefied natural gas (LNG) that was previously imported into the United States. The request covers up to 70 billion cubic feet (Bcf) of LNG over a two‑year period beginning July 8, 2026, and is limited to non‑Free Trade Agreement (FTA) countries that can receive LNG via ocean‑going carriers. The authorization would allow Cove Point to export the LNG from its terminal in Calvert County, Maryland, on behalf of itself and other title holders.

The proposal expands the U.S. LNG export footprint by enabling re‑exports to a broader set of trading partners, potentially boosting revenue for the company and diversifying global LNG supply routes. It also underscores the DOE’s role in balancing energy trade opportunities with regulatory compliance, including adherence to the Natural Gas Act (NGA) and environmental safeguards under the National Environmental Policy Act (NEPA).

Stakeholders have 30 days to submit protests, comments, or motions to intervene, with a filing deadline of May 11, 2026. DOE will review the application against NGA provisions, NEPA requirements, and other relevant regulations before issuing a final decision.

Key Elements

• Scope of Authorization: Up to 70 Bcf of previously imported LNG for a two‑year period (July 8, 2026 – July 7, 2028).
  
• Export Destinations: Non‑FTA countries capable of receiving LNG via ocean‑going carriers; excludes domestic production.
  
• Facility: Cove Point LNG Terminal, Calvert County, Maryland.
  
• Legal Basis: Application filed under the Natural Gas Act (NGA) § 3(a).
  
• Existing Authorization: Current blanket re‑export order expires July 7, 2026; new order to commence July 8, 2026 or upon issuance.
  
• Environmental Review: DOE must satisfy NEPA obligations before finalizing the order.
  
• Public Participation: 30‑day comment period ending May 11, 2026; protests, motions to intervene, and notices of intervention accepted electronically or by mail.
  
• Economic Implications: Potential increase in U.S. LNG export capacity and market diversification for non‑FTA partners.
  
• Regulatory Oversight: DOE will consider NGA requirements, DOE regulations, and any additional documents deemed relevant.

EPA Tweaks Oil & Gas Emission Rules to Ease Compliance While Tightening Monitoring

Overview

In March 2024 the U.S. Environmental Protection Agency (EPA) issued a final rule setting new source performance standards (NSPS) and emission guidelines (EG) for the crude oil and natural‑gas sector. After industry petitions, the agency finalized technical amendments in December 2025 and again in June 2026. The changes do not alter the underlying emission limits; instead, they clarify how operators must meet those limits, streamline compliance timelines, and adjust monitoring requirements.

The most significant updates address two areas:
1. Temporary flaring – operators may now flare associated gas for up to 72 hours (extendable only under “exigent circumstances”) instead of the previous 24‑hour cap. The rule adds record‑keeping and reporting requirements for any extended flaring.
2. Vent‑gas net‑heating‑value (NHV) monitoring – flares and enclosed combustion devices (ECDs) are exempt from continuous NHV monitoring when the gas stream’s NHV is high and no inert gases are added. When inert gases are introduced, operators must demonstrate that NHV stays above the required threshold, either through continuous monitoring or a 14‑day sampling demonstration.

Other technical clarifications include the use of alternative sampling methods, updated velocity limits for assisted flares, and a standardized reporting format that aligns with the Federal Register. The EPA’s regulatory analysis indicates modest cost savings for operators while maintaining or improving emissions control.

Key Elements

• Temporary Flaring Limits

  • Default maximum: 72 hours per incident.
    
  • Exigent circumstances (e.g., extreme weather, road closures, supply‑chain delays) may extend flaring beyond 72 hours, but total duration cannot exceed 72 hours after the circumstance ends.
    
  • Operators must keep detailed logs of the incident, the reason for extension, and submit annual reports.

• NHV Monitoring Requirements

  • Continuous monitoring or a 14‑day sampling demonstration is required only when inert gases (e.g., nitrogen, CO₂, water vapor) are added or when other operational changes could lower NHV.
    
  • High‑NHV streams (> 800 Btu/scf for pressure‑assisted flares, > 300 Btu/scf for steam‑ or air‑assisted flares) are exempt from monitoring.
    
  • Alternative test methods that prove ≥ 95 % methane/VOC combustion efficiency can waive continuous NHV monitoring.

• Record‑Keeping & Reporting

  • Operators must maintain time‑stamped records of all flaring incidents, NHV sampling, and monitoring system performance.
    
  • Annual reports (due 90 days after the compliance period) must include all required data, with a special reporting window on November 30 2026 for any earlier‑due reports.
    
  • The EPA’s electronic reporting interface (CEDRI) is the mandated submission platform.

• Other Technical Clarifications

  • Updated velocity limits for assisted flares to align with 40 CFR 60.18.
    
  • Expanded use of alternative sampling methods (e.g., GPA Midstream ²¹⁶⁶⁄₂₂₆₁).
    
  • Clarified that vent‑gas NHV must be expressed in Btu/scf at 20 °C, with volume‑percent conversions.

• Economic & Regulatory Context

  • The rule is deemed deregulatory under Executive Order 14192, with estimated annual cost savings of ~$208 k (2024‑2038).
    
  • No significant impact on small entities or tribal lands; no federalism or child‑protection implications.
    
  • The EPA’s analysis confirms that emission benefits are modest but that compliance costs are reduced through streamlined monitoring and reporting.

These amendments provide clearer guidance for oil and gas operators while preserving the EPA’s goal of reducing methane and VOC emissions from flares and combustion devices.

EU Moves to Tighten and Streamline Carbon Border Checks

Overview

The European Parliament’s first‑reading resolution on 10 September 2025 adopts a position to simplify and strengthen the Carbon Border Adjustment Mechanism (CBAM). The CBAM is a trade‑related climate policy that requires importers of certain goods to pay a carbon fee equivalent to the emissions embedded in those products, thereby preventing “carbon leakage” and ensuring that EU producers are not disadvantaged by stricter environmental rules.

The resolution builds on the Commission’s proposal (COM(2025)0087) and aims to reduce administrative burdens for businesses while tightening enforcement and expanding the scope of the mechanism. It aligns the CBAM more closely with the EU Emissions Trading System (ETS) and the EU’s 2030 and 2050 climate targets, ensuring that imported goods are subject to the same carbon pricing as domestic production.

The Parliament’s position will be forwarded to the Council, the Commission, and national parliaments. Once adopted by the Council, it will become Regulation (EU) 2025/2083, the final legislative act that will govern the CBAM’s implementation across the EU.

Key Elements

• Simplified Certification – Streamlined procedures for obtaining carbon certificates, reducing paperwork and administrative costs for importers.
  
• Expanded Product Coverage – Inclusion of additional goods (e.g., steel, cement, aluminum, fertilizers) to broaden the mechanism’s reach.
  
• Stronger Enforcement – Enhanced penalties for non‑compliance and tighter monitoring of import data.
  
• Alignment with EU ETS – Harmonisation of CBAM carbon pricing with the EU Emissions Trading System to avoid double‑counting and ensure consistency.
  
• Budgetary Considerations – Assessment of the CBAM’s fiscal impact, with provisions to offset costs for small and medium‑sized enterprises.
  
• Trade‑Fairness Safeguards – Measures to ensure the CBAM complies with World Trade Organization rules and does not constitute a discriminatory trade barrier.
  
• Stakeholder Consultation – Ongoing dialogue with industry, trade partners, and environmental groups to refine implementation details.
  
• Legislative Coordination – The resolution will be transmitted to the Council and Commission for final adoption as Regulation (EU) 2025/2083, ensuring a unified EU-wide application.

EU and Switzerland Align GPS‑Like Systems: A New Satellite Navigation Partnership

Overview
The European Parliament has granted its consent to a fresh cooperation agreement between the European Union and the Swiss Confederation on European Satellite Navigation Programmes. This pact builds on the existing Galileo framework, the EU’s global satellite navigation system, and extends its reach to Swiss territory and institutions. By formalising joint participation, the agreement ensures that Swiss users—ranging from scientific research to commercial logistics—can seamlessly access and contribute to the same high‑precision positioning services that underpin modern geoscience, energy infrastructure, and trade logistics.

The resolution confirms that the Council’s draft decision to conclude the agreement has been approved, and instructs the Parliament’s President to communicate the EU’s stance to the Council, the Commission, and the governments and parliaments of all Member States and Switzerland. This procedural step underscores the EU’s commitment to a coordinated, multi‑stakeholder approach, while also respecting Switzerland’s status as a non‑EU partner.

For professionals in earth, atmospheric, and ocean sciences, the agreement means enhanced data interoperability, shared research opportunities, and a unified regulatory framework for satellite navigation. It also supports the broader European strategy of reducing reliance on foreign navigation systems, thereby strengthening resilience for critical infrastructure, scientific monitoring, and cross‑border trade.

Key Elements

• Consent Granted – The European Parliament formally consents to the EU‑Switzerland cooperation agreement on satellite navigation.
  
• Joint Participation – Switzerland will integrate its national navigation assets with the EU’s Galileo system, enabling shared access to high‑accuracy positioning data.
  
• Procedural Coordination – The Parliament’s President will forward the EU’s position to the Council, Commission, and all relevant governments and parliaments.
  
• Scientific and Commercial Benefits – Unified navigation services improve data quality for geoscience research, energy grid management, and maritime logistics.
  
• Regulatory Alignment – The agreement harmonises technical standards and legal frameworks, facilitating cross‑border collaboration and trade.
  
• Strategic Autonomy – By expanding the Galileo footprint, the EU and Switzerland enhance their independence from external satellite navigation providers.

EPA Proposes New Hazardous‑Waste Signing Rule to Speed Clean‑ups

Overview

The Environmental Protection Agency (EPA) has issued a proposed rule to update its EPAAR (Environmental Protection Agency Acquisition Regulation) text, specifically adding a new clause that expands the use of Uniform Hazardous Waste Manifests. Currently, only a local clause allows contractors to sign these manifests at Superfund sites. The proposed change would let contractors sign the manifest directly at any EPA worksite—whether the site is a Superfund location or a non‑Superfund site—when removing hazardous or non‑hazardous materials.

This update is designed to streamline remediation efforts by permitting work to proceed even when EPA personnel are not physically present on the site. By simplifying the paperwork and reducing the need for on‑site EPA oversight, the rule aims to accelerate cleanup timelines and lower administrative burdens for contractors and agencies alike.

Stakeholders—including geoscientists, environmental engineers, and natural‑resource contractors—are invited to comment on the proposal by June 8, 2026. The EPA encourages public participation through its docket system (EPA‑HQ‑OMS‑2025‑0037; FRL‑13150‑01‑OMS) and provides multiple channels for submitting feedback.

Key Elements

• New EPAAR clause that authorizes contractors to sign Uniform Hazardous Waste Manifests at EPA worksites.
  
• Applicability to all sites: both Superfund and non‑Superfund locations are covered.
  
• Enables work without EPA personnel on site, reducing delays caused by staffing constraints.
  
• Streamlines procurement and compliance by consolidating manifest signing into a single, standardized clause.
  
• Comment period: public comments due by June 8, 2026.
  
• Docket ID: EPA‑HQ‑OMS‑2025‑0037; FRL‑13150‑01‑OMS; submissions can be made online, by mail, or via phone.
  
• Contact: Brandon R. Hawkins, Policy Division, Office of the Chief Procurement Officer, EPA (202) 250‑8897.

Expanding Louisiana’s LNG Hub: Sabine Pass Stage 5 Draft Environmental Review Opens for Public Input

Overview
The Federal Energy Regulatory Commission (FERC) has released a draft Environmental Impact Statement (EIS) for the Sabine Pass Stage 5 Expansion Project. The project, led by Sabine Pass Liquefaction, LLC and partners, seeks to add three new liquefaction trains to the existing Sabine Pass LNG terminal in Cameron Parish, Louisiana, and to construct a 55.6‑mile, 48‑inch natural‑gas pipeline (the Sabine Crossing Pipeline) that will run through Texas and Louisiana. Additional facilities include new compressor stations, meter stations, and a greenfield compressor station on the existing Creole Trail Pipeline System.

The draft EIS evaluates how construction and operation of these facilities would affect wetlands, forests, visual resources, and air quality. FERC concludes that most impacts would be temporary or short‑term, and that with the proposed avoidance, minimization, and mitigation measures the overall environmental effects would be less than significant. The analysis also notes acceptable safeguards to reduce the risk of hazardous incidents.

Stakeholders are invited to review the EIS and submit comments by 5:00 p.m. Eastern Time on May 26, 2026. FERC will consider all comments in its final decision. Public comment sessions will be held on April 21, 2026, at the Sabine Pass Community Center, and electronic or paper comments can be filed through FERC’s online platforms or by mail.

Key Elements

• Project Scope

  • Three new liquefaction trains (Trains 7‑9) at the Sabine Pass LNG terminal.
    
  • 55.6‑mile Sabine Crossing Pipeline (48‑inch diameter).
    
  • New compressor station (Hamshire), six meter stations, pig traps, and mainline valves.
    
  • Expansion of existing compressor stations (Gillis, Tarpon) and modification of a delivery meter station.
    

• Environmental Findings

  • Limited, mostly temporary impacts during construction.
    
  • Long‑term effects on wetlands, forested lands, visual resources, and air quality.
    
  • Mitigation measures (e.g., buffer zones, spill containment, air‑quality monitoring) deemed sufficient to keep impacts “less than significant.”
    

• Regulatory Context

  • Draft EIS prepared under the National Environmental Policy Act (NEPA) and FERC’s implementing regulations.
    
  • Cooperating agencies: U.S. Army Corps of Engineers, DOT, Coast Guard, NOAA, and DOE.
    
  • FERC’s role: authorize interstate natural‑gas facilities under the Natural Gas Act, balancing economic need and environmental protection.
    

• Public Participation

  • Comment deadline: May 26, 2026, 5:00 p.m. ET.
    
  • Four submission methods: eComment, eFiling, paper mail, or oral comment session (April 21, 2026).
    
  • Oral comments recorded by court reporter; transcript available on FERC’s eLibrary.
    

• Next Steps

  • FERC will review public comments and finalize the EIS.
    
  • If approved, a Certificate of Public Convenience and Necessity will be issued, allowing construction and operation of the expanded facilities.

Alabama Solar Power Project Gains Green Light: TVA Approves 200‑MW Spring Valley II Facility

Overview

The Tennessee Valley Authority (TVA) has formally adopted the preferred alternative for the Spring Valley II Solar Project, a 200‑megawatt (MW) photovoltaic (PV) plant that will occupy roughly 740 acres of a 2,426‑acre site in Colbert County, Alabama. The project will be built and operated by Spring Valley Solar, LLC, a subsidiary of Urban Grid, under a 20‑year power purchase agreement (PPA) with TVA. To connect the plant to TVA’s grid, a new 161‑kV substation and transmission line upgrades will be constructed.

The environmental assessment, released in December 2025 and finalized in January 2026, concludes that the project’s impacts will be minor to moderate. With best‑management practices (BMPs), erosion controls, and habitat restoration, the plant is expected to avoid adverse effects on groundwater, federally listed species, and historic properties. The project may modestly affect prime farmland and visual resources, but mitigation measures—including native vegetation buffers and careful siting of transmission infrastructure—are designed to minimize these impacts.

This development aligns with TVA’s 2019 Integrated Resource Plan, which calls for up to 14 GW of solar capacity by 2038. By adding 200 MW of clean, renewable electricity, the project supports regional energy reliability, reduces greenhouse‑gas emissions, and provides local economic benefits while maintaining stewardship of the surrounding natural and cultural resources.

Key Elements

• Capacity & Site: 200 MW AC solar PV, 740 acres of land in Colbert County, Alabama.
  
• Infrastructure: New 161‑kV substation and upgraded transmission lines to interconnect with TVA’s grid.
  
• PPA & Timeline: 20‑year power purchase agreement between TVA and Spring Valley Solar, LLC.
  
• Alignment with IRP: Supports TVA’s 2019 Integrated Resource Plan goal of expanding solar capacity to meet future demand.
  
• Environmental Impacts: Minor to moderate effects on land use, soil, wildlife, and visual resources; no direct adverse impact on groundwater or federally listed species.
  
• Mitigation Measures:
  
  • BMPs for erosion, sediment control, and habitat restoration.
    
  • Native vegetation buffers (30–50 ft) for visual screening.
    
  • Historic resource protection: updates to NRHP nominations, vegetative and mesh screens around Belle Mont Mansion, avoidance of archaeological sites.
    
• Public Involvement: Extensive scoping and comment periods (NOI, Draft EIS, Final EIS) with input from local stakeholders, environmental agencies, and tribal governments.
  
• Economic & Social Benefits: Job creation during construction and operation, increased renewable energy supply for TVA customers, and potential return of the site to agriculture after decommissioning.

BLM Seeks Public Input on New Form to Grant Private Land Access for Public Land Use

Overview
The Bureau of Land Management (BLM) has announced a new information‑collection request under the Paperwork Reduction Act (PRA) to streamline the process by which the public can obtain permission to cross private property in order to reach BLM‑managed lands within the Carrizozo Land Partnership. The proposed form, tentatively titled “Carrizozo Accesses Form,” will capture basic details about the requester, the intended route, and the purpose of the crossing. The data will be used by BLM and participating private landowners to verify requests, maintain a record of crossings, and ensure that access routes are used responsibly.

The BLM’s goal is to balance public access to valuable public lands with the protection of private landowners’ interests. By formalizing the request process, the agency hopes to reduce informal or unrecorded crossings that can lead to disputes or damage. The PRA framework requires that the BLM obtain approval from the Office of Management and Budget (OMB) before collecting the information, and the agency is inviting public comments on the proposed collection’s necessity, burden, and potential improvements.

Comments on the proposed information collection are due by June 8, 2026. Stakeholders—including landowners, recreational users, and industry groups—can submit written or electronic comments to the BLM’s Office of Management and Budget Clearance Officer or via email. The BLM will consider all feedback when requesting an OMB control number and finalizing the form.

Key Elements

• New Information Collection – A formal request for an OMB control number for the Carrizozo Accesses Form.
  
• Purpose – To verify and record requests for crossing private land to access BLM lands, ensuring responsible use and protecting private landowners.
  
• Burden Estimate – Approximately 100 forms per year, each taking about 10 minutes to complete, with no monetary cost to respondents.
  
• PRA Compliance – The collection is subject to the Paperwork Reduction Act; the BLM seeks public input on its necessity and burden.
  
• Comment Period – Open until June 8, 2026; comments can be mailed or emailed to the BLM PRA Office.
  
• Contact Information – Darrin King (PRA Clearance Officer) and Jesse Vinson (information collection contact) are available for inquiries.
  
• Public Record – Comments submitted will be part of the public record and may be made publicly available.
  
• Technology Use – The BLM encourages electronic submission of responses to reduce paperwork and improve data quality.
  
• Alignment with BLM Mission – Supports the agency’s goal of sustaining the health, diversity, and productivity of public lands for current and future generations.

FERC Opens Public Scoping on a New Natural‑Gas Pipeline in Pennsylvania and New York

Overview

The Federal Energy Regulatory Commission (FERC) has announced a scoping period to gather public input on the environmental impacts of the proposed Constitution Pipeline and Wright Interconnect Projects. These projects would add 124.4 miles of 30‑inch natural‑gas pipeline and associated facilities across Susquehanna County, Pennsylvania, and Broome, Chenango, and Schoharie Counties, New York, providing up to 650,000 dekatherms per day of additional transport capacity to New York and New England markets.

FERC’s notice follows petitions filed by Constitution Pipeline Company, LLC and Iroquois Gas Transmission System, L.P. in 2025 and 2026 to re‑issue certificates of public convenience and necessity. A final Environmental Impact Statement (EIS) was issued in 2014, but the projects were never completed. The Commission is now reviewing updated filings to determine whether new environmental analysis is required and, if so, whether an Environmental Assessment (EA) or a new EIS should be prepared.

Comments are solicited on any environmental changes since the 2014 EIS, including potential impacts, reasonable alternatives, and mitigation measures. The scoping deadline is May 4, 2026, and public participation can be submitted electronically or by paper. The outcome of this scoping will shape the scope of the forthcoming environmental document and ultimately influence FERC’s decision on the projects.

Key Elements

• Project Scope: 124.4 mi of new 30‑inch pipeline, two meter stations, two interconnections, ten communication towers, eleven mainline valves, and a pig launcher/receiver.
  
• Capacity: Up to 650,000 dekatherms per day (Dth/d) of natural‑gas transport to New York and New England.
  
• Land Use: Approximately 1,871.5 acres disturbed during construction; 761.5 acres retained for permanent operation; the remainder to be restored.
  
• Existing Rights‑of‑Way: About 9 % of the route follows existing pipeline, utility, or road corridors.
  
• NEPA Process: FERC will issue an EA or EIS based on scoping findings; public comments will be considered in the final decision.
  
• Historic Preservation: Section 106 consultation with state historic preservation offices, Indian tribes, and other stakeholders will be conducted to assess impacts on historic properties.
  
• Public Participation: Comments due by May 4, 2026; submission methods include eComment, eFiling, and paper mail.
  
• Timeline: Scoping period opens now; subsequent environmental document preparation and comment periods will follow.
  
• Stakeholder Engagement: Environmental mailing list includes federal, state, local agencies, elected officials, landowners, and public interest groups.

Allete’s Little Falls Hydroelectric Project Seeks New License, Sets Timeline for Environmental Review

Overview
Allete, Inc. has filed a new major license application (Project No. 2532‑098) with the Federal Energy Regulatory Commission (FERC) for the Little Falls Hydroelectric Project on the Mississippi River in Morrison County, Minnesota. The project is a run‑of‑river facility that currently generates about 30,583 MWh per year and will continue to operate in the same mode under the new license. The application includes detailed plans for a 477‑acre reservoir, multiple spillways, and two powerhouses totaling 4.72 MW of installed capacity.

The filing is not yet ready for environmental analysis. FERC has outlined a preliminary schedule: a deficiency letter and additional information request may be issued in July 2026, followed by a notice of readiness for environmental analysis in September 2026. Allete must submit final amendments within 30 days of that notice. The public can review the application and related documents through FERC’s eLibrary portal, and the Commission has provided contact points for inquiries and interventions.

Key Elements
- New Major License: Project No. 2532‑098, filed March 24, 2026.
- Location: Little Falls Hydroelectric Project, Mississippi River, Morrison County, MN.
- Reservoir & Spillways: 477‑acre reservoir; 11 distinct spillway structures (gated, ogee, log sluiceway, rubber dam, etc.).
- Powerhouses: Two units (800 kW) and four units (3.92 MW) for a total of 4.72 MW.
- Annual Production: ~30,583 MWh, run‑of‑river operation.
- Schedule:
- July 2026 – possible deficiency letter or additional information request.
- September 2026 – notice of readiness for environmental analysis.
- Final amendments due within 30 days after that notice.
- Public Access: Documents available via FERC eLibrary (docket P‑2532).
- Contact Points:
- Environmental compliance: Greg Prom, Minnesota Power/Allete.
- FERC Office of Public Participation: (202) 502‑6595.
- eLibrary support: (866) 208‑3676 or (202) 502‑8659 (TTY).

Allete’s Pillager Hydroelectric Project: New Relicensing Notice Sets 2026 Timeline

Overview

The U.S. Federal Energy Regulatory Commission (FERC) has announced that Allete, Inc. has filed a new major license (Project No. 2663‑067) for the Pillager Hydroelectric Project on Minnesota’s Crow Wing River. The application, submitted on March 24, 2026, seeks to continue operating the existing run‑of‑river facility, which generates roughly 7,600 MWh annually, under a new license while maintaining its current infrastructure and operational mode.

This notice outlines the procedural schedule for the relicensing process, including potential deficiency letters and additional information requests in July 2026, a notice of acceptance in September 2026, and a 30‑day deadline for final amendments following that acceptance. The application is not yet ready for environmental analysis, meaning that environmental review will commence only after the notice of readiness is issued.

The filing is publicly available through FERC’s eLibrary, and interested parties—including local communities, environmental groups, and industry stakeholders—can review the full application, submit comments, or request rehearing. Contact details for Allete’s compliance team and FERC’s public participation office are provided to facilitate engagement.

Key Elements

• Project Scope

  • 698‑acre reservoir on the Crow Wing River.
    
  • 357‑ft concrete gravity rollway dam with 18 steel slide gates.
    
  • Two 1.52 MW generating units in a 98‑ft reinforced concrete powerhouse.
    
  • Run‑of‑river operation with ~7,601 MWh annual output.

• Relicensing Objectives

  • Obtain a new major license to continue current operations.
    
  • Maintain existing dam and reservoir structures without major modifications.

• Procedural Timeline

  • July 2026: Potential deficiency letter and additional information request.
    
  • September 2026: Notice of acceptance/ready for environmental analysis.
    
  • 30 days after acceptance: Deadline for final amendments (per 18 CFR 2.1).

• Public Access & Participation

  • Documents available via FERC eLibrary (docket P‑2663).
    
  • Public inquiries and interventions handled by FERC’s Office of Public Participation.
    
  • Contact information for Allete’s Senior Environmental Compliance Specialist and FERC support provided.

• Environmental Review Status

  • Application not yet ready for environmental analysis; review will begin after the notice of readiness.
    
  • Future environmental assessments will consider impacts on river flow, reservoir ecology, and downstream communities.

• Stakeholder Engagement

  • Opportunities for comments, interventions, and rehearing requests.
    
  • Online registration for email notifications of project updates.

Delaware River Basin Commission Opens Virtual Doors: Public Hearing & Business Meeting on Water Management

Overview

The Delaware River Basin Commission (DRBC) has scheduled a public hearing on May 6, 2026 and a subsequent business meeting on June 11, 2026. Both events will be held online, allowing stakeholders across the basin to participate remotely. The hearing will review draft decisions on water withdrawals, discharges, and other projects that could significantly affect the basin’s water resources, while the business meeting will adopt the FY 2027‑2029 Water Resources Program, approve the 2027‑2028 budgets, and finalize budget allocations among the signatory parties.

These meetings are part of the DRBC’s ongoing effort to manage the Delaware River Basin in accordance with the Delaware River Basin Compact (Public Law 87‑328). Decisions made here influence water quality, supply, and ecosystem health for communities, industries, and natural habitats throughout the region. Public input is encouraged through written comments and optional open‑comment sessions, ensuring that local voices help shape basin policy.

The commission’s transparent, virtual format—complete with livestreams, closed captioning, and phone‑in options—highlights its commitment to accessibility and public engagement. Outcomes from these sessions will set the stage for future water‑resource projects, budget allocations, and regulatory actions that affect geoscience research, environmental stewardship, and regional development.

Key Elements

• Dates & Format

  • Public hearing: May 6, 2026, 1:30 p.m. (virtual)
    
  • Business meeting: June 11, 2026, 10:00 a.m. (virtual)
    
  • Both events livestreamed on YouTube with closed captioning.

• Public Participation

  • Written comments accepted until 5:00 p.m., May 11, 2026.
    
  • Optional open‑comment session after the June 11 meeting (up to one hour).
    
  • Toll‑free phone access for participants with limited internet.

• Agenda Highlights

  • Review of draft dockets for water withdrawals, discharges, and other projects.
    
  • Adoption of the FY 2027‑2029 Water Resources Program.
    
  • Approval of the 2027‑2028 current expense and capital budgets.
    
  • Allocation of budget responsibilities among basin signatory parties.

• Accessibility & Support

  • Live captioning on webinar and YouTube streams.
    
  • ADA accommodations available via the Commission Secretary.
    
  • Web‑based comment system ensures all submissions are captured and acknowledged.

• Follow‑Up Procedures

  • Items may be postponed or added up to ten days before the hearing.
    
  • Deferred items may trigger additional comment periods or future meetings.
    
  • All hearing materials, draft decisions, and resolutions posted on the DRBC website at least ten days prior to the hearing.

• Contact Points

  • Kate Schmidt (Commission staff) for comment‑system assistance.
    
  • Donna Woolf for public records access.
    
  • David Kovach for hearing‑item inquiries.

These elements collectively provide a clear framework for stakeholders to influence water‑resource management decisions that shape the environmental and economic future of the Delaware River Basin.

NOAA Extends Public Comment Deadline for Deep-Seabed Mining Licenses

Overview

On March 23 2026, the National Oceanic and Atmospheric Administration (NOAA) announced that it had received two applications for deep‑seabed mining exploration licenses—one from American Metal Resources, LLC (AMR) and another from SeaX, Inc. (SeaX). The agency scheduled a 60‑day public comment period and virtual hearings to allow stakeholders to weigh in on the potential environmental, economic, and regulatory impacts of these proposals.

NOAA originally set the public comment deadline for May 22 2026. However, a brief technical issue with its e‑Portal prevented the application materials from being available for one business day. To preserve the statutory 60‑day comment window required by the Deep Seabed Hard Mineral Resources Act (DSHMRA), NOAA extended the deadline to May 26 2026. This extension ensures that the public, scientists, industry, and other interested parties have adequate time to review the applications and submit feedback.

The notice underscores NOAA’s commitment to transparent decision‑making in the emerging field of deep‑seabed mining, a sector that holds promise for resource extraction but also raises significant environmental and geopolitical questions. By extending the comment period, NOAA is balancing the need for timely licensing with the public’s right to participate in shaping policies that affect the ocean’s deep‑sea ecosystems.

Key Elements

• Applications Received: AMR and SeaX, each seeking exploration licenses for deep‑seabed mining.
• Original Comment Deadline: May 22 2026.
• Extension Granted: Deadline moved to May 26 2026 to meet the 60‑day requirement under DSHMRA.
• Reason for Extension: One‑day e‑Portal outage that delayed public access to application materials.
• Public Engagement: Virtual public hearings scheduled to discuss the applications.
• Contact: Bryan Cole, NOAA Office for Coastal Management (301‑233‑2998).
• Regulatory Framework: Deep Seabed Hard Mineral Resources Act (DSHMRA) and related statutes (30 U.S.C. 1426(a)(1)).
• Agency Involved: Office for Coastal Management, National Ocean Service, NOAA, Department of Commerce.

Avista’s Spokane River Dam Rehab: FERC Green‑Lights Environmental Assessment

Overview

Avista Corporation has submitted a non‑capacity amendment to the Spokane River Hydroelectric Project (Project No. 2545) to rehabilitate the North Channel Dam by replacing all existing spillway gates. The project spans federal and tribal lands—including portions of the Coeur d’Alene Reservation—in Washington and Idaho.

The Federal Energy Regulatory Commission (FERC) has completed an Environmental Assessment (EA) under the National Environmental Policy Act. The EA concludes that, with appropriate environmental safeguards, the proposed amendment would not constitute a major federal action that significantly affects the quality of the human environment.

Public comments on the EA are solicited until May 4, 2026, with a strong encouragement to file electronically via FERC’s eFiling system. The assessment and related documents are available on FERC’s website under docket P‑2545.

Key Elements

• Project Scope: Replacement of all spillway gates on the North Channel Dam to improve safety and operational efficiency.
  
• Location & Jurisdiction: Spokane River corridor in Spokane, Lincoln, and Stevens counties (WA) and Kootenai & Benewah counties (ID), including federal and tribal lands.
  
• Environmental Impact: EA finds no major federal action; environmental measures are required to mitigate identified impacts.
  
• Public Participation: Comments due May 4, 2026; electronic filing preferred; paper submissions accepted.
  
• Tribal Involvement: Project affects the Coeur d’Alene Reservation; tribal consultation is part of the review process.
  
• Regulatory Framework: Compliance with 18 CFR part 380 (FERC) and the National Environmental Policy Act of 1969.
  
• Access to Documents: EA available via FERC’s “elibrary” using docket number P‑2545.

Allete’s Crow Wing River Hydroelectric Project: New License Filed, Timeline Set

Overview

Allete, Inc. has submitted a new major license application (Project No. 2454‑088) to the Federal Energy Regulatory Commission (FERC) for the Sylvan Hydroelectric Project on Minnesota’s Crow Wing River. The proposal seeks to continue operating the existing run‑of‑river plant, which generates roughly 9,963 MWh annually with a total installed capacity of 1.8 MW. The project features a 1,211‑acre reservoir, multiple earth embankments, a concrete‑core spillway, and three 600‑kW turbines.

The application is currently not ready for environmental analysis. FERC has outlined a preliminary schedule: a deficiency letter (if needed) and an additional information request are both slated for July 2026, followed by a notice of readiness for environmental analysis in September 2026. Allete must file any final amendments within 30 days of that notice. All documents are publicly available through FERC’s eLibrary, and interested parties can submit comments or interventions via the Office of Public Participation.

For stakeholders in geoscience, energy, and natural resource management, this filing signals a continued investment in small‑scale hydroelectric generation while highlighting the regulatory steps required to ensure environmental compliance and public transparency.

Key Elements

• New Major License: Project 2454‑088 for the Sylvan Hydroelectric Project.
  
• Location: Crow Wing River, Cass, Crow Wing, and Morrison Counties, Minnesota.
  
• Capacity & Production: 1.8 MW total, ~9,963 MWh/year (run‑of‑river mode).
  
• Infrastructure:
  
  • 1,211‑acre reservoir.
    
  • 78‑ft left earth embankment with concrete core.
    
  • 243.8‑ft spillway with vertical slide gates and inflatable rubber dams.
    
  • 41‑ft right earth embankment with concrete core.
    
  • Additional earth embankments (730 ft, 830 ft) with auxiliary spillway.
    
• Environmental Analysis Status: Not yet ready; scheduled for September 2026.
  
• Timeline:
  
  • Deficiency letter (if needed): July 2026.
    
  • Additional information request (if needed): July 2026.
    
  • Notice of readiness for environmental analysis: September 2026.
    
  • Final amendments deadline: 30 days after the notice.
    
• Public Access: Documents available via FERC eLibrary (docket P‑2454).
  
• Contact Points:
  
  • FERC Office of Public Participation: (202) 502‑6595.
    
  • FERC Online Support: (866) 208‑3676 / (202) 502‑8659.
    
  • Allete Environmental Compliance: Greg Prom, (218) 355‑3191.
    
• Regulatory Framework: Federal Power Act (16 U.S.C. 791(a)‑825®); 18 CFR 2.1 governing amendment deadlines.

EU Puts a Stop on Cancelling Carbon Credits to Keep the Carbon Market Liquid

Overview

The European Union is amending its Market Stability Reserve (MSR) rules to halt the automatic invalidation of allowances that exceed 400 million units. Since 2023, the MSR has been removing surplus allowances to restore balance in the EU Emissions Trading System (ETS). Over 3.2 billion allowances have already been invalidated, tightening supply and raising prices.

By stopping further invalidations, the EU aims to retain a larger pool of allowances in the reserve. This buffer will be available for future releases if the market becomes tight after the mid‑2030s, helping to smooth price swings and support the EU’s 2030 climate target and the 2050 net‑zero goal.

The change is part of the broader “Fit for 55” package and does not require additional EU funding. It simply modifies an existing decision, keeping the ETS framework intact while enhancing its resilience.

Key Elements

• Cease invalidation of allowances above 400 million in the MSR from the date the amendment enters into force.
  
• Preserve a larger reserve of allowances to act as a liquidity buffer for future market tightening.
  
• Maintain market stability by preventing further supply shocks that could raise carbon prices unpredictably.
  
• No new budgetary impact: the amendment is a regulatory change, not a financial measure.
  
• Supports EU climate commitments (2030 emissions reduction target, 2050 net‑zero) by ensuring a more predictable carbon market.
  
• Aligned with the “Fit for 55” package and the EU’s broader climate and energy strategy.
  
• No direct effect on other EU policies; it only tweaks the MSR’s operational rule.

Keep USGS Strong Act: Protecting the Nation’s Earth Science Backbone

The Keep USGS Strong Act is a bipartisan effort to shield the United States Geological Survey (USGS) from the federal hiring freeze and workforce reductions that have threatened its ability to conduct essential research and data collection. By exempting the agency from the Presidential Memorandum on hiring freezes and any reduction in force when appropriations are in place, the bill aims to preserve the scientific workforce that underpins national safety, environmental stewardship, and resource management.

USGS’s work spans a wide array of critical domains: monitoring the Great Lakes’ water quality and invasive species, operating a nationwide seismic network that informs building codes and early‑warning systems, tracking surface and groundwater resources for drought‑prone and urban areas, and producing topographic and geospatial data used by governments, researchers, and the public. The agency also studies natural hazards—volcanoes, landslides, floods—and conducts long‑term ecosystem and biodiversity monitoring. These efforts directly influence fisheries management, pollution control, disaster preparedness, and sustainable development of mineral and energy resources.

By ensuring a stable workforce and uninterrupted data streams, the Act supports informed decision‑making across government, industry, and communities. It safeguards the open‑data mission that empowers local governments, businesses, and citizens to plan resilient infrastructure, protect natural resources, and respond effectively to environmental risks.

Key Elements

• Exemption from Hiring Freeze: USGS is not subject to the 2025 Presidential Memorandum on hiring freezes or any extensions.
  
• Protection Against Workforce Reductions: No reduction in force or significant employee cuts are allowed if Congress has appropriated funds for salaries and expenses.
  
• Lease Stability: USGS leases of real property cannot be canceled without the Director’s approval.
  
• Broad Scientific Mandate: The bill highlights USGS’s roles in Great Lakes monitoring, seismic hazard assessment, water resource management, mapping, natural hazard research, ecosystem monitoring, and mineral/energy resource assessment.
  
• Open‑Data Commitment: Emphasizes the agency’s provision of freely accessible geospatial and scientific data to support public safety, environmental conservation, and sustainable development.
  
• Policy and Public Impact: By maintaining a robust workforce, the Act ensures continuous data collection that informs building codes, disaster preparedness, water quality standards, and conservation policies.

Justice for the River: $3.3 Million Compensation for Gold King Mine Spill Victims

Overview
In August 2015, the Gold King Mine in San Juan County, Colorado, released more than 3 million gallons of acid‑laden wastewater into the Animas and San Juan Rivers, contaminating water supplies, harming livestock, and damaging local businesses. The Gold King Mine Spill Compensation Act of 2025 seeks to provide a federal remedy for those harmed by that event. The bill authorizes the Environmental Protection Agency (EPA) Administrator to review, adjudicate, and pay claims for specific, documented damages that were not otherwise compensated.

The Act defines “covered damages” to include injuries, lost business income (excluding vacation rentals), livestock relocation expenses, and diminished agricultural yields that occurred between August 5 2015 and December 31 2015. It excludes response costs and emotional distress. “Injured persons” are homeowners, livestock grazer, farmers, or recreation businesses that have not settled for more than $2,500, have not received a judgment, and whose claims were denied or inadequately compensated by the Administrator. Claims must have been filed by August 5 2017.

The bill sets a $3.3 million emergency appropriation for fiscal year 2025, establishes a 180‑day deadline for the Administrator to determine and fix payment amounts, and allows claimants to accept a settlement that releases all related claims. Claimants may also pursue alternative legal remedies, but any election is final. A 60‑day window for judicial review and a 90‑day congressional report on claim disposition are also required.

Key Elements

• Compensation Scope

  • Covers injuries, lost income (Aug 5–Dec 31 2015), livestock relocation costs (Aug 5–Oct 15 2015), and crop yield losses (Aug 5–Dec 31 2015).
    
  • Excludes response costs, emotional distress, and punitive damages.

• Eligibility Criteria

  • Must be a homeowner, livestock grazer, farmer, or recreation business.
    
  • No prior settlement >$2,500 or court judgment related to the spill.
    
  • Claim filed by Aug 5 2017; business must be operational and not mine‑related.

• Administrative Process

  • EPA Administrator investigates, adjudicates, and settles claims.
    
  • State of Colorado law applies to damage calculations.
    
  • Payments limited to actual compensatory damages and the amount originally claimed.

• Payment and Acceptance

  • Administrator must determine payment amounts within 180 days of enactment.
    
  • Acceptance of payment releases all related claims against the U.S. and requires a perjury‑certified statement.

• Judicial Review

  • Claimants may file a civil action within 60 days of a final decision to modify or set aside the decision.
    
  • Courts review the Administrator’s record; decisions supported by substantial evidence are upheld.

• Reporting and Funding

  • Administrator must submit a congressional report within 90 days of processing all claims.
    
  • $3.3 million emergency appropriation available for FY 2025, designated under the Balanced Budget and Emergency Deficit Control Act.

Building the Arctic’s Backbone: U.S. Calls for Shipyard Input on Icebreaker Collaboration

Overview

The U.S. Maritime Administration (MARAD) has issued a Request for Information (RFI) to identify U.S. shipyards capable of building ice‑capable vessels and to gather insights on how to expand domestic icebreaker production. The RFI is part of the broader Icebreaker Collaboration Effort (ICE) Pact, a trilateral framework signed with Canada and Finland that seeks to strengthen polar shipbuilding capabilities, share technical expertise, and secure long‑term order books for heavy and medium icebreakers.

The ICE Pact emphasizes four pillars: enhanced information sharing, workforce development, open procurement for allied partners, and joint research and development. By leveraging the industrial bases of all three nations, the pact aims to meet the U.S. Coast Guard’s Polar Security Cutter (PSC) and Arctic Security Cutter (ASC) needs while fostering economic growth in coastal communities and ensuring national security in the increasingly accessible Arctic.

Stakeholders are invited to address a wide range of topics—from economic impacts and infrastructure requirements to intellectual‑property safeguards and advanced technologies such as AI‑enabled design tools and cold‑weather materials. The RFI seeks to inform future procurement strategies, financing mechanisms, and educational programs that will sustain a skilled maritime workforce capable of designing, building, and maintaining next‑generation icebreakers.

Key Elements

• ICE Pact Components

  • Information sharing and technical exchange among the U.S., Canada, and Finland.
    
  • Workforce development initiatives, including apprenticeship and training programs.
    
  • Open procurement pathways for allied nations to purchase U.S., Canadian, or Finnish‑built icebreakers.
    
  • Collaborative research and development on polar‑capable technologies.

• Shipyard Capacity Assessment

  • Identification of U.S. shipyards with the ability to construct ice‑capable vessels.
    
  • Evaluation of existing infrastructure (ports, utilities, testing facilities) and required upgrades.

• Economic and Community Impact

  • Analysis of job creation, infrastructure demands, and potential risks to local communities.
    
  • Consideration of housing, childcare, transportation, and cost‑of‑living factors that affect workforce recruitment and retention.

• Supply Chain and Small‑Business Participation

  • Barriers preventing small or mid‑size suppliers from entering the polar shipbuilding supply chain.
    
  • Incentives and technical assistance needed to scale supplier participation.

• Technology and Innovation Priorities

  • Adoption of AI‑enabled design tools, robotics, digital twins, and cold‑weather materials.
    
  • Identification of critical materials and components for domestic production or stockpiling.

• Testing and Facilities Needs

  • Required materials laboratories, climate chambers, autonomous systems ranges, and other testing facilities.
    
  • Assessment of current U.S. capabilities and gaps.

• Intellectual Property and Export Controls

  • Safeguards to protect designs in multinational programs.
    
  • National security requirements and export‑control considerations for U.S. built icebreakers.

• Procurement and Financing Structures

  • Block buys, multiyear procurement, public‑private partnerships, and other contract structures to stabilize order books.
    
  • Loan guarantees, grants, and risk‑sharing mechanisms to modernize or expand shipyards.

• Lessons Learned and Cooperation Models

  • Application of past U.S. and allied shipbuilding experiences to avoid cost overruns and delays.
    
  • Evaluation of multinational cooperation models such as AUKUS and NATO for applicability to ICE Pact.

• Future Planning and Research

  • Identification of basic research needs that benefit polar operations.
    
  • Guidance for long‑term maintenance planning and supply‑chain resilience.

Upper Pecos River Watershed Lands Return to Mining and Leasing: BLM and USFS Cancel Withdrawal

Overview

The Bureau of Land Management (BLM) and the U.S. Department of Agriculture’s Forest Service (USFS) have officially withdrawn their joint application to exclude 164,810 acres of National Forest System and public lands in northern New Mexico from mining and mineral leasing for a 20‑year period. The cancellation, announced in a Federal Register notice on April 6, 2026, means the lands will no longer be segregated and will be open to location and entry under U.S. mining laws and mineral/geothermal leasing statutes, subject to existing rights and other legal constraints.

This decision follows a review under the Department of the Interior’s Secretary’s Order 3418, which implements Executive Order 14154. The agencies concluded that the area would be better managed under existing land‑management plans and authorities, allowing for continued stewardship of the watershed while still permitting responsible mineral and geothermal development. The temporary segregation that had been in place since the original withdrawal notice in December 2024 will terminate automatically at 8 a.m. local time on May 6, 2026.

For stakeholders—including geoscientists, energy and mineral resource professionals, and local communities—this change signals a shift toward integrating resource extraction with watershed protection goals. The lands remain subject to all applicable environmental regulations, and any new mining or leasing activity will be evaluated within the framework of current federal and state policies.

Key Elements

• Cancellation of Withdrawal: BLM and USFS cancel their joint application to exclude 164,810.16 acres from mining and leasing.
• Effective Date: Segregation ends automatically at 8 a.m. local time on May 6, 2026.
• Land Area: 163,483 acres of National Forest System lands plus 1,327.16 acres of other public lands in the Upper Pecos River Watershed Protection Area.
• Legal Framework: Lands will be open to location and entry under U.S. mining laws and mineral/geothermal leasing laws, subject to existing rights and other segregations.
• Policy Rationale: Agencies determined that existing land‑management plans and authorities better support evolving national policy objectives and minimize landscape impacts from mining and leasing.
• Regulatory Basis: Action taken under 43 CFR 2310.1‑4(a) and 43 CFR 2310.2‑1(d); processed in accordance with 43 CFR part 2300 and 43 U.S.C. 1714.
• Contact Information: Jillian Aragon, Project Manager, BLM New Mexico State Office (email: jillian.aragon@blm.gov; TTY: 711 for U.S. residents).
• Public Notice: Published in the Federal Register (Doc. 2026‑06658) on April 3, 2026, with billing code 3411‑15‑P.

BLM Gets a Green Light: New Rule Lets It Thin Forests Faster to Fight Wildfires

Overview
The U.S. Interior Department has proposed a new categorical exclusion (CE) for the Bureau of Land Management (BLM) that expands the size of forest and woodland density‑management projects from the current 70‑acre limit to up to 5,000 acres. The change is intended to give the BLM greater flexibility to conduct large‑scale thinning and other density‑reduction activities that improve forest health, reduce fuel loads, and lower the risk of catastrophic wildfires on its 58 million acres of public forest and woodland.

The proposal builds on decades of BLM experience with thinning operations that have consistently shown no significant environmental impacts. By codifying a CE for these actions, the BLM can bypass the time‑consuming environmental assessment (EA) or environmental impact statement (EIS) process for routine density‑management projects, provided no extraordinary circumstances arise. The new CE also incorporates specific limits on road construction, erosion control, and other resource safeguards to ensure that the work remains environmentally responsible.

If adopted, the rule will streamline project approvals, enabling the BLM to respond more quickly to high‑risk conditions ahead of fire seasons. It aligns with recent NEPA reforms under the Fiscal Responsibility Act, Executive Order 14225’s emphasis on forest resilience, and the Department’s broader goal of protecting public lands while supporting timber production and rural economies.

Key Elements

• Expanded Scope – Allows density‑management actions (thinning, yarding, chipping, underburning, seeding) on up to 5,000 acres per project, up from the existing 70‑acre limit.
  
• Road Construction Limits – No more than 5 miles of new permanent roads; temporary roads limited to 2.5 miles per 1,000 acres and must be decommissioned after use.
  
• Environmental Safeguards – Requirements for erosion control, soil compaction mitigation, snag retention, invasive‑species prevention, riparian buffers, and prescribed‑fire constraints.
  
• NEPA Compliance – Actions eligible for the CE must still be reviewed for extraordinary circumstances; if found, an EA or EIS will be required.
  
• Public Comment Period – Comments accepted until May 6, 2026; submissions can be made electronically or by mail to the BLM Forestry Lead.
  
• Alignment with Policy – Supports the Fiscal Responsibility Act’s NEPA reforms, Executive Order 14225’s forest‑resilience goals, and the Department’s objective to reduce wildfire severity on public lands.

EPA Seeks Public Input on Expanding “No‑Discharge” Zones for Vessel Sewage and Military Discharges

Overview

The U.S. Environmental Protection Agency (EPA) is extending its current information‑collection request (ICR) for establishing No‑Discharge Zones (NDZs) under Clean Water Act (CWA) Section 312. The renewal, approved through September 30, 2026, will allow states to petition EPA for stricter limits on sewage discharges from all vessels—including those of the armed forces—and to request reviews of existing discharge standards. EPA is inviting public comments on the proposed data collection for a 60‑day period ending June 5, 2026.

The ICR will capture the administrative burden on states that develop NDZ petitions and on EPA as it reviews them. EPA estimates the annual burden at roughly 408 hours and $28,910, a reduction from the previous estimate due to a revised expectation of fewer state petitions. The request is part of EPA’s effort to improve water quality in state waters, protect marine ecosystems, and ensure compliance with federal discharge standards.

Key Elements

• Scope of NDZs:

  • Vessel sewage NDZs prohibit both treated and untreated sewage discharges from all vessels within designated state waters.
    
  • Uniform National Discharge Standards (UNDS) NDZs apply to specific military vessel discharges that meet federal performance standards.

• Information Required from States:

  • Detailed data on proposed NDZ boundaries, discharge characteristics, and environmental impact assessments.
    
  • Documentation supporting the need for stricter limits or a review of existing standards.

• Administrative Burden:

  • Estimated 408 hours per year for state respondents and EPA reviewers.
    
  • Annual cost of $28,910, including $400 for capital or operating expenses.

• Public Participation:

  • Comments must be submitted by June 5, 2026, via EPA’s online docket system or by mail.
    
  • EPA will consider feedback to refine the ICR before final submission to the Office of Management and Budget (OMB).

• Legal Basis:

  • CWA Section 312(f) and (n) authorize states to petition EPA for NDZs and for reviews of discharge determinations.
    
  • The ICR aligns with the Paperwork Reduction Act, ensuring that data collection is necessary and efficient.

• Implications for Geoscience and Natural Resource Fields:

  • Enhanced protection of coastal and inland water bodies from vessel‑related pollution.
    
  • Potential impacts on maritime operations, fisheries, and coastal ecosystem research.
    
  • Opportunities for scientists to provide data and expertise in shaping effective NDZ policies.

Big Wood Canal’s Magic Dam: Idaho’s New Hydropower Project Opens the Floodgates for Public Input

Overview
The U.S. Federal Energy Regulatory Commission (FERC) has accepted the Big Wood Canal Company’s application for a new hydroelectric license—Magic Dam—on the Big Wood River in Idaho. The project will operate in a run‑of‑river mode, releasing seasonal flows for irrigation while generating up to 9 MW of clean electricity. The application is now available for public inspection, and FERC is soliciting protests and motions to intervene from interested parties.

The notice outlines a clear timeline: a 60‑day filing window that ends on Monday, June 1, 2026, followed by a scoping phase in May 2026, environmental analysis in September 2026, and eventual licensing. The Commission encourages electronic submissions but also accepts paper filings. All comments and interventions must be filed in accordance with FERC’s Rules of Practice and Procedure, and must be served to the applicant and relevant resource agencies.

For stakeholders in geoscience, energy, and natural resources, this is an opportunity to influence how the project will balance water use, ecological impacts, and renewable energy generation on federal land managed by the Bureau of Land Management.

Key Elements

• Project Scope

  • 3,100‑ft earth‑filled dam with concrete spillway
    
  • 3,740‑acre reservoir (≈191,500 acre‑feet)
    
  • 36.5‑ft intake tower, 620‑ft conduit, 170‑ft penstock
    
  • 3‑unit powerhouse (total 9 MW)
    
  • 9.2‑mi, 4.16‑kV transmission line
    

• Operation Mode

  • Run‑of‑river, seasonal releases for irrigation on the Big Wood River
    

• Location & Land Use

  • Situated on federal land in Blaine and Camas Counties, Idaho
    
  • Managed by the U.S. Bureau of Land Management
    

• Regulatory Framework

  • FERC’s Federal Power Act (16 U.S.C. § 791‑825)
    
  • Filing deadlines: 60‑day window extended to June 1, 2026
    
  • Public participation: protests and motions to intervene must be filed by the deadline and served to the applicant and relevant agencies
    

• Timeline

  • May 2026: Issue Scoping Document Notice
    
  • June 2026: Scoping comments due
    
  • September 2026: Notice of Ready for Environmental Analysis
    

• Filing Instructions

  • Electronic filing via FERC eFiling or eComment systems (10,000‑char limit)
    
  • Paper filings addressed to Secretary Debbie‑Anne A. Reese, FERC (Washington, DC) or (Rockville, MD)
    
  • All documents must identify the project name and docket number (P‑3407‑088) on the first page
    

• Public Participation Resources

  • FERC eLibrary for document access (enter docket number without last three digits)
    
  • Contact offices: Office of Public Participation (202 502‑6595) and FERC Online Support (866 208‑3676)
    

This notice invites the public, environmental groups, water users, and industry stakeholders to shape the future of Idaho’s hydropower landscape while ensuring that ecological and resource considerations are adequately addressed.

Revamping the Flower Garden Banks Sanctuary: NOAA Seeks Public Input on Management Plan

Overview

The National Oceanic and Atmospheric Administration (NOAA) has launched a comprehensive review of the Flower Garden Banks National Marine Sanctuary (FGBNMS) management plan. The goal is to assess progress toward the sanctuary’s conservation objectives, update strategies for the expanded 17‑bank area, and ensure compliance with the National Marine Sanctuaries Act (NMSA). NOAA is inviting comments from individuals, businesses, tribes, and government entities to shape the next iteration of the plan.

FGBNMS, located 80–125 miles off Texas and Louisiana, protects a mosaic of shallow coral reefs, mesophotic habitats, and hard‑bottom ecosystems that support both biodiversity and economic activities such as diving, fishing, and scientific research. Since its 1992 designation and subsequent expansions, the sanctuary has become a critical reference point for marine health in the Gulf of Mexico. The 2024 Condition Report highlighted emerging threats—coral bleaching, invasive species, and increasing human use—that the new plan must address.

The review process follows a four‑stage framework: (1) information gathering through this notice, (2) drafting a revised management plan and accompanying NEPA environmental review, (3) public comment on the drafts, and (4) finalization of the plan and any regulatory amendments. NOAA will also consider requirements under the Endangered Species Act, Marine Mammal Protection Act, and other federal statutes. Public meetings and written comment periods are scheduled through May 21, 2026, providing multiple avenues for stakeholder engagement.

Key Elements

• Public Participation: Written comments due by May 21, 2026; oral comments at virtual (April 20) and in‑person (May 19) meetings.
  
• Stakeholder Scope: Input sought from individuals, companies, organizations, tribes, and federal agencies.
  
• Review Stages:
  
  1. Information collection (this notice)
     
  2. Draft management plan & NEPA review
     
  3. Public comment on drafts
     
  4. Final plan & regulatory updates
     
• Geoscience Focus:
  
  • Assessment of shallow coral vs. mesophotic habitat protection.
    
  • Monitoring of reef health, water quality, and invasive species.
    
  • Research needs across all 17 banks, including data sharing and emerging technologies.
    
• Resource Use & Access:
  
  • Strategies for visitor safety, compatible use, and enforcement in a remote setting.
    
  • Infrastructure improvements (mooring buoys, monitoring equipment) under resource constraints.
    
• Education & Outreach:
  
  • Evaluation of current programs and exploration of new technologies and partnerships.
    
• Regulatory Context:
  
  • No major rulemaking anticipated; focus on policy adjustments and compliance with NMSA, NEPA, and related statutes.
    
• Agency Collaboration:
  
  • Coordination with the Bureau of Ocean Energy Management, EPA, Gulf Council, DoD, and Coast Guard to align energy, environmental, and maritime interests.

NRC Green‑Lights Small Modular Reactor at Tennessee’s Clinch River: Final Environmental Review

Overview

The U.S. Nuclear Regulatory Commission (NRC) has released the final Supplemental Environmental Impact Statement (SEIS) for the Tennessee Valley Authority’s (TVA) application to construct a single GE Vernova Hitachi BWRX‑300 small modular reactor (SMR) at the Clinch River Nuclear Site (CRN‑1) in Roane County, Tennessee. The SEIS evaluates the environmental consequences of issuing a construction permit (CP) that would allow the reactor’s construction and operation, as well as the impacts of alternative actions.

After reviewing the draft SEIS, incorporating public comments, and consulting with federal, state, tribal, and local stakeholders, the NRC recommends issuing the CP, provided no safety issues arise. The assessment found no environmentally preferable alternatives that meet the project’s purpose and need, and concluded that the benefits—such as low‑carbon electricity and demonstration of SMR technology—outweigh the identified environmental costs.

The final SEIS is publicly available through the NRC’s ADAMS system and the CRN‑1 project website. It represents the culmination of a multi‑year NEPA review process that began with TVA’s initial application in 2025, including public notice, comment periods, and an independent environmental audit.

Key Elements

• Construction Permit: NRC’s recommendation to issue a CP for one BWRX‑300 SMR at CRN‑1, enabling TVA to demonstrate SMR feasibility.
  
• Environmental Scope: Assessment of impacts on water resources, land use, wildlife, cultural and historic sites, and radiological safety.
  
• Alternatives Analysis: Evaluation of no‑action, different site locations, and other reactor technologies; none were found to be superior environmentally.
  
• Public Participation: Draft SEIS released in November 2025; comment period closed December 2025; final SEIS incorporates stakeholder feedback.
  
• Regulatory Coordination: Collaboration between NRC and the U.S. Army Corps of Engineers, with compliance under NEPA, the National Historic Preservation Act, and NRC’s 10 CFR 51 regulations.
  
• Timeline: Final SEIS published April 1 2026; construction permit decision pending NRC issuance.
  
• Implications for Geosciences: Highlights the importance of hydrologic monitoring, seismic assessment, and land‑use planning in nuclear site development.
  
• Energy Context: The project supports the U.S. transition to low‑carbon power and showcases SMR technology’s potential for scalable, modular nuclear generation.

BLM Eyes Faster, Safer Forest Management with New Salvage Harvest Exclusion

Overview

The Bureau of Land Management (BLM) oversees roughly 248 million acres of public land, of which about 58 million acres are forested. With an estimated 2 million acres of dead or dying timber on its lands, the BLM has long used “salvage harvest” to remove hazardous trees, reduce wildfire fuel loads, and recover economic value for rural communities. Rising wildfire frequency and size have prompted the agency to seek a more flexible, streamlined approach to authorize larger salvage operations.

The Department of the Interior proposes a new categorical exclusion (CE) under the National Environmental Policy Act (NEPA) that would allow BLM to conduct salvage harvests on up to 5 000 acres—five times the current 250‑acre limit—while still meeting environmental safeguards. The CE would limit permanent road construction to one mile, allow temporary roads under specified conditions, and require documentation of erosion control, snag retention, and other resource protections. By removing the need for a full environmental assessment for routine salvage projects, the BLM aims to expedite decision‑making, reduce fuel loads before fire season, and support the federal land policy goal of domestic timber supply.

The proposal is part of the BLM’s NEPA implementation procedures and is open for public comment until May 6, 2026. If finalized, the new CE will coexist with the existing 250‑acre CE, giving BLM a tiered set of tools to respond to disturbances of varying scale while maintaining compliance with NEPA’s requirement to consider environmental impacts and engage stakeholders.

Key Elements

• Scope of the new CE: Salvage harvesting of dead or dying trees up to 5 000 acres, with limits on permanent road construction (≤ 1 mile) and temporary roads (≤ 2.25 mi per 1 000 acres).
  
• Environmental safeguards: Required documentation on snag retention, erosion control, soil compaction, invasive species prevention, riparian buffers, and prescribed fire operations.
  
• Retention of existing CE: The current 250‑acre CE (C.8) remains in place for smaller projects, ensuring a flexible, tiered approach.
  
• NEPA compliance: The CE is established through a substantiation report, public comment, and CEQ consultation, following the Department’s NEPA handbook procedures.
  
• Wildfire mitigation: By enabling quicker, larger salvage operations, the CE aims to reduce hazardous fuel loads and protect firefighters, infrastructure, and communities.
  
• Economic and rural benefits: Salvage harvests recover timber value, supporting local economies and the federal land policy goal of domestic timber supply.
  
• Public comment period: Comments are accepted until May 6, 2026, allowing stakeholders to influence the final CE language and implementation.

Draft Environmental Review Opens for the New Kosciusko Junction Pipeline

Overview

The U.S. Federal Energy Regulatory Commission (FERC) has released the Draft Environmental Impact Statement (EIS) for the proposed Kosciusko Junction Pipeline Project, a major natural‑gas transmission expansion in Mississippi and Texas. The project involves the sale and abandonment of existing pipelines, construction of new 36‑inch lines totaling over 110 miles, and installation of multiple compressor stations and meter facilities. The EIS evaluates potential environmental effects, outlines mitigation measures, and invites public input before FERC decides whether to issue a Certificate of Public Convenience and Necessity.

The draft EIS concludes that, with the proposed avoidance, minimization, and mitigation measures, any adverse environmental impacts would be less than significant. Cooperating agencies—including the Army Corps of Engineers, EPA, and Fish and Wildlife Service—have provided input, and their own conclusions will appear in separate records. The notice encourages comments from landowners, environmental groups, and the general public, with a deadline of May 25 2026 and several in‑person comment sessions scheduled in April 2026.

This project represents a substantial expansion of the natural‑gas infrastructure in the Gulf South region, potentially affecting land use, water resources, wildlife habitats, and local communities. The public comment period is a critical opportunity for stakeholders to influence the final environmental assessment and the eventual regulatory decision.

Key Elements

• Project Scope

  • Sale and abandonment of Texas Gas’s Greenville Lateral and Isola CS.
    
  • Construction of an 8.1‑mile Columbia Gulf Lateral and a 102.9‑mile Kosciusko Junction Pipeline (36‑inch diameter).
    
  • Installation of four new compressor stations (totaling ~110,000 hp) and four meter stations.
    

• Environmental Assessment

  • Draft EIS identifies limited adverse effects; mitigation measures aim to keep impacts less than significant.
    
  • Cooperating agencies (Army Corps, EPA, Fish & Wildlife) contributed analyses and will issue separate decisions.
    

• Public Participation

  • Comment deadline: 5:00 p.m. ET, May 25 2026.
    
  • Four public comment sessions (April 28–30 2026) in Mississippi towns.
    
  • Multiple electronic filing options (eComment, eFiling) and paper submissions accepted.
    

• Regulatory Context

  • FERC is the lead federal agency under the Natural Gas Act of 1938 for interstate transmission projects.
    
  • The draft EIS is not a decision document; it informs FERC’s evaluation of public convenience and necessity.
    

• Mitigation Measures

  • Avoidance of sensitive habitats, minimization of construction footprint, and implementation of monitoring plans.
    
  • Specific site‑level construction plans for residences within 25 ft of work zones are included in Appendix E.
    

• Stakeholder Impact

  • Potential effects on landowners, water resources, wildlife corridors, and local economies.
    
  • Opportunities for landowners to comment on site‑specific construction plans and mitigation strategies.

National Security Overrides Species Protection: Gulf Oil and Gas Exemption Granted

Overview
On March 31, 2026, the Endangered Species Committee—comprised of the Interior, Army, EPA, Agriculture, and Commerce Departments—held a public meeting in Washington, D.C. to consider a request from the Secretary of War that Gulf of America oil and gas activities be exempted from the Endangered Species Act (ESA) under Section 7(h). The Committee, by unanimous vote, granted the exemption, citing national‑security concerns and the findings in the Secretary’s National Security Findings letter.

The exemption applies to all exploration, development, and production activities overseen by the Bureau of Ocean Energy Management (BOEM) and the Bureau of Safety and Environmental Enforcement (BSEE) in the Outer Continental Shelf, as well as the avoidance or minimization measures already outlined in the National Marine Fisheries Service’s 2025 biological opinion and the U.S. Fish and Wildlife Service’s 2018 and 2025 consultation decisions. While the ESA’s procedural consultation and jeopardy requirements are waived, the existing mitigation measures remain in force, and the agencies must continue to implement them.

This decision can be challenged in federal court, with jurisdiction in the Fifth or Eleventh Circuit Courts of Appeals, and the Committee has designated DOJ attorneys to defend the order. The move underscores the tension between environmental safeguards and national‑security priorities in the Gulf of America’s energy sector.

Key Elements

• Exemption Granted – Section 7(h) of the ESA allows the Committee to waive ESA requirements for the Gulf of America oil and gas activities.
• Scope – Covers all BOEM/BSEE‑approved exploration, development, and production operations in the Outer Continental Shelf, plus the mitigation measures already identified in prior biological and consultation documents.
• Mitigation Measures – Existing avoidance and minimization actions from NMFS (2025) and FWS (2018, 2025) remain mandatory; no new mitigation is required under the exemption.
• Procedural Waivers – Agencies are relieved from Section 7(a)(2) consultation, jeopardy, and adverse modification requirements for the exempted activities.
• Legal Recourse – The exemption is subject to judicial review in the Fifth or Eleventh Circuit Courts of Appeals; DOJ attorneys will represent the Committee.
• Agency Collaboration – The decision involved the Interior, Army, EPA, Agriculture, Commerce, and the Council of Economic Advisors, reflecting a multi‑departmental approach to national‑security‑driven environmental policy.
• Implications for Geoscience and Energy – The exemption may accelerate offshore drilling and exploration while maintaining baseline environmental safeguards, illustrating how national‑security considerations can reshape regulatory frameworks in the Gulf region.

FERC Opens the Book on Vermont’s Tiny Turbine: Will a Small Hydropower Plant Need a Federal License?

Overview

On April 3 2026 the Federal Energy Regulatory Commission (FERC) issued a notice inviting public input on a jurisdictional inquiry concerning the Baldin Brook Hydroelectric Project in Lamoille County, Vermont. The Vermont Department of Environmental Conservation (DEC) has asked FERC to determine whether the project falls under federal licensing requirements because it sits on a stream that is a tributary of a navigable water, was built after August 26 1935, and is connected to the interstate transmission grid.

The legal question hinges on the Federal Power Act (FPA). Under Section 23(b)(1), non‑federal hydro projects must be licensed if they are on a navigable water, occupy federal lands, use surplus water from a federal dam, or, crucially, are on a stream over which Congress has Commerce Clause jurisdiction and affect interstate commerce. Courts have long held that even small hydro plants that feed the grid can displace power from the national system, thereby influencing interstate commerce and triggering licensing obligations.

FERC’s notice invites comments, protests, and motions to intervene by May 15 2026. Stakeholders—including local communities, environmental groups, and energy developers—can submit written input electronically or by mail. The Commission will review all submissions and decide whether the Baldin Brook project must obtain a federal license, a determination that could shape future small‑hydro development in Vermont and beyond.

Key Elements

• Project Details: Baldin Brook Hydroelectric Project, Lamoille County, Vermont; small‑scale plant connected to the interstate grid.
  
• Jurisdictional Basis: FERC is evaluating whether the project meets the FPA’s Commerce Clause criteria (post‑1935 construction on a tributary of a navigable water).
  
• Legal Context: Small hydro projects that feed the grid can affect interstate commerce; courts have affirmed licensing requirements under these circumstances.
  
• FERC Docket: UL26‑4‑000; notice published in the Federal Register (Doc. 2026‑06505).
  
• Comment Period: 45 days from notice, deadline May 15 2026, 5:00 p.m. Eastern Time.
  
• Submission Methods: Electronic filing via FERC’s eFiling system; paper filings accepted at specified addresses.
  
• Potential Outcomes: FERC may rule the project requires a federal license, which would impose additional regulatory oversight and permitting steps.
  
• Stakeholder Impact: Decision will influence future small‑hydro development, local energy policy, and environmental stewardship in Vermont.

EPA Seeks to Reclaim Cleanup Costs from Corporate Lakes Atlanta Over Lithium Battery Fire

The Environmental Protection Agency (EPA) has announced a proposed administrative settlement with Corporate Lakes Atlanta, LLC concerning the Lakes Parkway Lithium Battery Fire Superfund Site in Lawrenceville, Georgia. Under the Comprehensive Environmental Response, Compensation and Liability Act (CERCLA), the EPA incurred costs to clean up the site after a lithium battery fire released hazardous substances into the environment. The settlement would require Corporate Lakes Atlanta to reimburse the EPA for those cleanup expenses.

The notice invites public comments on the proposed agreement until May 4, 2026. EPA may modify or withdraw the settlement if new information suggests it is inappropriate, improper, or inadequate. Interested parties can review the settlement details and submit comments online or via email, with contact information provided in the notice.

Key Elements - CERCLA Framework: The settlement is governed by the federal Superfund law, which holds responsible parties liable for cleanup costs.
- Corporate Lakes Atlanta, LLC: The company is the proposed liable party for the lithium battery fire and subsequent contamination.
- Cost Recovery: The agreement seeks to recover all EPA-incurred cleanup costs, including investigation, remediation, and monitoring expenses.
- Public Comment Period: Comments are accepted until May 4, 2026, and may influence the final terms of the settlement.
- Contact Channels: Comments and inquiries can be submitted online, by email, or by contacting Program Analyst Paula V. Painter.
- Potential Adjustments: EPA may alter or withdraw the settlement if new facts emerge during the comment period.
- Relevance to Geoscience and Energy: The case highlights the environmental risks associated with lithium battery production and the importance of responsible waste management in the growing battery industry.

EIA Extends 3‑Year Petroleum Data Collection, Streamlines Reporting for Energy Markets

Overview
The U.S. Energy Information Administration (EIA) has requested a three‑year extension of its Petroleum Supply Reporting System (PSRS) under the Paperwork Reduction Act. The PSRS comprises seven weekly surveys (WPSRS), eight monthly surveys (MPSRS), and two annual surveys, one of which is a proposed new standby survey. The extension keeps the system in place through 2029, ensuring continuity of critical data on crude oil, gas liquids, petroleum products, and biofuels.

The PSRS data feed a wide array of national and international reports—such as the Weekly Petroleum Status Report, Petroleum Supply Monthly, and the Short‑Term Energy Outlook—providing policymakers, industry, and the public with timely, reliable insights into supply, inventory, and production trends. These statistics underpin market transparency, inform regulatory decisions, and support academic and media analyses of energy economics and environmental impacts.

Alongside the extension, EIA proposes modest revisions to survey instructions, updates to country lists for crude oil imports, and the creation of a new standby form (EIA‑830) to capture storage capacity data annually. These changes aim to reduce respondent burden, improve data quality, and allow rapid activation of the standby form during market disruptions.

Key Elements

• Three‑year extension of the PSRS (OMB Control No. 1905‑0165) through 2029.
  
• Survey structure: 7 weekly (WPSRS), 8 monthly (MPSRS), 2 annual (including proposed standby).
  
• Data collected: production, inputs, imports, inventories, refinery and biofuel plant capacities, feedstock consumption, and storage volumes.
  
• Primary uses: national reports (WPSR, PSM, MER), outlooks (STEO, AEO), IEA submissions, and external publications (e.g., USDA bioenergy statistics).
  
• Minor instruction updates to align language across surveys and improve clarity.
  
• Country list revision on Form EIA‑804 to reflect current U.S. crude oil import patterns.
  
• Form EIA‑819 renamed and re‑structured to better capture non‑traditional fuel feedstocks.
  
• Removal of annual supplements from monthly forms (EIA‑810, EIA‑813, EIA‑815) and consolidation into a new standby annual storage capacity form (EIA‑830).
  
• Estimated burden: 176,071 respondent hours, costing roughly $16.7 million in labor, with no additional respondent costs beyond normal business operations.
  
• Comment period closed May 4, 2026; public feedback was solicited to refine the collection.

Pennsylvania’s Coastal Management Program Under Review: NOAA Seeks Public Input

Overview

The National Oceanic and Atmospheric Administration (NOAA) is conducting a formal performance evaluation of Pennsylvania’s federally approved Coastal Management Program, as required by the Coastal Zone Management Act (CZMA). The evaluation will assess how well the Commonwealth has met national objectives, adhered to the program’s approved framework, and complied with the terms of federal financial assistance.

NOAA is inviting the public to participate through a virtual meeting on May 19, 2026, and by submitting written comments by May 29, 2026. The agency will consider all relevant input—oral and written—before finalizing its findings, which will be published once the evaluation is complete.

This process offers stakeholders, including scientists, policymakers, and local communities, an opportunity to influence future coastal management strategies, funding allocations, and regulatory priorities in Pennsylvania.

Key Elements

• Public Meeting: Virtual session on May 19, 2026, 12 p.m.–1 p.m. ET; registration opens May 18, 2026.
  
• Oral Participation: Register as a speaker to provide testimony; anonymity allowed by entering “Anonymous” in name fields.
  
• Written Comments: Submit to Carrie Hall (Evaluator) by May 29, 2026; subject line must read “Comments on Pennsylvania Coastal Management Program.”
  
• Public Record: All comments, including personal information, become part of the public record; confidential or sensitive data should not be included.
  
• Evaluation Focus: Assessment of compliance with CZMA national objectives, program adherence, and financial assistance terms.
  
• Outcome: Final evaluation findings will be announced by NOAA’s Office for Coastal Management after the review concludes.
  
• Contact: Carrie Hall, Evaluator, NOAA Office for Coastal Management (email/phone provided).

Idaho Gold Rush: Federal Review of Black Pine Mine Opens 30‑Day Comment Window

The Forest Service, in partnership with the Bureau of Land Management (BLM), has announced the start of a 30‑day public comment period for an Environmental Impact Statement (EIS) on the proposed Black Pine Gold Project in Cassia and Oneida Counties, Idaho. The project, submitted by Liberty Gold (USA) Inc., plans to expand existing open‑pit mines and construct four new pits, along with a cyanide heap‑leach processing facility and supporting infrastructure on federal lands. The EIS will assess the environmental effects of these activities, including impacts on water quality, wildlife, cultural resources, and the visual character of the Sawtooth National Forest.

Key objectives of the EIS include ensuring that mining operations comply with federal land‑management laws, protecting surface resources, and determining whether a project‑specific amendment to the Sawtooth Forest Plan is required. The notice also highlights the project’s status under the Fixing America’s Surface Transportation Act (FAST‑41), which mandates transparent permitting timelines for covered projects. The Forest Service expects the full EIS to be completed within two years, with a decision‑making schedule available on its website.

Key Elements

• Project Scope: Expansion of four existing open‑pit mines, construction of four new pits, ore stockpiling, and a cyanide heap‑leach processing plant on adjacent BLM land.
  
• Infrastructure: Mine office facilities, access roads, utilities, and water pipelines to be built on BLM‑administered lands.
  
• Environmental Review: EIS will evaluate impacts on groundwater, surface water, wildlife (including Greater sage grouse), cultural sites, scenic values, grazing, air quality, and soil suitability for reclamation.
  
• Regulatory Framework:
  
  • Forest Service lead agency; BLM cooperating agency.
    
  • Requires additional permits from Idaho Department of Environmental Quality (cyanidation, air quality) and Idaho Department of Lands (operating, reclamation, closure plans).
    
  • Project must be consistent with the Sawtooth Forest Plan; likely requires a project‑specific plan amendment.
    
• Public Participation: 30‑day comment period (deadline May 4, 2026) with opportunities for virtual and in‑person meetings.
  
• Transparency: FAST‑41 dashboard provides a public permitting timetable; the project is a “covered project” under FAST‑41.
  
• Timeline: EIS expected within two years; mine life projected at 17 years, followed by a 25‑year reclamation and monitoring phase.
  
• Objection Process: Comments must be timely and specific to qualify for the pre‑decisional objection process under 36 CFR 218.
  
• Cooperating Agencies: Idaho Department of Lands and Idaho Department of Environmental Quality provide technical expertise.
  

This notice invites stakeholders to shape the environmental assessment of a significant gold and silver mining venture that could reshape Idaho’s landscape and economy.