Pelican, Alaska: City Seeks Public Input on New Hydroelectric License

The Federal Energy Regulatory Commission (FERC) has announced that the City of Pelican, Alaska, has filed a new minor license application for its existing Pelican Hydroelectric Project. The project, located on Pelican Creek in the city, operates a run‑of‑river hydroelectric system that includes a rock‑filled crib dam, intake and penstock pipes, two small generating units (600 kW and 100 kW), and a short transmission line. The facility is already in operation under a current license, and the city intends to continue running it in the same mode.

This notice signals that the application is now ready for environmental analysis. FERC is inviting the public, environmental groups, and other stakeholders to submit comments, recommendations, terms and conditions, and prescriptions. The deadline for initial submissions is May 1, 2026, with reply comments due by June 15, 2026. The city must also provide a water‑quality certification or evidence of a waiver by May 1, and any final amendments must be filed by April 1.

The process offers an opportunity for community members and experts in hydrology, ecology, and energy policy to influence how the project will be regulated. Comments can shape environmental safeguards, operational limits, and potential impacts on local fish populations and water quality. The outcome will determine whether the city receives a new license that allows continued operation, potentially affecting local renewable energy supply and the region’s natural resource management.

Key Elements

• New Minor License – FERC will issue a new license under the Federal Power Act; the existing license does not include waivers for certain sections, so a new license is required.
  
• Run‑of‑River Operation – The project will continue to operate in a run‑of‑river mode, meaning it relies on natural stream flow without large reservoirs.
  
• Existing Facilities – Includes a 12‑ft wide by 22‑ft high crib dam, steel and concrete intake, polyethylene penstock and surge tank, two generators (600 kW & 100 kW), a 4.16‑kV transmission line, and a 500‑ft access road.
  
• Environmental Analysis – FERC will conduct an environmental review; the city must submit a water‑quality certification or waiver by May 1, 2026.
  
• Public Comment Period – Comments, recommendations, terms and conditions, and prescriptions are due by May 1, 2026; reply comments by June 15, 2026.
  
• Electronic Filing – FERC encourages use of its eFiling and QuickComment systems; paper filings are also accepted with specific mailing addresses.
  
• Service List Requirements – Intervenors must serve copies of their filings to all parties on the official service list and, if applicable, to relevant resource agencies.
  
• Final Amendments Deadline – Any final amendments to the application must be filed by April 1, 2026.
  
• Implications for Local Community – The license will determine continued operation, potential environmental safeguards, and the city’s renewable energy contribution to the region.

Reclamation Bureau Updates Water Contracts: New Deals, Renewals, and Repairs Across the West

The Bureau of Reclamation’s quarterly notice reports all water‑service, repayment, and other water‑related contract actions that have been proposed, completed, or discontinued since the last publication. The document serves as a public record of how the federal agency manages water resources for irrigation, municipal use, and infrastructure maintenance under the Reclamation Project Act of 1939 and related statutes.

The notice covers a wide geographic range—from the Colorado River Basin to the Columbia‑Pacific Northwest—listing specific contract actions such as new water‑delivery assignments, contract renewals, repayment agreements for dam repairs, and conversions of irrigation water to miscellaneous uses. It also highlights the procedural framework for contract approval, including the roles of the Secretary of the Interior, the Commissioner of Reclamation, regional directors, and, when necessary, congressional review.

Public participation is a key feature of the process. The Bureau invites stakeholders to observe contract negotiations, submit written comments, and access contract documents through Freedom of Information Act requests. All contract actions are coordinated with National Environmental Policy Act requirements, and the notice provides contact information for regional offices and the Reclamation Law Administration Division for further inquiries.

Key Elements

• Contract Types Covered

  • Water‑service contracts (delivery of project water for authorized uses)
    
  • Repayment contracts (reimbursable shares for infrastructure repairs)
    
  • Conversion contracts (changing irrigation water to miscellaneous purposes)
    
  • Lease and assignment contracts (transfer of water entitlements)

• Approval and Oversight

  • Contracts must be approved by the Secretary of the Interior or delegated authority (Commissioner or regional directors).
    
  • Congressional review may be required for certain water rates or terms.
    
  • Final contracts are subject to the Reclamation Project Act and related regulations (e.g., 43 CFR 426.22).

• Public Participation Procedures

  • Stakeholders may observe negotiations and submit written comments.
    
  • Advance notice of meetings is provided to parties who request it.
    
  • Written comments and public testimony are reviewed and summarized by regional offices.
    
  • Contracts can be accessed via FOIA requests.

• Examples of Recent Actions

  • Completion of a repayment contract for spillway repairs at Hyrum Dam (April 2025).
    
  • Renewal of water‑service contracts for the Norman Project (August 2025).
    
  • New assignment of Colorado River water entitlement from Beattie Farms Southwest to the Hualapai Tribe (March 2026).
    
  • Modification of a contract for 60 acre‑feet of Colorado River water per year for Milton and Jean Phillips (March 2026).

• Regional Coverage

  • Five Reclamation regions are represented: Interior Region 5 (Missouri Basin), Region 7 (Upper Colorado Basin), Region 8 (Lower Colorado Basin), Region 9 (Columbia‑Pacific Northwest), and Region 10 (California‑Great Basin).
    
  • Each region lists its own set of new, completed, discontinued, and modified contract actions.

• Contact Information

  • Morgan Raymond, Reclamation Law Administration Division, provides a central point of contact for questions and further details.
    
  • Regional offices offer additional assistance and contract documentation upon request.

EPA Finalizes Guidance to Secure Funding for Abandoned Mine Clean‑ups

Overview

The Environmental Protection Agency (EPA) has released the final “Financial Assurance Guidance” for the Good Samaritan Remediation of Abandoned Hardrock Mines Act of 2024. The Act creates a pilot program that can grant up to 15 permits to low‑risk projects aimed at cleaning up abandoned hard‑rock mine sites. To receive a permit, applicants must demonstrate that they possess the financial resources to complete the work or have a third‑party financial assurance mechanism in place. The guidance clarifies how those resources should be documented and managed, ensuring that any unfinished work can be funded without tapping taxpayer dollars.

The guidance is not a regulatory requirement; it serves as a practical reference for potential applicants and the EPA’s own permitting process. It was developed after a public comment period (August–September 2025) and incorporates stakeholder feedback. The final document is available on the EPA website and is effective as of March 5, 2026.

For geoscientists, mineral‑resource developers, and environmental professionals, the guidance offers a clearer pathway to secure the necessary financial backing for mine‑site remediation projects, promoting responsible stewardship of former mining landscapes while protecting public funds.

Key Elements

• Good Samaritan Permit Scope – Up to 15 permits for low‑risk remediation projects under the 2024 Act.
  
• Financial Assurance Requirement – Applicants must prove they have the funds to finish the project or secure a third‑party financial assurance mechanism.
  
• Use of Funds – Assurance funds cover incomplete work, preventing the use of taxpayer money.
  
• Guidance Nature – Non‑binding; serves as a reference for applicants and EPA staff.
  
• Effective Date – Guidance becomes effective on March 5, 2026.
  
• Access – Final guidance posted on EPA’s Good Samaritan website and available through the EPA docket (EPA‑HQ‑OLEM‑2025‑0586).
  
• Contact – Jamey Watt, Office of Mountains, Deserts and Plains, EPA (watt.jamey@epa.gov).
  
• Implications for Stakeholders – Provides a clear framework for securing financial assurance, encouraging participation in the pilot program and ensuring accountability in abandoned mine remediation.

Ohio Takes the Lead: State‑Level Environmental Oversight for New Highway Projects

Overview

The Federal Highway Administration (FHWA) has opened a comment period on a proposed renewal of the Memorandum of Understanding (MOU) between Ohio and the federal government. The MOU would transfer Ohio’s Department of Transportation (ODOT) the responsibility for most environmental reviews and consultations required under the National Environmental Policy Act (NEPA) and related federal laws for highway projects that receive federal aid within the state. The renewal extends the current agreement through June 2026, allowing Ohio to make project‑level decisions on environmental assessments, categorical exclusions, and environmental impact statements for a broad range of state‑funded or federally funded road projects.

The agreement is part of the Surface Transportation Project Delivery Program, which lets states assume NEPA duties while the FHWA retains oversight. Ohio’s proposal includes detailed exclusions—such as projects that cross state or international borders, certain federally authorized highways, and projects undertaken by non‑ODOT recipients of federal funds. The MOU also clarifies that the FHWA will continue to conduct formal government‑to‑government consultations with federally recognized Indian tribes, while ODOT will handle routine outreach.

If approved, the MOU will streamline environmental decision‑making for Ohio’s highway network, potentially speeding up construction while maintaining compliance with a wide array of federal environmental statutes. The public and stakeholders have until April 6, 2026, to submit comments on the renewal package and draft MOU.

Key Elements

• Transfer of NEPA duties: Ohio will conduct environmental assessments, categorical exclusions, and impact statements for most federally funded highway projects within the state.
  
• Scope of projects: Applies to projects funded with Title 23 funds or requiring FHWA approval, excluding:
  
  • Certain federally authorized highways (23 U.S.C. 202, 203, 204).
    
  • Projects crossing state or international borders.
    
  • Recreational trail projects.
    
  • Projects by non‑ODOT direct recipients of federal aid.
    
• Environmental laws covered:
  
  • Clean Air Act, Clean Water Act, Endangered Species Act, National Historic Preservation Act, and many others.
    
  • Excludes FHWA responsibilities under specific statutes (e.g., 23 U.S.C. 134, 135).
    
• Consultation with tribes: FHWA retains formal government‑to‑government consultation authority; ODOT will conduct routine outreach.
  
• Public disclosure: ODOT must label all environmental analyses with a statement indicating the review is performed under the MOU.
  
• Oversight and review: FHWA will review public comments and may revise the MOU before finalizing it.
  
• Comment period: Open until April 6, 2026, via regulations.gov or mail.
  
• Administrative context: The renewal follows the original 2015 MOU, its 2018 amendment, and the 2020 first renewal, now extended to 2026.

EPA Delays Hazardous‑Substance Spill Plans to 2030 and Tweaks Climate Language

Overview

The Environmental Protection Agency (EPA) has proposed a new rule that pushes back the deadline for onshore, non‑transportation facilities to develop and submit Facility Response Plans (FRPs) for worst‑case releases of hazardous substances under the Clean Water Act. The original 2024 final rule required plans to be ready by June 1, 2027; the proposed change extends this to June 1, 2030, giving regulated entities an additional three years to prepare and submit their plans.

The delay is intended to allow EPA to evaluate and offer compliance‑assistance tools that facilities may need to meet the new requirements. EPA estimates that the postponement will save regulated parties and the agency roughly $25–$30 million annually in compliance costs, while still ensuring that plans are developed in a timely, risk‑based manner.

Alongside the date shift, EPA is revising the rule’s language to remove references to climate change and specific environmental‑justice considerations, in line with Executive Order 14148. The agency argues that a purely risk‑based approach—focused on the potential harm of a hazardous‑substance release—provides adequate protection for all communities, without singling out particular populations or climate scenarios.

Key Elements

• Compliance‑date extension:

  • Initial regulated facilities (in operation by Nov 30, 2029) must submit FRPs by June 1, 2030.
    
  • Newly regulated facilities must submit within six months of meeting criteria, but no earlier than June 1, 2030.
    
  • Newly constructed or altered facilities must submit prior to operation, with a 60‑day startup adjustment period.
    

• Cost savings: EPA projects annualized savings of $24–$25 million (7 % discount rate) and $18–$19 million (3 % discount rate) by delaying the compliance date.

• Language changes:

  • “Adverse weather” definition no longer cites climate change.
    
  • Removal of references to “climate change” and “environmental‑justice communities” from several sections (e.g., § 118.5(b)(8), § 118.11(b)(3)(i)).
    
  • Replacement with broader terms such as “potentially exposed or susceptible populations” and “adverse weather conditions.”
    

• Regulatory impact: The rule is deemed deregulatory, with no net burden on small entities and no new information‑collection requirements.

• Public comment period: Comments are accepted until April 6, 2026, allowing stakeholders to weigh in on the delay and language revisions.

Puerto Rico’s Corozal Well Cleans Up: EPA Removes Site from Superfund List

Overview

The U.S. Environmental Protection Agency (EPA) has officially removed the Corozal Well site in Puerto Rico from the National Priorities List (NPL), the federal register of the most hazardous Superfund sites. The deletion follows a comprehensive cleanup under the Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA), confirming that all required remedial actions have been completed and that no further response is necessary.

The decision was based on extensive groundwater monitoring data showing contaminant levels consistently below regulatory limits, and on a remedial investigation that found no remaining source of contamination. While the site is now considered safe for unrestricted use, the EPA notes that future monitoring and maintenance may still occur, and the site remains eligible for additional funding if new conditions arise.

For local stakeholders, the deletion means that responsibility for ongoing well regulation and water quality oversight will shift to Puerto Rico’s Department of Natural and Environmental Resources (PRDNER) and the Department of Health (PRDOH). The action does not eliminate potential liability for responsible parties, nor does it preclude the site from being re‑listed if future contamination is detected.

Key Elements

• Full Deletion: Corozal Well is removed entirely from the NPL; no portions remain listed.
  
• Cleanup Completion: Groundwater and soil remediation achieved all CERCLA remedial objectives; contaminant concentrations are below maximum contaminant levels.
  
• Monitoring Continuation: EPA will continue to monitor the site’s groundwater and conduct five‑year reviews as required by the National Oil and Hazardous Substances Pollution Contingency Plan.
  
• Local Oversight: Post‑deletion, PRDNER and PRDOH will oversee well operation, maintenance, and water quality regulation.
  
• Future Action Eligibility: The site remains eligible for Superfund funding if new contamination or risks emerge; it can be restored to the NPL without a new hazard ranking.
  
• Liability Status: Deletion does not alter responsible party liability; parties remain accountable for any future remedial needs.
  
• Public Participation: The EPA considered six public comments, addressing concerns about groundwater contamination and source‑area investigations, before finalizing the deletion.
  
• Regulatory Context: The action amends 40 CFR Part 300, removing the Corozal Well entry from the NPL appendix and updating the National Contingency Plan accordingly.

Duke Energy’s Bad Creek Pumped‑Storage Expansion Faces Public Review

The Federal Energy Regulatory Commission (FERC) has accepted Duke Energy Carolinas, LLC’s application for a new major license to expand the Bad Creek Pumped Storage Project in South Carolina. The notice, published in the Federal Register on March 4 2026, invites motions to intervene, protests, and comments from the public and stakeholders. The application is now ready for environmental analysis under the Federal Power Act, and the Commission has set deadlines for submissions and for the filing of final amendments.

The Bad Creek Project is a large pumped‑storage facility that moves water between an upper reservoir (≈35,500 acre‑feet) and Lake Jocassee, the lower reservoir. The existing plant has four 350 MW reversible units and generates roughly 1.9 million MWh annually, while consuming about 2.4 million MWh for pumping, resulting in a net loss of ~0.5 million MWh. Duke Energy proposes to add a second complex—Bad Creek II—with four new reversible units (106–425 MW) that would increase annual generation by up to 25,856 MWh without altering the existing reservoirs. The expansion would also involve new infrastructure such as a powerhouse, tunnels, and transmission lines.

Stakeholders have 60 days (until April 28 2026) to file motions to intervene or protests, and 105 days (until June 12 2026) to submit comments, recommendations, terms and conditions, or prescriptions. All filings must be made through FERC’s eFiling system or via paper, and must include the project name and docket number. Duke Energy must also submit water‑quality certification or a waiver by the same April deadline, and final amendments to the application by March 30 2026.

Key Elements

• Project: Bad Creek Pumped Storage Project, Lake Jocassee, Oconee County, SC
  
• Existing capacity: 1,400 MW (four 350 MW units), 1.9 MWh annual generation, 2.4 MWh pumping, net loss ~0.5 MWh
  
• Expansion (Bad Creek II): four new reversible units (106–425 MW), up to +25,856 MWh annual generation, no reservoir modifications
  
• Application status: Accepted for filing, ready for environmental analysis under the Federal Power Act
  
• Public participation deadlines:
  
  • Motions to intervene / protests: April 28 2026, 5 p.m. EST
    
  • Comments / recommendations / terms & conditions / prescriptions: June 12 2026, 5 p.m. EST
    
• Filing methods: eFiling (FERCOnline) or paper; must include project name, docket number, and contact info
  
• Water‑quality certification: required by April 28 2026 (certification, request, or waiver)
  
• Final amendments: due March 30 2026, 5 p.m. EST
  
• Regulatory framework: Federal Power Act, 18 CFR 385 (Rules of Practice and Procedure)
  
• Stakeholder impact: potential effects on water resources, local ecosystems, energy supply, and regional transmission infrastructure.

New Mexico’s Storm‑Water Clean‑Up Plan: A Statewide Permit to Protect Rivers and Communities

Overview

The Environmental Protection Agency (EPA) Region 6 has proposed a new National Pollutant Discharge Elimination System (NPDES) general permit that would cover all municipal separate storm sewer systems (MS4s) in New Mexico’s urbanized areas. The permit is designed to replace two expired permits and to bring the state’s storm‑water program into full compliance with the Clean Water Act’s Phase I and Phase II requirements. By authorizing a single, statewide permit, the EPA aims to streamline permitting, reduce administrative burdens for local governments, and ensure consistent protection of the state’s rivers, lakes, and groundwater.

The core of the proposal is a set of discharge control conditions that require MS4 operators to implement best management practices (BMPs) and a comprehensive storm‑water management plan (SWMP). These measures are intended to prevent non‑stormwater pollutants from entering the sewer system and to reduce the concentration of pollutants in storm‑water discharges to the maximum extent practicable (MEP). The permit also incorporates the six minimum control measures outlined in 40 CFR 122.34(b), covering source‑control, detention, infiltration, and treatment options.

Stakeholders—including municipalities, water‑quality advocates, and the general public—have 61 days to submit comments (until May 4, 2026). A virtual public hearing will follow the comment period. The EPA will consider all timely comments before issuing the final permit, which will set the legal framework for storm‑water management across New Mexico for the next decade.

Key Elements

• Coverage: All MS4s within the Bureau of the Census‑designated urbanized areas (2000, 2010, 2020) and any additional systems the Director designates.
  
• Phase I & Phase II Integration: Combines requirements for large/medium MS4s (Phase I) and small MS4s in urbanized areas (Phase II) into a single general permit.
  
• Maximum Extent Practicable (MEP): Operators must achieve pollutant reductions to the highest level practicable, using BMPs and engineering controls.
  
• Best Management Practices (BMPs): Mandatory implementation of the six minimum control measures (source control, detention, infiltration, etc.) as outlined in 40 CFR 122.34(b).
  
• Storm‑Water Management Plan (SWMP): A comprehensive plan that must be developed, implemented, and maintained to meet statutory requirements.
  
• Public Participation: 61‑day comment period ending May 4, 2026, with a virtual public hearing scheduled thereafter.
  
• Administrative Record: Draft permit, fact sheet, and supporting documents available online via the EPA docket (Regulations.gov).
  
• Legal Basis: Clean Water Act (33 U.S.C. 1251 et seq.) and the 1987 Water Quality Act amendments.
  
• Implications for Water Quality: Aims to restore and maintain the chemical, physical, and biological integrity of New Mexico’s waters by reducing storm‑water pollution.

Appalachian Pipeline Project Gets Environmental Assessment, Public Comment Window Opens

Overview
Eastern Gas Transmission and Storage, Inc. (EGTS) has released an Environmental Assessment (EA) for its proposed Appalachian Reliability Project, a 3.9‑mile, 30‑inch natural‑gas pipeline that will run through Armstrong, Greene, and Westmoreland counties in Pennsylvania and Monroe County in Ohio. The project is designed to deliver roughly 550,000 dekatherms per day of firm natural‑gas capacity to the interstate grid, thereby enhancing reliability for the region’s energy supply.

Under the National Environmental Policy Act (NEPA), the EA evaluates potential environmental impacts, considers reasonable alternatives, and recommends mitigation measures. The assessment concludes that the project would not constitute a major federal action significantly affecting the quality of the human environment, meaning that the project is unlikely to trigger a more extensive environmental review.

EGTS invites public participation in the review process. Comments on the EA are due by 5:00 p.m. Eastern Time on March 30, 2026. The EA is available in electronic format on the Federal Energy Regulatory Commission (FERC) website, and stakeholders can submit comments via FERC’s eComment or eFiling systems, or by mail.

Key Elements

• Project Scope: 3.9 miles of 30‑inch natural‑gas pipeline, additional compression at two existing stations, a new metering and regulation station, and modifications to two existing stations.
  
• Capacity: Approximately 550,000 dekatherms per day of firm natural‑gas transportation.
  
• Location: Armstrong, Greene, and Westmoreland counties, Pennsylvania; Monroe County, Ohio.
  
• NEPA Finding: EA concludes the project is not a major federal action, reducing the need for a full Environmental Impact Statement.
  
• Public Comment Period: Deadline March 30, 2026; comments should address environmental effects, alternatives, and mitigation.
  
• Access to EA: Available electronically on FERC’s website (https://www.ferc.gov).
  
• Comment Submission Methods:
  
  1. eComment (text‑only)
     
  2. eFiling (file attachments)
     
  3. Paper mail to FERC, Washington, DC or Rockville, MD.
     
• 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.
  
• Stakeholder Engagement: The EA has been distributed to federal, state, and local agencies, elected officials, environmental groups, Native American tribes, landowners, and the general public.

Geomagnetic Storms and the Power Grid: FERC Extends Data‑Gathering Requirements

Overview

The Federal Energy Regulatory Commission (FERC) has extended the approved information‑collection period for its mandatory reliability standard TPL‑007‑4 (FERC‑725N). This standard requires owners and operators of the bulk‑power system to assess how geomagnetic disturbance events—such as solar storms—could affect power‑grid equipment and to develop corrective action plans. The extension keeps the current reporting requirements unchanged, giving stakeholders additional time to comply while the Commission continues to monitor the grid’s resilience to space‑weather events.

The notice invites public comment until May 4, 2026. Comments can be submitted electronically through FERC’s website or by mail. The Commission seeks input on the necessity, accuracy, and potential improvements to the data collection, as well as ways to reduce the burden on respondents.

Key Elements

• Standard Purpose: TPL‑007‑4 mandates vulnerability assessments for geomagnetic disturbances and corrective action plans to protect the bulk‑power system.
• Who Must Report: Generator owners, planning coordinators, distribution providers, and transmission owners are required to submit annual data.
• Burden Estimate: Approximately 82,200 hours of work and $5.2 million in costs per year across all reporting entities.
• Extension Details: The information‑collection period is extended without any changes to the standard’s requirements or reporting format.
• Regulatory Context: The standard is part of the Energy Policy Act of 2005, certified by the North American Electric Reliability Corporation (NERC) as the Electric Reliability Organization (ERO).
• Comment Opportunities: Stakeholders can suggest improvements to data quality, clarity, and automation, and can propose ways to reduce reporting burdens.
• Submission Channels: Comments are accepted electronically via FERC’s online portal, or by mail to Washington, DC, or Rockville, MD.

This extension underscores the ongoing effort to safeguard the electric grid against natural space‑weather hazards while balancing the administrative load on industry participants.

Storm‑Water Stewardship for Tribal Communities in New Mexico and Oklahoma

Overview

The U.S. Environmental Protection Agency (EPA) has issued a notice proposing a new National Pollutant Discharge Elimination System (NPDES) general permit that will cover storm‑water discharges from tribal municipal separate storm sewer systems (MS4s) in New Mexico and Oklahoma. The permit is intended to replace two expired permits and will apply to all MS4s located within the Census‑defined urbanized areas of these states, as well as any additional systems the EPA Director designates. By consolidating Phase I (large and medium MS4s) and Phase II (small MS4s) requirements into a single permit, the EPA aims to streamline compliance while ensuring that storm‑water runoff meets the Clean Water Act’s maximum‑extent‑practicable (MEP) pollutant‑reduction standard.

The proposal invites public comment until May 4, 2026, and will be followed by a virtual public hearing. Stakeholders—including tribal governments, local municipalities, environmental groups, and industry—can submit written comments through Regulations.gov or by email. The EPA will consider all comments received before the final decision on the permit.

Key Elements

• Scope and Coverage

  • Applies to all tribal MS4s in New Mexico and Oklahoma that serve urbanized areas (population ≥ 100,000) and any additional systems designated by the EPA Director.
  • Combines Phase I (large/medium) and Phase II (small) storm‑water regulations into one general permit.

• Regulatory Basis

  • Grounded in the Clean Water Act (CWA) § 402(p)(3)(B) and the 1987 Water Quality Act amendments.
  • Requires that storm‑water discharges be free of non‑stormwater pollutants and meet MEP standards.

• Control Measures

  • Mandates a comprehensive Stormwater Management Program (SWMP) that includes best management practices (BMPs) addressing the six minimum control measures outlined in 40 CFR 122.34(b).
  • BMPs cover source‑control, detention/retention, infiltration, and other engineering or design solutions.

• Administrative and Compliance Features

  • Provides a single permit structure to reduce administrative burden for tribal and local authorities.
  • Requires documentation of BMP implementation, monitoring, and reporting to the EPA.
  • Includes provisions for enforcement and penalties for non‑compliance.

• Public Participation

  • Comments accepted until May 4, 2026; a virtual hearing will be scheduled thereafter.
  • EPA encourages comments via Regulations.gov, email, or mail, with guidance on confidential business information and multimedia submissions.

• Environmental Goals

  • Aims to protect water quality by reducing pollutants in storm‑water runoff, thereby supporting the CWA’s objective to restore and maintain the chemical, physical, and biological integrity of the nation’s waters.

This proposal represents a significant step toward modernizing storm‑water regulation for tribal communities, balancing regulatory rigor with practical implementation for the unique needs of New Mexico and Oklahoma.

Klamath Falls Air Quality Gets the Green Light: EPA Approves Redesignation to Attainment

Overview

The Environmental Protection Agency (EPA) is proposing to approve Oregon’s request to redesignate the Klamath Falls area from a nonattainment zone to an attainment zone for fine particulate matter (PM₂.₅) under the 2006 24‑hour National Ambient Air Quality Standard (NAAQS). The proposal also includes approval of a 10‑year maintenance plan that will keep the area in compliance through 2037. The action reflects the state’s successful implementation of a range of permanent and enforceable measures—particularly those targeting residential wood‑burning emissions—that have lowered PM₂.₅ concentrations below the federal standard.

If finalized, the redesignation will remove Klamath Falls from the list of nonattainment areas, allowing the region to shift from stricter nonattainment regulations to maintenance‑level requirements. The maintenance plan will require continued monitoring, inventory updates, and contingency measures to respond quickly to any future exceedances, ensuring long‑term air quality protection for residents, wildlife, and the local ecosystem.

Key Elements

• Redesignation to Attainment – EPA will recognize that the area has consistently met the 2006 24‑hour PM₂.₅ standard, based on recent monitoring data (2022‑2024 design value of 34 µg/m³).
• Maintenance Plan Approval – A 10‑year plan (through 2037) that includes:
  • An attainment emissions inventory for 2017 and projected inventories for 2037.
  • A monitoring network to verify continued compliance.
  • Contingency procedures to address any future violations.
• Permanent Control Measures – Enforcement of wood‑burning curtailment notifications, woodstove change‑out programs, and restrictions on non‑certified solid‑fuel devices.
• Transportation Conformity – Motor‑vehicle emissions budgets for PM₂.₅ and NOₓ have been reviewed and deemed adequate, supporting transportation projects that do not jeopardize air quality.
• State Rule Updates – Oregon’s revisions to the Klamath County Clean Air Ordinance and related state regulations will be incorporated into the State Implementation Plan (SIP).
• Public Comment Period – Stakeholders have until April 3, 2026 to submit comments on the proposed rule.

EPA Proposes Removing Eight Superfund Sites from the National Priorities List

Overview

The Environmental Protection Agency (EPA) has announced a proposed rule to delete six Superfund sites in full and two sites partially from the National Priorities List (NPL). The NPL, established under the Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA), identifies locations that pose significant risks to public health or the environment. Deletion indicates that all required remedial actions have been completed and no further response is deemed necessary, although the sites remain eligible for future Superfund action if conditions change.

The proposed deletions cover a range of contamination types—including soil, groundwater, and landfill sites—across states such as Illinois, New York, Kentucky, Florida, Georgia, and Nebraska. EPA’s decision follows extensive state consultation, five‑year reviews, and the preparation of Final Close‑Out Reports or Partial Deletion Justifications that demonstrate the effectiveness of cleanup efforts.

Public comment is invited for 30 days (through April 3, 2026). EPA will consider feedback before issuing a final notice. Even after deletion, the EPA retains enforcement authority, and ongoing monitoring, operation, and maintenance of remedies may continue as required by CERCLA.

Key Elements

• Sites Proposed for Deletion

  • Full deletions: Rowe Industries (NY), Kerr‑McGee (IL), Caldwell Lace Leather (KY), Pepper Steel & Alloys (FL), Miami Drum Services (FL), Diamond Shamrock Landfill (GA).
    
  • Partial deletions: Velsicol Chemical Corp. (IL – land/soil portion), Hastings Ground Water Contamination (NE – groundwater and landfill cap).
    

• Deletion Criteria

  • All responsible parties have completed required remedial actions.
    
  • No further response is appropriate under CERCLA.
    
  • Five‑year reviews confirm continued protectiveness.
    

• Process and Public Participation

  • EPA consulted with state agencies and provided 30 working days for review.
    
  • Notice of intent published in the Federal Register; public comment period of 30 days.
    
  • Comments submitted via Regulations.gov or email to designated EPA contacts.
    

• Post‑Deletion Oversight

  • Sites remain subject to monitoring, operation, and maintenance of remedies.
    
  • EPA may restore a site to the NPL if a significant release occurs.
    
  • Deletion does not alter responsible party liability or EPA’s enforcement powers.
    

• Implications for Geoscience and Natural Resources

  • Confirms that soil and groundwater contamination has been remediated to acceptable levels.
    
  • Highlights the role of long‑term monitoring and five‑year reviews in ensuring environmental protection.
    
  • Provides a framework for evaluating future risks and potential re‑classification of sites.

Solano Irrigation District Announces Hydropower License Application for Monticello Project

Overview

The Federal Energy Regulatory Commission (FERC) has approved the Solano Irrigation District’s request to pursue a traditional licensing process for the Monticello Power Plant Project, a proposed hydropower facility near Winters, California. The district filed a Notice of Intent to File License Application and a Pre‑Application Document (PAD) in December 2025, and FERC’s February 2026 approval formally initiates the licensing sequence.

The project will harness water flow from the existing infrastructure in Napa, Solano, and Yolo counties to generate renewable electricity, potentially adding clean power to the regional grid while supporting local water management needs. The licensing process will involve detailed environmental and technical studies, public comment periods, and coordination with federal and state agencies.

FERC is also beginning informal consultations under the Endangered Species Act, the Magnuson‑Stevens Fishery Conservation and Management Act, and the National Historic Preservation Act. These consultations aim to assess impacts on wildlife, fisheries, and historic resources before the project proceeds to full licensing.

Key Elements

• Project: Monticello Power Plant Project – a hydropower facility near Winters, California.
  
• Licensing Path: Traditional FERC licensing process, approved on February 25, 2026.
  
• Pre‑Application Document: Submitted December 12, 2025; includes proposed process plan and schedule.
  
• Environmental Consultations:
  
  • U.S. Fish and Wildlife Service (Section 7, Endangered Species Act).
    
  • NOAA Fisheries (Section 305(b), Magnuson‑Stevens Act).
    
  • California State Historic Preservation Officer (Section 106, National Historic Preservation Act).
    
• Public Participation: Contact information for inquiries, comments, and interventions provided.
  
• Stakeholder Coordination: Solano Irrigation District designated as FERC’s non‑federal representative for consultations.
  
• Regulatory References: 18 CFR 5.3 (notice of intent), 18 CFR 5.6 (pre‑application), 50 CFR 402 (ESA), 50 CFR 600.920 (Magnuson‑Stevens), 36 CFR 800.2 (NHPA).

USGS Seeks Public Input on Ash‑Fall Reporting System

Overview

The U.S. Geological Survey (USGS) is renewing its Ash Fall Report information‑collection program, a voluntary system that lets residents, local governments, and emergency managers submit real‑time observations of volcanic ash falling in their area. The data feed directly into the Alaska Volcano Observatory (AVO) and help refine ash‑fall forecasts, improve warning messages, and support scientific research on eruption dynamics.

The notice, published in the Federal Register on March 3 2026, invites comments until May 4 2026. Respondents are estimated at about 250 per year, with each submission taking roughly five minutes. The total annual burden is projected at 21 hours of volunteer time, and the program is expected to enhance the accuracy of ash‑fall models and the effectiveness of emergency response.

For geoscientists, energy and mineral resource planners, and environmental professionals, the collection offers a richer, ground‑truth dataset that complements satellite imagery and atmospheric models. By engaging the public in data gathering, the USGS aims to reduce the societal and economic impacts of volcanic ash, from infrastructure damage to health risks.

Key Elements

• Renewal of OMB Control Number 1028‑0106 – the program is an extension of a previously approved information collection.
  
• Voluntary, low‑burden reporting – estimated 5 minutes per submission, 21 total annual burden hours.
  
• Target respondents – general public, local governments, and emergency managers across the United States.
  
• Real‑time data flow – reports are entered via a web form on the AVO site and immediately available to AVO staff for rapid decision‑making.
  
• Historical data use – retrospective reports improve ash‑fall models, support research on eruptive processes, and refine future forecasts.
  
• Public visibility – ash‑fall reports are displayed on a dynamic map for 24 hours, with aging indicators to help users assess recency.
  
• Stakeholder engagement – the notice solicits comments on necessity, burden estimates, data quality, and potential automation to further reduce respondent effort.
  
• Implications for resource management – accurate ash‑fall information aids in protecting energy infrastructure, water supplies, transportation networks, and agricultural operations.

BLM to File New Survey Maps in Utah – A Window for Public Input

Overview

The Bureau of Land Management (BLM) has announced that several newly completed plats of survey will be officially filed in its Utah State Office on April 2, 2026. These plats—detailed maps that record the boundaries and features of public lands—were prepared at the request of the BLM and the Bureau of Indian Affairs (BIA). The filing is a routine step that finalizes the legal description of the surveyed parcels, enabling the BLM to manage, lease, or otherwise administer the land in accordance with federal statutes.

The notice invites interested parties to protest the official filing. Protests must be submitted in writing to the BLM Utah State Director no later than the scheduled filing date. If a protest is received on time, the filing will be paused until the protest is reviewed. After the filing, the plats will be available for public inspection at the BLM office in Salt Lake City, and copies can be requested for a fee.

This action underscores the importance of accurate cadastral records for land management, resource development, and tribal land stewardship. By ensuring that survey data are officially recorded, the BLM supports transparent decision‑making for future land use, conservation, and potential resource extraction projects across Utah.

Key Elements

• Scheduled filing date: April 2, 2026 (BLM Utah State Office, Salt Lake City).
  
• Protest deadline: Must be received by the filing date; late protests are untimely.
  
• How to protest: Written notice to BLM Utah State Director, identifying specific plat(s).
  
• Plats involved:
  
  • T. 42 S., R. 20 E., Group 1483 (BIA request, accepted Sept 26 2025).
    
  • T. 40 S., R. 23 E., Group 1340 (BLM request, accepted Sept 26 2025).
    
  • T. 41 S., R. 23 E., Group 1480 (BIA request, accepted Sept 26 2025).
    
• Location of plats: Public Room, BLM Utah State Office, 440 W. 200 S., Suite 500, Salt Lake City (viewing free, copies for fee).
  
• Contact: Matthew J. Kurchinski, BLM Chief Cadastral Surveyor for Utah – phone (801) 539‑4139 or email mkurchin@blm.gov.
  
• Purpose: Finalize legal descriptions to support land management, leasing, and resource planning under federal law.
  
• Implications: Accurate plats aid in resolving boundary disputes, guiding mineral and energy development, and ensuring compliance with tribal and federal land use policies.

BLM Announces Official Filing of Key Survey Plats in the Dakotas

Overview

The U.S. Bureau of Land Management (BLM) has issued a notice that the plats of survey for specific parcels in North and South Dakota will be officially filed 30 days after this publication. These surveys, completed at the request of the Bureau of Indian Affairs (BIA) Great Plains Region, are essential for accurate land management and future resource planning in the region.

The filing process opens a brief window for interested parties to protest the official recording of the plats. Protests must be submitted to the BLM Montana/Dakotas State Office by April 2, 2026. If a protest is received on time, the filing will be paused until the protest is resolved, ensuring that any concerns about boundary accuracy or land use are addressed before finalization.

Once filed, the plats will become part of the public record, providing clear, legally recognized boundaries for landowners, developers, and government agencies. The documents are available for viewing at the BLM Montana State Office in Billings, Montana, and can be obtained for a nominal fee.

Key Elements

• Official Filing Schedule – 30 calendar days after publication (March 3, 2026).
  
• Protest Deadline – Notices of protest must reach BLM Montana/Dakotas State Office by April 2, 2026.
  
• Access to Plats – Available for free viewing or for purchase at the BLM Montana State Office, 5001 Southgate Drive, Billings, MT.
  
• Contact Information – Thomas L. Laakso, Chief Cadastral Surveyor, (406) 896‑5125, tlaakso@blm.gov.
  
• Survey Details –
  
  • North Dakota: Dependent resurvey of Section 25, Township 162 N, Range 71 W (Group 111).
    
  • South Dakota: Dependent resurvey of Section 20, Township 94 N, Range 64 W (Group 196).
    
• Legal Basis – Authority under 43 U.S.C. § 301.
  
• Implications for Geoscience & Resource Management – Provides precise cadastral data critical for mapping, land use planning, mineral rights delineation, and environmental assessments.

Oil & Gas Valuation: Renewing the Data‑Gathering Playbook

Overview

The U.S. Department of the Interior’s Office of Natural Resources Revenue (ONRR) has announced the renewal of its federal oil and gas valuation information collection under OMB Control Number 1012‑0005. The renewal, published in the Federal Register on March 3, 2026, seeks to keep the agency’s data‑collection framework current so it can accurately assess royalties, transportation and processing allowances, and relief options for marginal properties on federal leases.

The notice invites public comment until May 4, 2026, and explains that the collection covers mandatory reporting by federal oil and gas lessees and state agencies. It also highlights the use of specific forms—ONRR‑4393 for allowance‑exceedance requests and ONRR‑2014 for sales and royalty remittance reporting—along with the estimated burden of 9,913 annual hours across roughly 139 responses.

By renewing this collection, ONRR aims to streamline paperwork, reduce respondent burden, and ensure that royalty calculations and related relief programs remain transparent and compliant with the Paperwork Reduction Act.

Key Elements

• Renewal of Information Collection – OMB‑approved extension of the federal oil and gas valuation data‑collection program.
  
• Purpose – Verify royalty payments, evaluate transportation/processing allowances, and process relief requests for marginal properties.
  
• Forms Involved –
  
  • ONRR‑4393: Request to exceed regulatory allowance limits.
    
  • ONRR‑2014: Report of Sales and Royalty Remittance (not included in this burden estimate).
    
• Estimated Burden – 9,913 annual hours, averaging 71.32 hours per response, across ~139 annual submissions.
  
• Respondents – 120 federal lessees/designees and 7 state agencies.
  
• Comment Period – Open until May 4, 2026; submissions via regulations.gov or email to ONRR.
  
• Transparency – Comments will be publicly posted; ONRR will summarize them in its request to OMB.
  
• Regulatory Context – Covers 30 CFR parts 1202, 1204, and 1206, which govern royalties, marginal property relief, and product valuation.
  
• Goal – Reduce paperwork, improve data quality, and maintain compliance with the Paperwork Reduction Act.

Flow‑Cutting Drought Relief: FERC’s Environmental Assessment for Great River Hydro

Overview

The Federal Energy Regulatory Commission (FERC) has released an Environmental Assessment (EA) evaluating a proposed temporary reduction in water flow from the Comerford Dam on the Connecticut River. Great River Hydro, LLC seeks to lower the minimum flow to 600 cubic feet per second (cfs) from September 29, 2025 through January 31, 2026, citing severe drought that has depleted the upstream Moore Reservoir’s storage capacity. The aim is to preserve reservoir levels and avoid further flow cuts should the drought worsen.

The EA, prepared under the National Environmental Policy Act (NEPA) and FERC’s 18 CFR 380 regulations, analyzes the potential impacts on the river’s ecosystem, water quality, fish and wildlife, and downstream users. The assessment concludes that the temporary variance would not constitute a major federal action and is unlikely to significantly affect the human environment. Nonetheless, it documents possible ecological effects and recommends monitoring and mitigation measures.

Public stakeholders are invited to review the EA and submit comments through FERC’s electronic filing system by March 27, 2026. The decision will balance the need for water resource conservation during a drought with the protection of the Connecticut River’s ecological integrity.

Key Elements

• Project Scope: Temporary variance from the Comerford Dam’s minimum flow requirement for the Fifteen Mile Falls Hydroelectric Project (Project No. 2077-130).
  
• Flow Reduction: 600 cfs from September 29, 2025 to January 31, 2026, down from the standard minimum flow.
  
• Environmental Assessment Findings:
  
  • Not a major federal action under NEPA.
    
  • Potential minor impacts on fish, wildlife, and water quality; no significant adverse effects projected.
    
  • Recommends monitoring of river conditions and adaptive management if conditions change.
    
• Public Comment Period: Open until March 27, 2026 (5:00 p.m. Eastern Time).
  
• Access to EA: Available on FERC’s eLibrary (docket P‑2077) and in PDF form on the official Federal Register.
  
• Contact Information:
  
  • FERC Online Support: FERCOnlineSupport@ferc.gov or 1‑866‑208‑3676.
    
  • Office of Public Participation: (202) 502‑6595 or OPP@ferc.gov.
    
• Regulatory Context: FERC’s authority under 18 CFR 2.1 and 18 CFR 380; compliance with NEPA.
  
• Implications for Geoscience & Natural Resources:
  
  • Highlights the interplay between hydropower operations and riverine ecosystems during drought.
    
  • Provides a case study on adaptive water management and NEPA compliance for hydroelectric projects.

PGE Seeks Temporary Water Flow Flexibility to Protect Salmon and Optimize Hydropower

Overview

The Federal Energy Regulatory Commission (FERC) has published a notice that Pacific Gas and Electric Company (PGE) has filed an application for a temporary variance to the minimum flow requirements on the West Branch Feather River and Philbrook Creek. The variance would allow the company to reduce instantaneous minimum flows from 15 cfs (normal year) and 7 cfs (dry year) on the Feather River, and from 2 cfs on Philbrook Creek, to lower levels for up to 48 hours. The change is intended to improve water‑storage efficiency, increase cold‑water releases to Butte Creek, and reduce water residence time in the DeSabla Forebay, thereby mitigating high‑temperature impacts on Central Valley spring‑run Chinook salmon.

The request is scheduled to take effect from May 4, 2026 through September 30, 2026, with a possible earlier start in Philbrook Creek if reservoir storage permits and if approved by the California Department of Fish and Wildlife, the National Marine Fisheries Service, and the U.S. Fish and Wildlife Service. PGE argues that the variance will preserve cold‑water storage, enhance summer flow to the creek, and reduce the need for buffer releases that currently strain downstream ecosystems.

FERC is inviting public comments, protests, and motions to intervene by March 30, 2026. Stakeholders—including federal, state, local, and tribal agencies—are encouraged to cooperate in preparing environmental documents, though they cannot intervene in the proceeding. The notice provides electronic filing instructions and contact information for assistance.

Key Elements

• Project: DeSabla‑Centerville hydroelectric project on Butte Creek, West Branch Feather River, and tributaries in Butte County, California.
  
• Variance Request:
  
  • Feather River: reduce instantaneous minimum flow from 15 cfs (normal) / 7 cfs (dry) to 7 cfs for 48 hours.
    
  • Philbrook Creek: reduce instantaneous minimum flow from 2 cfs to 1–2 cfs for 48 hours.
    
  • Effective period: May 4 – Sept 30 2026 (possible earlier start in Philbrook Creek).
    
• Environmental Rationale:
  
  • Preserve cold‑water storage in Philbrook Reservoir.
    
  • Increase flow to Butte Creek via Hendricks Canal.
    
  • Decrease residence time in DeSabla Forebay, reducing summer water temperatures that threaten Chinook salmon.
    
• Stakeholder Cooperation: Federal, state, local, and tribal agencies may assist in environmental documentation but cannot intervene.
  
• Public Participation: Comments, protests, and motions to intervene must be filed by March 30 2026, with electronic filing encouraged.
  
• Regulatory Context: Application filed under the Federal Power Act; subject to FERC Rules of Practice and Procedure.

US Trade Commission Keeps Antidumping Duties on Ferrovanadium to Protect Domestic Steel Industry

Overview

Ferrovanadium, a key alloying element used to strengthen steel, is imported in large volumes from China and South Africa. In 2025 the U.S. International Trade Commission (ITC) began a five‑year review of the antidumping duty orders that protect U.S. ferrovanadium producers from cheaper foreign imports. The review was expedited in late 2025 and concluded in February 2026.

On March 3 2026 the ITC issued a notice confirming that revoking the antidumping duties would likely lead to a continuation or recurrence of material injury to the U.S. ferrovanadium industry. The Commission therefore maintains the duties, ensuring that domestic producers can compete against imports that are priced below fair market value.

For geoscience and natural‑resource stakeholders, this decision underscores the importance of stable supply chains for critical alloying elements. It also highlights how trade policy can directly influence the availability of mineral‑derived products that are essential to the manufacturing of infrastructure, vehicles, and energy‑related equipment.

Key Elements

• Antidumping Duty Status – The ITC has determined that the duties on ferrovanadium from China and South Africa must remain in place to prevent injury to U.S. producers.
  
• Five‑Year Review – This is the fourth review in a series of five‑year investigations, reflecting ongoing monitoring of market conditions and trade practices.
  
• Expedited Review Process – The Commission accelerated the review in December 2025, completing determinations by February 2026.
  
• Impact on U.S. Industry – Revocation of duties could lead to material injury, affecting jobs, technology development, and the domestic supply of high‑strength steel alloys.
  
• Trade Policy Implications – The decision illustrates how the U.S. uses antidumping measures to safeguard critical mineral‑derived industries from unfair foreign competition.

BSEE Tightens Rules on Mixing Oil and Gas in Offshore Wells to Protect Safety and Resources

Overview

The Bureau of Safety and Environmental Enforcement (BSEE) has finalized a rule that updates the federal regulations governing downhole commingling— the practice of mixing hydrocarbons from multiple reservoirs within a single wellbore— on the Outer Continental Shelf (OCS). The rule, effective March 2 2026, aligns the agency’s procedures with the “One Big Beautiful Bill” (OBBB) Act, which requires BSEE to approve commingling requests unless it can demonstrate that the operation would be unsafe or would reduce ultimate resource recovery.

The update revises 30 CFR 250.1158, clarifying that operators must submit detailed technical, geological, and economic data before BSEE can grant approval. The agency maintains that operators remain responsible for ensuring safety, environmental protection, and optimal recovery, and that the new rule does not add significant costs or regulatory burdens. BSEE also confirmed that the rule does not trigger major environmental or economic impacts and that it does not impose new information‑collection requirements.

For industry stakeholders, the rule means a more transparent and consistent approval process that reflects the latest statutory mandate while preserving the rigorous safety and resource‑conservation standards that have long governed offshore drilling.

Key Elements

• Alignment with OBBB: The rule updates BSEE’s commingling regulations to match the statutory language of the OBBB Act, ensuring that approval is granted unless conclusive evidence shows the operation would be unsafe or reduce recovery.
  
• Approval Process: Operators must request approval from a Regional Supervisor and provide comprehensive supporting information (geology, seismic data, well logs, engineering analyses, and economic justification).
  
• Operator Responsibilities: The rule does not shift responsibility away from operators; they must still demonstrate that safety, environmental, and resource‑conservation risks are fully considered and mitigated.
  
• No New Fees or Mandates: The rule does not introduce additional service fees or unfunded mandates, and it does not impose new paperwork or reporting burdens beyond existing requirements.
  
• Environmental and Economic Impact: BSEE determined the rule has no significant adverse effects on the environment or the economy, and it is exempt from a major environmental review under NEPA.
  
• Data Collection: No new information‑collection requirements are added; existing measurement and reporting standards under 30 CFR 250.1167 and related subparts remain in force.
  
• Public Participation: While the rule was issued as a direct final rule, BSEE acknowledged comments and clarified that it will continue to consider stakeholder input in future guidance and potential outreach.

US Grants Exception to Belarus Potash Trade Amid Ongoing Sanctions

Overview

The U.S. Department of the Treasury’s Office of Foreign Assets Control (OFAC) has issued General License No. 13, which permits certain transactions with three major Belarusian potash producers: the Joint Stock Company Belarusian Potash Company, Agrorozkvit LLC, and Belaruskali OAO. The license was first announced on December 15, 2025 and is now formally published in the Federal Register.

This move comes while the U.S. maintains broad sanctions against Belarus under the Belarus Sanctions Regulations (31 CFR part 548). The license specifically allows trade that would otherwise be prohibited, but it does not lift any property‑blocking measures or authorize dealings with other sanctioned individuals or entities. The decision reflects a targeted approach to keep critical agricultural inputs—potash, a key fertilizer mineral—available to U.S. and allied markets while preserving pressure on the Belarusian regime.

For stakeholders in geoscience, mineral resources, and trade, the license clarifies which transactions remain permissible and underscores the importance of potash in global food security. It also signals that U.S. policy is balancing economic interests with geopolitical objectives, a nuance that will shape future supply‑chain decisions in the fertilizer sector.

Key Elements

• General License No. 13 – authorizes transactions with the Belarusian potash companies and any entity in which they hold a 50 % or greater interest.
  
• Scope of Authorization – covers all activities that would otherwise be prohibited under the Belarus Sanctions Regulations, except those involving blocked property or other sanctioned parties.
  
• Limitations – does not unblock any property, nor does it permit transactions with other blocked individuals or entities unless separately authorized.
  
• Effective Date – the license was issued on December 15, 2025; the Federal Register publication confirms its availability to the public.
  
• Contact Information – inquiries can be directed to OFAC’s Assistant Director for Regulatory Affairs (phone: 202‑622‑4855) or via the OFAC website.
  
• Regulatory Context – part of 31 CFR part 548, the Belarus Sanctions Regulations, which impose broad restrictions on U.S. dealings with Belarusian entities.
  
• Implications for Trade – enables continued U.S. and allied access to potash products from Belarus, supporting agricultural supply chains while maintaining overall sanctions pressure.

Las Vegas to Turn 122 Acres of Public Land into a New City Park – BLM Seeks Public Input

Overview

The Bureau of Land Management (BLM) has announced that it has identified roughly 121.95 acres of federal land in northwest Las Vegas, Nevada, as suitable for recreation and public purposes under the Recreation and Public Purposes (R&PP) Act. The land, bounded by Log Cabin Way, El Capitan Way, and future road extensions, will be leased to the City of Las Vegas and subsequently conveyed for the development of a public park featuring sports fields, trails, parking, and related facilities.

The proposal follows a series of environmental reviews, including a 2016 Multi‑Action Analysis Environmental Assessment and a 2023 National Environmental Policy Act (NEPA) adequacy determination, confirming that the project meets federal environmental standards. The BLM’s decision is consistent with the Las Vegas Valley Disposal Boundary Final Environmental Impact Statement and the 1998 Las Vegas Resource Management Plan.

Public comment is invited until April 16, 2026. If no adverse comments are received, the lease and conveyance will become effective on May 1, 2026. The notice will also appear weekly in the Las Vegas Review‑Journal for three consecutive weeks, ensuring local residents have ample opportunity to weigh in.

Key Elements

• Land Classification – 121.95 acres in Clark County, NV, deemed suitable for recreation under the R&PP Act.
  
• Lease & Conveyance – BLM will lease the land to the City of Las Vegas and then convey it, allowing the city to develop a public park.
  
• Mineral Rights – The lease preserves U.S. mineral rights; the lessee may not mine or prospect without separate authorization.
  
• Environmental Compliance – Project approved by NEPA, with prior Environmental Assessment and DNA studies confirming no significant adverse impacts.
  
• Public Participation – Comments on suitability, proposed use, and administrative procedures are accepted until April 16, 2026; protests may be filed with the Nevada State Director.
  
• Timeline – Notice published March 2, 2026; decision effective May 1, 2026 if no adverse comments.
  
• Geoscience Relevance – The land’s geological setting is documented in official surveys; any future mining or resource extraction remains under federal jurisdiction, ensuring that natural resource interests are safeguarded while enabling recreational development.

US Trade Review: Will Removing Aluminum Duties Help or Hurt American Industry?

Overview

The U.S. International Trade Commission (ITC) has opened a five‑year review of the countervailing and antidumping duty orders that were imposed on common alloy aluminum sheet (CAAS) from a broad group of countries. The review, announced in the Federal Register on March 2 2026, seeks to determine whether revoking these duties would likely lead to continued or new material injury to U.S. producers of CAAS. The orders were originally issued on April 27 2021, and the ITC is now evaluating the economic impact of lifting them.

The scope of the review covers CAAS imported from Bahrain, Brazil, Croatia, Egypt, Germany, India, Indonesia, Italy, Oman, Romania, Serbia, Slovenia, South Africa, Spain, Taiwan, and Turkey. The ITC will consider factors such as import volumes, price effects, and the overall health of the domestic aluminum sheet industry. The outcome could influence tariffs on a key construction and manufacturing material used in everything from building envelopes to aerospace components.

Stakeholders—including U.S. manufacturers, unions, importers, and exporters—have until April 1 2026 to submit written responses, and until May 8 2026 to comment on the adequacy of those responses. The ITC will use the information provided to decide whether to conduct a full or expedited review, potentially reshaping trade policy for a material that underpins many sectors of the U.S. economy.

Key Elements

• Purpose – Five‑year review under the Tariff Act to assess whether revoking duties would cause material injury to U.S. CAAS producers.
  
• Countries Covered – Bahrain, Brazil, Croatia, Egypt, Germany, India, Indonesia, Italy, Oman, Romania, Serbia, Slovenia, South Africa, Spain, Taiwan, Turkey.
  
• Types of Duties Reviewed – Countervailing duties (CVD) on CAAS from Bahrain, India, Turkey; antidumping duties (ADD) on CAAS from the 16 countries listed above.
  
• Order Effective Date – April 27 2021.
  
• Deadlines – Responses due April 1 2026; comments on response adequacy due May 8 2026.
  
• Response Requirements – Parties must provide detailed data on production, imports, pricing, market conditions, and potential injury, using the ITC’s “NOI worksheet” and adhering to confidentiality and certification rules.
  
• Definitions – Domestic Like Product (U.S. CAAS), Domestic Industry (all U.S. CAAS producers), Subject Merchandise (CAAS from the listed countries).
  
• Participation – Any interested party—including producers, unions, importers, exporters, and trade associations—can file an appearance and submit information.
  
• Potential Impact – Outcomes could affect tariffs on aluminum sheet used in construction, automotive, aerospace, and consumer goods, influencing supply chains, pricing, and employment.
  
• Legal Framework – Conducted under Title VII of the Tariff Act of 1930; governed by ITC rules (19 CFR part 201 and 207).
  
• Public Access – Proceedings and filings are available through the ITC’s Electronic Document Information System (EDIS) and the public docket.

US Eyes Future of Phosphate Fertilizer Trade with Morocco and Russia

Overview

Phosphate fertilizers are a cornerstone of modern agriculture, supplying essential nutrients that enable high crop yields worldwide. In 2021, the U.S. Department of Commerce imposed countervailing duty (CVD) orders on imports of these fertilizers from Morocco and Russia, citing unfair subsidies that harmed U.S. producers. The International Trade Commission (ITC) has now opened a five‑year review of those orders to determine whether lifting the duties would likely lead to continued or new material injury to the domestic industry.

The ITC’s review is guided by the Tariff Act of 1930 and will assess market conditions, import volumes, price effects, and the overall health of U.S. phosphate fertilizer production. Stakeholders—including U.S. producers, importers, trade associations, and labor groups—are invited to submit detailed data and analyses by April 1, 2026. The Commission will decide whether to conduct an expedited or full review based on the adequacy of the information received.

If the ITC finds that revoking the CVD orders would not harm U.S. producers, the duties could be lifted, potentially lowering fertilizer costs for American farmers and altering global trade flows. Conversely, a finding of likely injury would support keeping the duties in place, preserving a protective shield for domestic producers but maintaining higher prices for U.S. growers.

Key Elements

• Scope of Review: Five‑year assessment of countervailing duty orders on phosphate fertilizers from Morocco and Russia.
  
• Legal Basis: Conducted under the Tariff Act of 1930, section 751©.
  
• Stakeholder Participation: U.S. producers, importers, unions, trade associations, and foreign exporters are eligible to file responses.
  
• Response Deadline: April 1, 2026 (5:15 p.m. local time).
  
• Information Required:
  
  • Production, capacity, and financial data for U.S. phosphate fertilizer producers (2025 figures).
    
  • Import volumes, values, and market share for U.S. importers of Moroccan and Russian fertilizers.
    
  • Export data for foreign producers in the two countries.
    
  • Analysis of supply‑side changes (technology, capacity) and demand‑side shifts (substitutes, end‑use markets).
    
  • Assessment of potential price and market impact if duties were revoked.
    
• Confidentiality: Business proprietary information may be protected under an administrative protective order; authorized parties can access it through the ITC’s electronic docket.
  
• Review Types: The Commission may conduct an expedited review (based on available data) or a full review (requiring more extensive evidence).
  
• Public Comment: Comments on the adequacy of responses are due by May 8, 2026.
  
• Potential Outcomes:
  
  • Revocation of CVD orders, leading to lower fertilizer costs for U.S. farmers.
    
  • Continuation of duties, maintaining a protective tariff for domestic producers.
    
• Implications for Geoscience & Natural Resources: The decision will influence the supply chain of a critical mineral commodity, affect agricultural land use, and shape future trade policies in the broader mineral and energy sectors.

Silicon Metal Trade Review: U.S. Eyes Bosnia, Iceland, Kazakhstan, and Malaysia

Overview

The U.S. International Trade Commission (ITC) has opened a five‑year review of the countervailing duty order on silicon metal from Kazakhstan and antidumping duty orders on silicon metal from Bosnia and Herzegovina, Iceland, and Malaysia. The review, announced in the Federal Register on March 2, 2026, seeks to determine whether revoking these duties would likely lead to continued or new material injury to the U.S. domestic silicon metal industry within a foreseeable future.

Silicon metal is a critical raw material for electronics, solar‑panel manufacturing, and advanced alloys. The ITC’s assessment will consider changes in supply and demand, technological advances, and market conditions that could affect the availability and price of silicon metal. Stakeholders—including producers, importers, and industry associations—are invited to submit data and comments by April 1, 2026, with a final comment deadline of May 8, 2026.

The outcome of this review could reshape U.S. trade policy on a key mineral resource, influencing domestic production capacity, supply‑chain resilience, and the competitiveness of U.S. technology sectors that rely on high‑purity silicon.

Key Elements

• Legal Basis: Five‑year review under the Tariff Act of 1930 (section 751©).
  
• Orders Reviewed:
  
  • Countervailing duty on silicon metal from Kazakhstan (effective April 19, 2021).
    
  • Antidumping duties on silicon metal from Bosnia and Herzegovina, Iceland, and Malaysia (effective August 19, 2021).
    
• Purpose: Evaluate whether revoking these duties would cause material injury to the U.S. domestic silicon metal industry.
  
• Stakeholder Participation:
  
  • Domestic producers, importers, unions, trade associations, and foreign producers may file responses.
    
  • Participation requires filing an entry of appearance within 21 days of publication.
    
• Data Requested: Production volumes, capacity, sales, costs, import/export figures, price information, and supply‑chain dynamics for 2025.
  
• Timeline:
  
  • Responses due April 1, 2026.
    
  • Comments on adequacy of responses due May 8, 2026.
    
• Implications for Geoscience & Natural Resources:
  
  • Silicon metal is derived from mined silicon dioxide; changes in trade policy affect mining, refining, and downstream manufacturing.
    
  • The review may influence investment in domestic silicon production and the development of alternative materials.
    
• Public Access: All filings and the public service list are available through the ITC’s Electronic Document Information System (EDIS).
  

This review offers a critical opportunity for stakeholders in the silicon supply chain to shape U.S. trade policy on a material that underpins modern electronics, renewable energy, and advanced manufacturing.

Re‑imagining Shooting Grounds: BLM Seeks Public Input on Target‑Shooting Plans for the Sonoran Desert National Monument

Overview

The Bureau of Land Management (BLM) has announced its intent to amend the Resource Management Plan (RMP) for the Sonoran Desert National Monument (SDNM) and prepare an associated Environmental Assessment (EA). The focus is on recreational target shooting—an activity that currently occupies about 5,300 acres of the monument while the remaining 480,000 acres prohibit such use. The amendment will evaluate whether to expand, reduce, or otherwise modify these shooting allocations, guided by the 2012 SDNM Record of Decision and the 2024 RMP amendment.

The planning process will consider four key issues: potential impacts on monument objects, the effectiveness of existing mitigation and monitoring protocols, public health and safety, and overall availability of shooting sites. The BLM will integrate NEPA requirements, the Endangered Species Act, and the National Historic Preservation Act, ensuring that cultural resources, wildlife, and endangered species are protected throughout the analysis.

Public participation is central to this effort. A 30‑day scoping period ends on March 30, 2026, during which stakeholders—including federal, state, local agencies, tribal nations, and the general public—can submit comments on the scope, alternatives, and planning criteria. The BLM will use an interdisciplinary team to assess the environmental, cultural, and recreational implications of any proposed changes.

Key Elements

• Scope of the Amendment

  • Adjusts the distribution of recreational target shooting areas within the SDNM.
    
  • Current status: ~5,300 acres allowed, ~480,500 acres prohibited.

• Planning Criteria & Issues

  • Impacts on monument objects (e.g., archaeological sites, natural features).
    
  • Effectiveness of mitigation/monitoring protocols.
    
  • Public health and safety considerations.
    
  • Availability and accessibility of shooting sites.

• Regulatory Framework

  • NEPA (Environmental Assessment).
    
  • Endangered Species Act compliance.
    
  • National Historic Preservation Act (Section 106) and tribal consultation under Executive Order 13175.
    
  • Dingell Act and EXPLORE Act provisions for recreational shooting closures.

• Alternatives Considered

  • No Action: Maintain the 2024 RMP status.
    
  • Expanded Shooting Areas: Increase acreage with enhanced monitoring.
    
  • Reduced or Re‑located Areas: Limit shooting to minimize impacts.

• Public Engagement

  • Comment period: until March 30, 2026.
    
  • Submission methods: online portal, email, or mail.
    
  • No public meetings scheduled during the scoping period; future meetings would be announced in advance.

• Interdisciplinary Team

  • Specialists in recreation management, wildlife, vegetation, cultural resources, socioeconomics, GIS, and environmental coordination.

• Stakeholder Collaboration

  • Coordination with federal, state, local agencies, tribal nations, and other interested parties.
    
  • Opportunity for agencies to participate as cooperating entities in the environmental analysis.

• Compliance and Coordination

  • Alignment with the 2012 SDNM Record of Decision and the 2024 RMP amendment.
    
  • Integration of land‑use planning and NEPA processes to meet statutory and regulatory requirements.

US Launches Trade Probe into Chinese and Indian Graphite Electrodes

Overview

Large‑diameter graphite electrodes—key components in steelmaking, aluminum smelting, and high‑performance batteries—have been imported into the United States from China and India at prices that some U.S. manufacturers claim are below fair value. On February 27, 2026, the International Trade Commission (ITC) announced it would begin preliminary antidumping and countervailing duty investigations (Nos. 701‑TA‑787‑788 and 731‑TA‑1775‑1776) to determine whether these imports are harming U.S. industry or hindering its development.

The investigations are triggered by petitions from U.S. firms Resonac Graphite America Inc. and Tokai Carbon GE LLC, which argue that the imported electrodes are subsidized by their governments and sold at unfairly low prices. If the ITC finds evidence of dumping or subsidies, it could impose duties that raise the cost of these electrodes for U.S. users, potentially affecting downstream industries such as steel production, aluminum manufacturing, and battery production.

The ITC’s notice sets a tight timetable: a preliminary determination must be made within 45 days (by April 10, 2026), with the Commission’s findings reported to the Department of Commerce by April 17, 2026. The notice also invites interested parties—including manufacturers, consumers, and trade associations—to participate, file evidence, and attend a staff conference in March.

Key Elements

• Investigation Numbers: 701‑TA‑787‑788 and 731‑TA‑1775‑1776 (preliminary).
  
• Petitioners: Resonac Graphite America Inc. (SC) and Tokai Carbon GE LLC (NC).
  
• Deadlines:
  
  • Preliminary determination by April 10, 2026.
    
  • Report to Commerce by April 17, 2026.
    
• Participation:
  
  • Parties may file an entry of appearance within 7 days of notice publication.
    
  • Industrial users and consumer groups can join as parties.
    
• Business Proprietary Information (BPI): Protected under an Administrative Protective Order; authorized parties can access BPI through the ITC’s Electronic Document Information System (EDIS).
  
• Conference: Staff conference on March 17, 2026 (9:30 a.m.); requests to attend must be emailed by March 13, 2026.
  
• Written Submissions:
  
  • Briefs due by March 20, 2026, 5:15 p.m.
    
  • Conference testimony and supplementary material due by March 16, 2026, 4:00 p.m.
    
• Certification Requirement: All submissions must be certified accurate and complete; BPI may be disclosed to ITC staff and U.S. government personnel for cybersecurity purposes.
  
• Contact: Camille Bryan, Office of Investigations, U.S. ITC, 500 E Street SW, Washington, DC 20436 (phone 202‑205‑2811).
  

These provisions outline the procedural framework for the investigation and provide a roadmap for stakeholders to engage with the process and understand how the outcome could shape the U.S. graphite electrode market and related industries.

EPA Opens the Books on Federal Environmental Impact Studies

The Environmental Protection Agency (EPA) has issued a notice announcing the availability of its comments on several recently completed Environmental Impact Statements (EISs) prepared by other federal agencies. Under Section 309(a) of the Clean Air Act, EPA is required to review and publicly comment on EISs that may affect air quality. The notice lists three specific projects: a draft supplement for U.S. military training and testing in the Mariana Islands, a final EIS for the expansion of a lithium‑mining operation in Nevada, and a final EIS for a transmission‑line upgrade in Nevada. Each comment period has a defined deadline, and the EPA has provided contact information for further inquiries.

This announcement underscores the EPA’s role in ensuring that large‑scale energy, mineral‑resource, and infrastructure projects meet environmental and air‑quality standards. By making its comments publicly available, the agency promotes transparency and allows stakeholders—including scientists, industry, and local communities—to review EPA’s assessments and recommendations. The notice also serves as a reminder that federal agencies must consider EPA’s input when finalizing project plans that could impact air quality and related environmental factors.

Key Elements

• EPA’s Review Requirement: EPA must comment on all EISs that could affect air quality under the Clean Air Act.
• Projects Covered:
  • EIS 20260016: Draft supplement for U.S. Air Force, Coast Guard, Navy, and Marine Corps training/testing in the Mariana Islands.
  • EIS 20260017: Final EIS for the Silver Peak Lithium Operation Expansion Project (BLM, Nevada).
  • EIS 20260018: Final EIS for the GridLiance West Core Upgrades Transmission Project (BLM, Nevada).
• Comment Periods:
  • Draft supplement: comments due by May 1, 2026.
  • Final EIS for lithium mining: review period ends March 30, 2026.
  • Final EIS for transmission upgrades: review period ends March 30, 2026.
• Contact Information:
  • Brian Whitehouse (USAF EIS) – 808‑471‑4696
  • Scott Distel (Silver Peak Lithium) – 775‑861‑6476
  • Whitney Wirthlin (GridLiance) – 702‑515‑5117
• Legal Framework: The notice references CEQ guidance on 42 U.S.C. 4332 and the EPA’s obligation under Clean Air Act Section 309(a).
• Transparency: EPA’s comments are posted on its public EIS portal, enabling stakeholders to access the agency’s analysis and recommendations.

California Offshore Oil & Gas Lease Sales: A Call for Public Input on a New Environmental Study

Overview
The Bureau of Ocean Energy Management (BOEM) has announced its intent to prepare a Programmatic Environmental Impact Statement (PEIS) for proposed oil and gas lease sales in the Northern, Central, and Southern California Program Areas. This action is part of the 11th National Outer Continental Shelf (OCS) Oil and Gas Leasing Program, which seeks to open up roughly 26.2 million hectares of Pacific Ocean off California for exploration and development. The PEIS will evaluate the environmental, economic, and cultural impacts of leasing these blocks and will inform future lease‑sale decisions.

The notice invites comments from federal, state, tribal, local governments and the public until March 30, 2026. BOEM will use the scoping period to identify significant issues, potential alternatives, and mitigation measures. The study will consider three alternatives: (A) a full lease sale of all available blocks, (B) a no‑action alternative, and © a lease sale limited to areas adjacent to existing offshore infrastructure. The PEIS will also trigger Section 106 historic‑preservation consultations and may lead to a final Environmental Impact Statement if leases move to development.

Key Elements
- Purpose: Provide access to potentially recoverable oil and gas resources on the Outer Continental Shelf, supporting national energy goals under Executive Orders 14154 and 14156.
- Scope: Covers 11,876 lease blocks across Northern, Central, and Southern California, totaling ~65 million acres.
- Alternatives:
- Alternative A: Full lease sale of all blocks.
- Alternative B: No action (cancel the sale).
- Alternative C: Lease sale limited to areas near existing infrastructure to reduce new construction.
- Potential Impacts: Air and water quality, benthic communities, fish and marine mammals, coastal habitats, cultural and historic resources, and socioeconomic factors.
- Comment Process: 30‑day scoping period (until March 30, 2026) via Regulations.gov; public comments will shape the PEIS content.
- Cooperating Agencies: BOEM invites federal, state, tribal, and local agencies with jurisdiction or expertise to participate in the NEPA process.
- Timeline: PEIS preparation will precede any lease sale; a Record of Decision and final sale notice will follow if the Secretary authorizes a sale.
- Contact: Susan Zaleski, Acting Regional Supervisor, BOEM Pacific OCS Region (805) 384‑6328 or susan.zaleski@boem.gov.

Winter Storms Hit Washington’s San Juan County: SBA Expands Disaster Aid

Overview

On February 25, 2026 the U.S. Small Business Administration (SBA) issued an amendment to its earlier administrative declaration of disaster for the State of Washington. The amendment extends the disaster’s geographic scope to include San Juan County, recognizing the severe winter storms that struck the region from December 5 to December 25, 2025. The update preserves all other terms of the original declaration, such as loan deadlines and eligibility criteria, while adding the new county to the list of affected areas.

The amendment underscores the SBA’s role in providing rapid financial relief to businesses that suffered physical damage or economic injury during the storm. It also highlights the importance of timely application windows—physical loan applications must be submitted by April 27, 2026, and economic injury disaster loans by November 24, 2026. The notice directs applicants to the SBA’s MySBA Loan Portal for assistance.

For geoscientists, energy, and natural‑resource professionals, the expanded declaration signals that the winter storms had significant impacts on infrastructure, supply chains, and local economies in San Juan County. It also illustrates how federal disaster policy can influence regional recovery efforts and resource management strategies.

Key Elements

• Geographic Expansion: San Juan County, Washington, added to the list of adversely affected areas.
  
• Incident Period: December 5–25, 2025, severe winter storms.
  
• Loan Application Deadlines:
  
  • Physical damage loans: April 27, 2026.
    
  • Economic injury disaster loans: November 24, 2026.
    
• Application Portal: MySBA Loan Portal (https://lending.sba.gov).
  
• Authority: 13 CFR 123(b); Catalog of Federal Domestic Assistance No. 59008.
  
• Contact: Jennifer Talarico, Office of Disaster Recovery and Resilience, SBA.
  
• Implications for Natural Resources: Potential disruptions to local fisheries, forestry, and energy supply chains; need for coordinated recovery and resilience planning.

Washington Faces Winter Storm Disaster: SBA Declares Emergency, Opens Loan Window

Overview
On February 24 2026 the U.S. Small Business Administration (SBA) issued an administrative declaration of disaster for the state of Washington, citing the severe winter storms that struck the region from December 5 to December 22, 2025. The declaration formally recognizes the widespread damage to infrastructure, homes, businesses, and agricultural operations caused by heavy snowfall, ice, and flooding. It also authorizes federal assistance to help affected entities recover and rebuild.

The notice outlines the practical steps for those impacted: businesses, homeowners, and non‑profits can apply for disaster assistance loans through the MySBA Loan Portal, with a physical‑damage loan deadline of April 27 2026 and an economic‑injury loan deadline of November 24 2026. Interest rates vary by credit availability and loan type, ranging from 2.875 % for homeowners without alternative credit to 8.000 % for businesses with credit elsewhere. The declaration lists primary counties—King, Lewis, Skagit, Snohomish, Whatcom—and contiguous counties that are considered adversely affected.

For geoscientists, energy planners, and natural‑resource professionals, the declaration signals a significant weather‑related event that has implications for water resources, coastal erosion, and regional infrastructure resilience. The federal response provides a framework for funding repairs to critical facilities, restoring power grids, and supporting local economies that depend on agriculture, forestry, and tourism.

Key Elements

• Declaration Authority: SBA Administrative Declaration #21450 and #21451 (Washington Disaster Number WA‑20025).
  
• Incident Period: December 5–22, 2025 (severe winter storms).
  
• Affected Areas: Primary counties—King, Lewis, Skagit, Snohomish, Whatcom; contiguous counties—Chelan, Cowlitz, Grays Harbor, Island, Kitsap, Kittitas, Okanogan, Pacific, Pierce, Skamania, Thurston, Wahkiakum, Yakima.
  
• Loan Application Deadlines
  
  • Physical Damage Loans: April 27 2026
    
  • Economic Injury Loans: November 24 2026
    
• Interest Rates
  
  • Physical Damage
    
  • Homeowners (credit elsewhere): 5.750 %
    
  • Homeowners (no credit elsewhere): 2.875 %
    
  • Businesses (credit elsewhere): 8.000 %
    
  • Businesses (no credit elsewhere): 4.000 %
    
  • Non‑profits (credit elsewhere or not): 3.625 %
    
  • Economic Injury
    
  • Businesses & small agricultural cooperatives (no credit elsewhere): 4.000 %
    
  • Non‑profits (no credit elsewhere): 3.625 %
    
• Application Portal: https://lending.sba.gov
  
• Contact Information: Sharon Henderson, Office of Disaster Recovery & Resilience, 409 3rd St SW, Suite 6050, Washington, DC 20416; phone (202) 205‑6734; email disastercustomerservice@sba.gov.
  
• Implications for Geoscience & Natural Resources
  
  • Assessment of storm‑induced damage to water infrastructure and coastal systems.
    
  • Funding opportunities for restoring critical energy and transportation networks.
    
  • Support for agricultural recovery and forest management in affected counties.

Wyoming Gets Green Light for Coal Ash Management Program

Overview

The U.S. Environmental Protection Agency (EPA) has approved Wyoming’s partial coal combustion residuals (CCR) permit program, allowing the state to regulate the disposal of coal‑burning waste—such as fly ash, bottom ash, and flue‑gas desulfurization materials—through its own permitting system. The approval means that, for the units covered by the state program, Wyoming’s regulations will replace the federal CCR rules, while the remaining federal requirements will continue to apply to any units not covered by the state program.

The decision follows a thorough review of Wyoming’s permitting framework, public‑participation procedures, monitoring and enforcement authority, and technical criteria. EPA found that the state’s rules are at least as protective as the federal standards, and that the state has the necessary staff, funding, and legal authority to administer the program. The approval also acknowledges that the state’s program is “partial,” so federal regulations will still govern any CCR units for which Wyoming has not sought or received approval.

For coal‑fueling utilities and other operators in Wyoming, the new program will streamline permitting, provide clearer guidance on groundwater monitoring and closure requirements, and give the public a defined avenue to comment on and challenge permit decisions. EPA will review the program at least every 12 years, or sooner if significant releases occur, ensuring ongoing protection of human health and the environment.

Key Elements

• State‑Led Permitting: Wyoming’s Department of Environmental Quality (WDEQ) will issue permits for CCR units, replacing the federal CCR permitting process for approved units.
  
• Compliance Monitoring: WDEQ has authority to conduct inspections, collect monitoring data, and enforce compliance with both state and federal requirements.
  
• Public Participation: The program requires two 30‑day public comment periods, newspaper notices, and the option for public hearings, ensuring transparency and community input.
  
• Groundwater Protection: State regulations incorporate federal groundwater monitoring and corrective‑action standards, with additional state‑specific provisions deemed at least as protective.
  
• Enforcement Authority: WDEQ can issue cease‑and‑desist orders, pursue civil penalties, and, if necessary, intervene in federal enforcement actions.
  
• Partial Approval: Only the provisions approved by EPA will replace federal rules; all other federal CCR requirements remain enforceable for Wyoming units.
  
• Program Review: EPA will review the state program no less frequently than every 12 years, or sooner after significant releases or regulatory changes.
  
• Funding and Staffing: WDEQ has secured state budget support and federal grant funding to administer the program, ensuring adequate resources for permitting and enforcement.
  
• Legal Authority: The program is authorized under the Resource Conservation and Recovery Act (RCRA) and Wyoming’s Environmental Quality Act, giving the state the statutory basis to regulate CCR units.

U.S. Keeps Import Tariffs on Chinese Electrolytic Manganese Dioxide to Protect Domestic Industry

Overview

Electrolytic manganese dioxide (EMD) is a key component in batteries, pigments, and industrial catalysts. In 2008 the U.S. Commerce Department first imposed an antidumping duty (AD) order on EMD imported from China, citing that Chinese producers were selling below fair value and harming U.S. manufacturers. After a series of five‑year “sunset” reviews, the International Trade Commission (ITC) concluded in February 2026 that revoking the order would likely lead to continued dumping and material injury to the U.S. industry. Consequently, the Department of Commerce has extended the AD order through a formal notice, maintaining the tariff and cash‑deposit requirements for all future imports.

The continuation means that U.S. customs will continue to collect AD cash deposits at the rates in effect at the time of entry, and the order remains in force until the next scheduled review. The decision reflects ongoing concerns about market distortion and the need to safeguard domestic production of EMD, which is critical for the growing battery and renewable‑energy sectors. The order also underscores the U.S. commitment to enforce trade rules when domestic industries face unfair competition.

For stakeholders—manufacturers, suppliers, and researchers—this means that the tariff environment for EMD remains unchanged, potentially affecting supply chain costs, pricing, and investment decisions. The notice also reminds parties involved in the proceeding to comply with protective‑order requirements regarding proprietary information.

Key Elements

• Scope of the Order

  • Covers all EMD produced by electrolysis (powder, chip, or plate).
    
  • Excludes natural manganese dioxide (NMD) and chemical manganese dioxide (CMD).
    
  • Classified under HTSUS subheading 2820.10.00.00.

• Tariff and Deposit Requirements

  • U.S. Customs will continue to collect AD cash deposits at current rates for all imports of covered merchandise.
    
  • The order remains effective from February 23, 2026, until the next review.

• Review Process

  • The order is subject to a five‑year sunset review; the next review will be initiated no later than 30 days before the fifth anniversary of the last ITC determination.
    
  • The ITC’s February 2026 determination found that revocation would likely cause material injury to U.S. industry.

• Administrative Protective Order (APO)

  • Parties must return or destroy proprietary information disclosed under the APO in accordance with 19 CFR 351.305(a)(3).
    
  • Failure to comply can result in sanctions.

• Implications for Trade and Industry

  • Maintains tariff protection for U.S. EMD producers, potentially influencing pricing and supply chain dynamics.
    
  • Signals ongoing U.S. enforcement of trade rules against perceived dumping practices.

NOAA Opens Doors to the Deep: Upcoming Ocean Exploration Advisory Board Meeting

Overview

The National Oceanic and Atmospheric Administration (NOAA) has announced a two‑day, fully virtual meeting of its Ocean Exploration Advisory Board (OEAB) on March 18–19, 2026. The OEAB is a federal advisory committee that guides NOAA on strategic priorities for ocean, marine, and Great Lakes science, including exploration, discovery, and the development of new technologies. The meeting will provide board members with agency updates, allow them to discuss recommendations, and set the agenda for the next five years of ocean research.

The public will have the opportunity to submit comments during a designated 3‑minute window on March 18 at 3:35 p.m. Central Standard Time. Attendance and comment submission require advance registration through a Google Form. The session will be recorded for minutes and is accessible to people with disabilities via Webex closed captioning. NOAA encourages stakeholders—researchers, industry partners, and citizen scientists—to participate and shape the future of ocean exploration.

This notice underscores NOAA’s commitment to transparency and collaboration. By inviting public input and highlighting key topics such as market barriers to new ocean technologies, data management best practices, and extramural partnerships, the agency aims to foster innovation and ensure that ocean science remains responsive to societal needs and environmental stewardship.

Key Elements

• Meeting Dates & Times – March 18, 2026 (9 a.m.–4 p.m. CDT) and March 19, 2026 (9 a.m.–4 p.m. CDT).
  
• Format – Fully online via Webex; no in‑person attendance.
  
• Public Comment – 3‑minute window on March 18 at 3:35 p.m. CST; registration required.
  
• Agenda Topics –
  
  • Prioritizing ocean survey and discovery initiatives.
    
  • Developing a 5‑year strategic plan for ocean, marine, and Great Lakes science.
    
  • Improving the proposal review process and addressing market barriers to commercialization of ocean mapping tools.
    
  • Enhancing data management, processing, storage, and archiving standards.
    
• Accessibility – Closed captioning available; additional accommodations requested via email.
  
• Contact Information – Liz Tirpak or Gretchen Spencer (oceanexplorer@noaa.gov; 301‑734‑1226).
  
• Registration Link – https://forms.gle/2DkS5SMHJsAH3Rjy9
  
• Website for Materials – https://oeab.noaa.gov/meetings/2026-oeab-meetings/
  
• Purpose – To advise NOAA leadership on strategic priorities, foster extramural collaboration, and improve the effectiveness of ocean exploration programs.

Golden Triangle Storage Seeks FERC Approval for New Natural Gas Pipeline to Texas Hydrogen Facility

Overview

Golden Triangle Storage, LLC (GTS) has filed a request with the Federal Energy Regulatory Commission (FERC) to construct a new natural‑gas pipeline lateral that will connect its storage facility to Linde Inc.’s hydrogen production plant in Jefferson County, Texas. The proposed 12‑inch, two‑mile pipeline would deliver 125 million cubic feet per day of firm wheeling service, expanding the capacity of the existing Houston Pipeline Company meter station and adding a new interconnect and meter site at Linde’s facility. The project is estimated to cost roughly $27 million and does not alter the parameters of GTS’s already‑certified storage operations.

The request is made under FERC’s blanket authorization framework, which allows certain routine infrastructure upgrades to be approved more quickly than a full, individual application. GTS’s blanket certificate (Docket CP07‑415‑000) covers a range of future projects, and this interconnection is one of those covered activities. The Commission has published the notice in the Federal Register and opened a public comment period, setting a firm deadline of 5:00 p.m. Eastern Time on April 24, 2026 for protests, motions to intervene, and comments.

For stakeholders—including local residents, ratepayers, environmental groups, and industry participants—this notice signals an upcoming decision that could affect regional energy supply, land use, and environmental impacts. The public has the opportunity to influence the outcome through formal protests or interventions, and the Commission will consider all submissions before determining whether to grant the requested authorization.

Key Elements

• Project Scope: 2‑mile, 12‑inch natural‑gas pipeline lateral; new interconnect and meter at Linde’s hydrogen facility; capacity increase at Houston Pipeline Company meter station.
  
• Purpose: Provide 125 million cf/d of firm wheeling service to support hydrogen production and regional gas distribution.
  
• Cost & Funding: Estimated $27 million, details available in the filed request.
  
• Regulatory Path: Filed under FERC’s blanket authorization (Docket CP07‑415‑000); no change to existing storage facility parameters.
  
• Public Participation:
  
  • Protest deadline: 5:00 p.m. ET, April 24, 2026.
    
  • Motion to intervene deadline: same date.
    
  • Comments deadline: same date.
    
  • Filing methods: electronic eFiling or paper mail; no fee.
    
• Implications for Geoscience & Natural Resources:
  
  • Potential impacts on local groundwater and surface water due to pipeline construction.
    
  • Interaction with existing natural‑gas infrastructure and potential for increased gas transport efficiency.
    
  • Opportunity for stakeholders to raise environmental and land‑use concerns before final approval.
    
• Contact & Resources:
  
  • FERC Office of Public Participation (OPP) for filing assistance.
    
  • eLibrary and eSubscription services for tracking docket updates.
    
  • Legal representation details provided for protest and intervention filings.

Southern Star Pipeline Plans 5.5‑Mile Abandonment: Public Comment Deadline Set

Overview

The Federal Energy Regulatory Commission (FERC) has published a notice regarding Southern Star Central Gas Pipeline, Inc.’s request to abandon approximately 5.5 miles of its 16‑inch‑diameter pipeline in Johnson County, Kentucky, and to replace a short segment of 4‑inch pipe. The company cites the need to maintain the integrity and safety of the network while ensuring reliable service to its customers. The proposed work, estimated at $2.5 million, will also involve removing associated above‑ground appurtenances.

The notice invites public participation through protests, motions to intervene, and comments. Interested parties have until 5:00 p.m. Eastern Time on April 24, 2026, to file. Protests and interventions are governed by FERC’s Natural Gas Act regulations, and any protest that is not withdrawn within 30 days will be considered by the Commission. Intervenors gain the right to request rehearings and to challenge orders in court.

FERC encourages electronic filing via its eFiling system but also accepts paper submissions. All filings must reference docket number CP26‑90‑000. The Commission will review the request and any submissions before making a decision, with the public able to track the proceeding through FERC’s eLibrary and eSubscription services.

Key Elements

• Project scope: Abandonment of ~5.5 mi of 16‑inch pipeline; removal of above‑ground appurtenances; replacement of ~0.063 mi of 4‑inch pipe.
  
• Location: Johnson County, Kentucky (Line XQ Abandonment Project).
  
• Estimated cost: $2.5 million.
  
• Purpose: Maintain pipeline integrity, safety, and service reliability.
  
• Public participation deadline: 5:00 p.m. ET, April 24, 2026.
  
• Protest rules: Must be filed by deadline; if not withdrawn within 30 days, the Commission will consider the request.
  
• Intervention rules: Motion to intervene must be filed by the same deadline; successful intervenors gain rights to rehearings and court challenges.
  
• Comment submission: Allowed but does not confer party status; must be filed by deadline.
  
• Filing methods: eFiling (eRegister → General → Protest/Intervention/Comment) or paper mail to FERC’s Secretary.
  
• Contact information: Southern Star’s regulatory manager, Jennifer Matthews (phone 270‑316‑2972, email jennifer.matthews@southernstar.com).
  
• Tracking the proceeding: Use FERC’s eLibrary and eSubscription services for updates and documents.

Surrendering a Colorado Hydroelectric Plant: Public Call for Comments on Decommissioning and Restoration

Overview

The Federal Energy Regulatory Commission (FERC) has announced that the Public Service Company of Colorado intends to surrender its operating license for the Salida Hydro Nos. 1 & 2 project. Located on the South Arkansas River and Fooses Creek in Chaffee County, the plant sits partly on U.S. Forest Service land within the Pike‑San Isabel National Forests. The surrender will trigger the removal of key infrastructure—dam, forebay, penstock, powerhouse, and associated facilities—and the restoration of the river corridor to its natural state.

This notice invites federal, state, local, and tribal agencies, as well as the public, to submit comments, protests, or motions to intervene by March 25, 2026. The Commission emphasizes electronic filing but accepts paper submissions. Applicants must also secure a water‑quality certification under the Clean Water Act, and cooperating agencies are encouraged to assist in environmental documentation, though they cannot intervene in the proceeding.

The decommissioning reflects a broader trend toward retiring aging hydroelectric assets that no longer meet safety, environmental, or economic thresholds. By restoring the site, the company aims to mitigate ecological impacts, improve habitat connectivity, and comply with federal land‑management policies.

Key Elements

• License surrender and decommissioning of Salida Hydro Nos. 1 & 2, including removal of dam, forebay, penstock, powerhouse, and adjacent substation.
  
• Restoration of the river corridor on federal, state, and private lands to a natural or near‑natural condition.
  
• Water‑quality certification required under Section 401 of the Clean Water Act; submission deadline 60 days after notice.
  
• Public participation window: comments, protests, and motions to intervene due by March 25, 2026; electronic filing encouraged.
  
• Cooperation with environmental agencies (e.g., U.S. Forest Service, Colorado Water Quality Control Division) is invited, though cooperating agencies cannot intervene.
  
• Compliance with FERC rules on filing, service of documents, and evidentiary basis for interventions.
  
• Implications for geoscience and natural resources: the project’s removal will alter hydrologic regimes, sediment transport, and aquatic habitats, offering opportunities for ecological research and monitoring.
  
• Stakeholder engagement: the notice underscores the role of local communities, tribal nations, and conservation groups in shaping the restoration outcome.

National Park Service Keeps Mining & Oil‑Gas Reporting Requirements Under Review

Overview

The National Park Service (NPS) has issued a notice to renew an existing information‑collection program that requires operators of mining claims and non‑federal oil and gas rights within national park units to submit detailed reports. The renewal, authorized under the Paperwork Reduction Act of 1995, carries the same Office of Management and Budget (OMB) control number 1024‑0064 and is slated to remain in effect without substantive changes.

The program gathers data on claim ownership, operator plans, and mitigation measures intended to protect park resources and values. With an estimated 799 annual responses and a total burden of 3,473 hours (costing roughly $102,300), the collection is designed to balance regulatory oversight with a manageable reporting load for businesses.

Stakeholders—including geoscientists, mining and energy companies, and conservation groups—are invited to comment on the collection’s necessity, accuracy, and potential for improvement. Comments are due by March 30 2026 and can be submitted electronically or by mail to the NPS Information Collection Clearance Officer.

Key Elements

• Purpose: Collect data on mining and non‑federal oil‑gas activities in national parks to ensure compliance with conservation standards.
  
• Scope: Covers all mining claims and oil‑gas rights within National Park System units, requiring operators to detail access plans and mitigation measures.
  
• Respondents: Primarily businesses that hold or operate mining claims or oil‑gas rights; 799 expected annual submissions.
  
• Burden Estimate: 3,473 total annual hours, ranging from 1 to 140 hours per response; estimated cost $102,300.
  
• OMB Control Number: 1024‑0064 (valid for the current renewal).
  
• Comment Period: Open until March 30 2026; submissions accepted via Regulations.gov or by mail to the NPS Information Collection Clearance Officer.
  
• Contact: Stephen Simon, Policy and Regulatory Specialist, Energy and Minerals Branch, NPS; email Stephen_Simon@nps.gov.
  
• Legal Basis: Paperwork Reduction Act of 1995; authorized by the Mining in the Parks Act and codified in 36 CFR part 9 (subparts A and B).

U.S. Seeks Input on Building a Global Critical Mineral Trade Pact

Overview
The U.S. Trade Representative (USTR) has opened a 14‑day comment period to gather expert and stakeholder input on a proposed plurilateral agreement that would regulate trade in critical minerals—those essential for defense, advanced technology, and clean‑energy systems. The goal is to create a resilient, market‑based supply chain that reduces dependence on any single source and mitigates the risk of supply disruptions.

The notice invites comments on a wide range of policy tools, including minimum price mechanisms, tariff‑rate quotas, and investment‑screening commitments. It also seeks guidance on how to prioritize which minerals and trading partners should be included, how to set reference prices that reflect extraction and processing costs, and how to establish common standards to curb regulatory arbitrage and unfair trade practices.

By soliciting feedback from industry, academia, and the public, USTR hopes to design an agreement that balances national security interests with free‑market principles, encourages domestic production and recycling, and fosters cooperation among like‑minded partners.

Key Elements

• Plurilateral Agreement Framework – A legally binding pact among selected trading partners to coordinate trade rules for critical minerals.
  
• Price Mechanisms – Minimum or reference price systems, tariff‑rate quotas, and potential price‑undertakings to stabilize markets and support investment.
  
• Investment Incentives – Commitments on investment screening, transparency, and first‑refusal rights to protect critical‑mineral assets.
  
• Regulatory Standards – Common rules to address regulatory arbitrage and ensure fair competition across jurisdictions.
  
• Supply‑Chain Resilience – Measures to diversify sources, promote recycling, and prevent gray‑market flows.
  
• Coordination Mechanisms – Platforms for rapid response to market shocks, natural disasters, or geopolitical changes.
  
• Legal Authority – Exploration of how other countries can implement similar price or trade measures under the agreement.
  
• Prioritization Criteria – Guidance on selecting minerals and partners based on market dynamics, supply chain structure, and national security relevance.
  
• Transparency and Enforcement – Rules for monitoring compliance, addressing breaches, and ensuring benefits accrue to member parties.

Fusion’s First Regulatory Blueprint: NRC Sets the Stage for Safe, Scalable Fusion Energy

Overview

The U.S. Nuclear Regulatory Commission (NRC) has issued a proposed rule to extend its existing by‑product material framework to cover fusion machines—devices that generate energy by fusing atomic nuclei. The rule, published in the Federal Register on February 26 2026, aims to provide a technology‑inclusive, risk‑informed licensing pathway that accommodates the diverse range of fusion designs currently under development. By treating fusion‑generated radioactive material as by‑product material, the NRC leverages well‑established regulations for particle accelerators while tailoring requirements to the unique radiological, safety, and environmental characteristics of fusion devices.

The rule is accompanied by draft guidance (NUREG‑1556, Volume 22) that outlines application content, training, emergency planning, and waste‑management procedures specific to fusion machines. The NRC invites public comment until May 27 2026 and will hold at least one public meeting to explain the proposal and gather stakeholder input. The regulatory framework is designed to streamline licensing, reduce uncertainty for developers, and ensure that fusion facilities meet the same high standards of radiation protection, security, and environmental stewardship that govern other nuclear facilities.

Key Elements

• Scope & Definitions

  • New definition of fusion machine added to 10 CFR parts 20, 30, 37, 50, 72, 110, 150, 170, 171.
  • Fusion‑generated radioactive material is explicitly classified as by‑product material under the Atomic Energy Act (AEA) and the ADVANCE Act of 2024.
  • Fusion machines are treated as a subset of particle accelerators for regulatory purposes.

• Licensing Requirements

  • Applications must include a detailed description of the fusion machine, radiation‑safety measures, training, inspection, and inventory‑control plans (new § 30.32(k)).
  • Licensees must demonstrate adequate training, safety, and decommissioning plans (new § 30.33(a)(6)).
  • No new annual fees are proposed; existing fee structures remain unchanged.

• Environmental & Waste Management

  • An environmental report is required for construction and operation unless a categorical exclusion applies (new § 51.60(b)(1)(viii)).
  • Fusion‑generated waste may be disposed of at low‑level waste (LLW) facilities if it meets classification criteria or at sites that have completed a site‑specific intrusion assessment (amended § 20.2008(a)).
  • Recordkeeping and inspection requirements expanded to cover production of tritium and activation products (amended §§ 30.51, 30.52).

• Safety, Security, and Emergency Preparedness

  • Radiation‑protection standards from 10 CFR part 20 apply; additional security measures may be required for activation products not listed in Appendix A (§ 37.5).
  • Emergency plans must be developed if off‑site dose could exceed 1 rem (10 mSv) (§ 30.32(k)(2)(i)).
  • Physical‑protection requirements are consistent with existing by‑product material rules, with flexibility for fusion‑specific hazards.

• Cost‑Benefit Analysis

  • Estimated net benefit of ~$1.38 million, with a >99 % probability of a positive net benefit.
  • Anticipated cost savings for fusion developers due to clearer, technology‑inclusive regulations.
  • NRC and Agreement States expect reduced licensing effort and improved public confidence.

• Stakeholder Engagement

  • Draft guidance (NUREG‑1556, Vol 22) is open for comment; public meetings and a comment period through May 27 2026.
  • The rule is coordinated with Agreement States, ensuring compatibility across federal and state regulatory frameworks.

This proposed rule marks the first formal regulatory step toward commercial fusion energy in the United States, setting a clear, science‑based pathway for developers while safeguarding public health, safety, and the environment.

Sanctions Renewed: EU Targets Belarusian Power Players and Resource Firms

Overview

The European Union has extended its restrictive measures against Belarus until 28 February 2027, reaffirming its stance on the country’s role in the Russian invasion of Ukraine and its domestic repression. The new regulation amends the existing list of sanctioned individuals and entities, adding 54 new natural persons and 7 legal entities that are linked to human‑rights abuses, political repression, or the Belarusian regime’s support of Russian military actions. The list now includes high‑ranking officials, security‑force commanders, judges, and business leaders who have benefited from state contracts and have been implicated in the suppression of dissent.

The regulation also broadens the scope to cover companies involved in the military‑industrial complex and natural‑resource extraction. Firms such as Belshina (tyre manufacturing), Belaruskali (potash production), Grodno Azot (nitrogen compounds), and several defense contractors (AGAT, MZKT, 140 Repair Plant) are now subject to asset freezes and travel bans. These entities are singled out for their role in supplying equipment to the Russian military, supporting the Belarusian regime’s economic interests, and for the mistreatment of workers who protested against the government.

By tightening sanctions, the EU aims to pressure the Lukashenko administration to halt its repressive policies, curb its support for Russian aggression, and restore respect for human rights and the rule of law. The regulation is immediately binding across all Member States and will be monitored for compliance and effectiveness.

Key Elements

• Renewal of sanctions: The restrictive measures remain in force until 28 Feb 2027, with no changes to the core framework.
  
• Expanded list of individuals: 54 new natural persons, including former ministers, security chiefs, and judges, are added for their involvement in political repression and human‑rights violations.
  
• New legal entities: 7 companies—Beltechexport, AGAT, 140 Repair Plant, MZKT, Grodno Azot, Belshina, and Belaruskali—are sanctioned for supplying military equipment, supporting the regime’s economy, and violating workers’ rights.
  
• Geoscience and resource focus: The regulation targets major mining and chemical firms (Belaruskali, Grodno Azot) that are key to Belarus’s export revenue and have links to the Russian war effort.
  
• Military‑industrial coverage: Defense contractors (AGAT, MZKT, 140 Repair Plant) are listed for producing riot‑control gear and armored vehicles used against peaceful protests.
  
• Human‑rights emphasis: The list includes judges and prosecutors who have imposed politically motivated sentences, as well as prison officials responsible for torture and inhumane conditions.
  
• Binding and immediate effect: The regulation is directly applicable in all Member States, with enforcement mechanisms to ensure compliance.
  
• Monitoring and review: The EU will assess the impact of the sanctions and may adjust the list in future decisions.

EU Extends Sanctions on Belarus, Targeting Key Figures and Resource Companies Amid Ongoing Conflict

Overview

The European Council has adopted Decision ²⁰²⁶⁄₄₂₇, renewing and expanding the restrictive measures imposed on Belarus under Decision 2012/642/CFSP. The new decision keeps the sanctions in force until 28 February 2027, reflecting the EU’s assessment that the Belarusian regime remains a key supporter of Russia’s aggression against Ukraine and continues to violate human rights.

The amendment updates the list of 54 natural persons and 7 legal entities subject to EU sanctions. The list now includes high‑ranking officials, security‑force commanders, judges, and business leaders who have played a role in the repression of dissent and in facilitating Belarus’s involvement in the war. It also adds several state‑owned and private companies that supply military equipment, produce strategic minerals, or benefit from the Belarusian state’s control over critical resources.

For geoscientists, energy and mineral‑resource professionals, the decision highlights the EU’s focus on the Belarusian mining, chemical, and defense sectors. By sanctioning companies such as Beltechexport, AGAT, 140 Repair Plant, MZKT, Grodno Azot, Belshina, and Belaruskali, the EU aims to curb the flow of military technology and strategic raw materials that support Russia’s war effort and to pressure the Belarusian government to change its policies.

Key Elements

• Renewal Period – Sanctions remain in force until 28 February 2027.
  
• Expanded List of Individuals – 54 persons, including former ministers, security‑force commanders, judges, and political officials, are subject to asset freezes and travel bans.
  
• Newly Sanctioned Entities – 7 legal persons, notably:
  • Beltechexport – arms and military‑equipment exporter.
    
  • AGAT electromechanical Plant – manufacturer of riot‑control and military equipment.
    
  • 140 Repair Plant – produces armored vehicles used against protests.
    
  • MZKT (VOLAT) – produces military vehicles and has a history of suppressing worker protests.
    
  • Grodno Azot – state‑owned nitrogen‑compound producer.
    
  • Belshina – tyre manufacturer supplying Russian military.
    
  • Belaruskali – world‑leading potash producer, involved in the relocation of Ukrainian children.
    
• Sectoral Focus – Defense manufacturing, mining (potash, nitrogen compounds), chemical production, and logistics of military equipment.
  
• Sanction Measures – Asset freezes, travel bans, and restrictions on business dealings with the listed persons and entities.
  
• Policy Context – The decision is part of the EU’s Common Foreign and Security Policy (CFSP) to counter Belarus’s support for Russia’s war in Ukraine and to deter further human‑rights abuses.

EU Extends Sanctions on Belarus, Targeting Key Figures and Resource‑Based Companies

Overview

The European Union’s Council Implementing Regulation (EU) ²⁰²⁶⁄₄₂₆, adopted on 26 February 2026, renews restrictive measures against Belarus until 28 February 2027. The regulation implements Article 8a of Regulation (EC) No 765/2006, which was originally introduced to respond to Belarus’s role in the Russian aggression against Ukraine and to address human‑rights abuses within Belarus.

The regulation amends Annex I of the original sanctions list, adding 54 natural persons and 7 legal entities. These additions include high‑ranking officials, security‑force commanders, judges, and business leaders who have either directly supported the Lukashenko regime or benefited from its control over strategic sectors. The list also covers companies involved in mining, chemical production, and military‑industrial activities that supply equipment to Belarusian forces or to Russia’s war effort in Ukraine.

For professionals in geoscience, energy, and natural‑resource sectors, the updated list signals a tightening of EU controls on trade and investment with Belarusian enterprises. Export restrictions, asset freezes, and travel bans now apply to a broader set of entities that operate in key resource sectors such as potash mining (Belaruskali), nitrogen production (Grodno Azot), and tyre manufacturing (Belshina). The regulation therefore has direct implications for research collaborations, supply chains, and investment decisions involving Belarusian natural‑resource assets.

Key Elements

• Renewal of sanctions: Measures remain in force until 28 February 2027, ensuring continued EU pressure on Belarus.
  
• Expanded list of individuals: 54 natural persons, including former ministers, security‑force commanders, judges, and political figures, are subject to travel bans and asset freezes.
  
• Expanded list of entities: 7 legal persons, notably state‑owned mining and chemical companies (Belaruskali, Grodno Azot, Belshina, MZKT, AGAT, 140 Repair Plant, Beltechexport), face export restrictions and financial sanctions.
  
• Focus on strategic resources: The regulation targets companies that produce or export minerals, chemicals, and military equipment, thereby limiting Belarus’s ability to finance its regime and support Russia’s war effort.
  
• Enforcement across the EU: The regulation is directly applicable in all Member States, requiring national authorities to enforce travel bans, asset freezes, and trade restrictions.
  
• Implications for research and trade: Geoscientists, energy analysts, and natural‑resource professionals must review compliance requirements when engaging with Belarusian partners or accessing Belarusian data and resources.
  
• Potential ripple effects: Sanctions may affect global supply chains for potash, nitrogen fertilizers, and industrial chemicals, influencing commodity markets and investment flows in the region.

Streamlining the Interior’s NEPA Rules to Accelerate Energy and Resource Projects

Overview

The Department of the Interior (DOI) has finalized a rule that revises its National Environmental Policy Act (NEPA) implementing regulations. The rule largely removes the 2008 DOI NEPA regulations—now redundant after the Council on Environmental Quality (CEQ) rescinded its own NEPA rules—and places most procedural guidance in a new DOI NEPA Handbook. The change is intended to align DOI’s procedures with the 2023 NEPA amendments, reduce duplication with state, tribal, and local processes, and speed up permitting for energy, mineral, and land‑use projects while preserving the statutory environmental safeguards.

The final rule retains a core set of regulations that are essential for rapid, compliant action: emergency‑response provisions, categorical‑exclusion rules, and procedures for applicant‑ and contractor‑prepared environmental documents. It also codifies lead‑agency and cooperating‑agency designations, page limits, and deadlines for environmental assessments (EAs) and environmental impact statements (EISs). By moving the bulk of the guidance to a handbook, DOI gains flexibility to update procedures more quickly in response to evolving science, policy, and court decisions.

For geoscientists, energy developers, and natural‑resource professionals, the rule means clearer, more predictable NEPA workflows. Routine activities such as routine land management, infrastructure maintenance, or small‑scale resource development can proceed under categorical exclusions, while larger projects still trigger the full NEPA review but with streamlined timelines and reduced paperwork. Emergency actions—such as wildfire suppression or flood‑control measures—can be taken without a full NEPA analysis, provided the responsible official documents the decision and mitigates foreseeable impacts.

Key Elements

• Partial repeal of 2008 DOI NEPA regulations – most procedural guidance moved to the DOI NEPA Handbook (non‑regulatory).
  
• Retained regulations
  
  • Emergency response (46.150) – allows action without full NEPA review when imminent threats to life, property, or significant resources exist.
    
  • Categorical exclusions (46.205, 46.210, 46.215) – streamline routine actions; updated list and clarified extraordinary‑circumstance criteria.
    
  • Applicant‑ and contractor‑prepared documents (46.105, 46.107) – set standards for professional integrity, disclosure of conflicts, and independent review.
    
  • Lead and cooperating agencies (46.220, 46.225) – codify coordination among federal, state, tribal, and local entities.
    
• Updated page limits and deadlines – EISs capped at 150 pages (300 for complex projects) and EAs at 50 pages, with statutory deadlines of 1 year (EA) and 2 years (EIS).
  
• Public participation – required only at the notice‑of‑intent stage for EISs; other comment periods are optional, reflecting the 2023 NEPA amendments.
  
• Emergency procedures clarified – responsible officials must document the emergency, consider probable impacts, and mitigate where practicable.
  
• Categorical‑exclusion extraordinary circumstances – streamlined list; removed outdated references to executive orders and clarified that violations of environmental laws are not an extraordinary circumstance.
  
• No new environmental impacts – the rule itself is a categorical exclusion; it does not create or alter any environmental effects.
  

These changes aim to make DOI’s NEPA compliance more efficient, predictable, and responsive to the needs of energy, mineral, and land‑use stakeholders while maintaining the core environmental protections required by law.

FERC Removes Rehearing‑Delay Rule to Speed Natural Gas Pipeline Construction

Overview

The Federal Energy Regulatory Commission (FERC) has finalized a rule that eliminates a regulation—Section 157.23 of the Natural Gas Act—that previously barred the issuance of construction authorizations for natural‑gas facilities while a rehearing was pending. The change, confirmed in a 2026 Federal Register notice, makes the rule effective from November 10 2025. The decision follows a public comment period and a prior temporary waiver that had already lifted the restriction for one year.

FERC argues that the removal is necessary to meet rising electricity and natural‑gas demand, reduce potential delays that could threaten grid reliability, and align with President Biden’s executive orders aimed at accelerating energy infrastructure. The agency maintains that other safeguards—judicial review, stay orders, and a presumptive stay policy—continue to protect landowners and stakeholders.

The rule does not create new requirements; it simply removes the cross‑reference that tied construction authorizations to the status of a rehearing. Stakeholders can still seek judicial review or a stay if they believe a project should not proceed during a rehearing period.

Key Elements

• Removal of § 157.23 – Eliminates the prohibition on issuing construction authorizations while a rehearing is pending.
  
• Modification of § 153.4 – Deletes the cross‑reference to the removed section, ensuring the rule’s consistency.
  
• Effective Date – The rule takes effect on November 10 2025, as confirmed in the 2026 notice.
  
• Stakeholder Protections Remain – Judicial review, motions for stay, and the presumptive stay policy still apply to protect landowners and other affected parties.
  
• No New Regulatory Burden – The change simply removes a delay mechanism; no additional compliance requirements are added.
  
• Alignment with Energy Policy – Supports the administration’s goal of reducing construction delays for energy infrastructure under Executive Orders 14154 and 14156.
  
• Public Comment Process – The rule was preceded by a 30‑day comment period on a Notice of Proposed Rulemaking, with 23 comments received and addressed.
  
• Confirmation of Waiver Order – The temporary waiver issued in June 2025 is acknowledged, and the final rule confirms the removal without further rulemaking.

EPA Repeals Tightened Emission Rules for Coal‑ and Oil‑Fired Power Plants, Restoring 2012 Standards

Overview

On February 24 2026 the Environmental Protection Agency (EPA) issued a final rule that cancels the 2024 amendments to the National Emission Standards for Hazardous Air Pollutants (NESHAP) for coal‑ and oil‑fired electric‑utility steam‑generating units (EGUs). The repeal eliminates the stricter filterable particulate‑matter (fPM) limit that had applied to existing coal units, removes the mercury (Hg) limit for lignite‑fired EGUs, and ends the requirement that all such units demonstrate fPM compliance solely through continuous emissions monitoring systems (CEMS).

The action is part of the EPA’s broader regulatory‑relief agenda aimed at reducing burdens on the power sector while preserving overall air‑quality protections. The rule is effective April 27 2026 and restores the 2012 MATS limits for fPM and non‑Hg hazardous air‑pollutant metals.

Stakeholders—including utilities, environmental groups, and industry analysts—must review the updated 40 CFR 63 provisions to understand the new compliance landscape. While the repeal removes several costly requirements, other emission limits (e.g., for mercury, hydrogen chloride, and sulfur dioxide) remain in force, and reporting obligations continue under the existing framework.

Key Elements

• Restoration of 2012 Standards – fPM limit reverts to 0.030 lb/MMBtu; non‑Hg HAP metal limits return to 2012 levels.
  
• Removal of Mercury Limit for Lignite Units – the 1.2 lb/TBtu Hg cap is replaced by the 4.0 lb/TBtu standard.
  
• Elimination of Mandatory CEMS for fPM – units no longer must rely exclusively on particle‑counting CEMS to prove compliance; alternative monitoring methods are allowed.
  
• Cost Savings – EPA estimates annual compliance cost reductions of roughly $29.8 million for the power sector.
  
• Residual‑Risk Review Integration – the repeal reflects the 2020 residual‑risk analysis showing cancer risk already below the one‑in‑a‑million threshold, making the tighter fPM rule “unnecessary” under the Clean Air Act.
  
• Reporting Requirements Remain – mercury, HCl, HF, and SO₂ monitoring and quarterly compliance reporting continue unchanged under 40 CFR 63.
  
• Regulatory Flexibility – the action aligns with executive orders promoting deregulation and federalism, and it is subject to the Congressional Review Act.
  
• Stakeholder Guidance – utilities should consult the EPA docket (EPA‑HQ‑OAR‑2018‑0794) and the updated NESHAP tables to verify applicable limits and compliance options.

NBRC Embeds NEPA into Border Development Plans

Overview

The Northern Border Regional Commission (NBRC) has adopted a comprehensive set of procedures to weave the National Environmental Policy Act (NEPA) into every stage of its decision‑making. The notice, published in the Federal Register on February 24 2026, establishes how the commission will evaluate environmental impacts for grants, projects, and policy actions across Maine, New Hampshire, Vermont, and New York. By integrating NEPA early, NBRC aims to balance economic development with the protection of natural resources, ensuring that environmental considerations inform funding, planning, and implementation.

The procedures outline a clear workflow: determine whether NEPA applies, select the appropriate level of review (categorical exclusion, environmental assessment, or environmental impact statement), and document the decision. They also define the roles of NBRC staff, applicants, and cooperating agencies, set strict deadlines for assessments, and provide mechanisms for public participation and emergency action. The framework is designed to be efficient, reducing duplication by leveraging existing studies and encouraging coordination with state, tribal, and local partners.

For geoscientists, energy developers, and natural‑resource professionals, the notice signals that any NBRC‑funded activity—whether it involves infrastructure, utilities, or land‑use planning—must undergo a NEPA review that considers impacts on ecosystems, water resources, wetlands, endangered species, and cultural sites. The commission’s commitment to transparency and public input further ensures that stakeholders can influence decisions that shape the region’s environmental future.

Key Elements

• NEPA Integration: NBRC will apply NEPA to all grant programs, projects, and activities it administers, unless an action is exempt or falls under a statutory exception.
  
• Categorical Exclusions (CATEX): A detailed list of 8 CATEX categories (e.g., economic planning, workforce programs, equipment installation, facility modifications) is provided, with criteria for applicability and extraordinary‑circumstance checks.
  
• Review Levels:
  
  • CATEX for actions meeting exclusion criteria.
    
  • Environmental Assessment (EA) for actions with uncertain or likely non‑significant effects.
    
  • Environmental Impact Statement (EIS) for actions with significant, potentially irreversible effects.
    
• Roles and Responsibilities:
  
  • Executive Director as NEPA decision maker.
    
  • Grant Attorney to facilitate community engagement.
    
  • Program Staff to oversee applicant compliance and document preparation.
    
• Timelines:
  
  • EAs must be completed within 12 months of the decision to prepare.
    
  • EISs must be completed within 24 months.
    
  • Extensions require CEQ consultation and justification.
    
• Public Involvement: Notice of intent, public comment periods, and public records are mandatory for CATEX, EA, and EIS processes.
  
• Emergency Procedures: NBRC may adopt alternative arrangements for urgent actions, with CEQ approval and thorough documentation.
  
• Efficient Review:
  
  • Reliance on existing NEPA documents from other agencies.
    
  • Supplemental analyses for significant changes or new information.
    
  • Integration of other environmental requirements (e.g., wetlands, endangered species, historic preservation).
    
• Lead and Cooperating Agencies: NBRC may act as lead, joint lead, or cooperating agency, coordinating with federal, state, tribal, and local partners to streamline the NEPA process.
  
• Documentation and Transparency: All NEPA decisions, including CATEX determinations, EAs, EISs, FONSI, and RODs, will be publicly available on the NBRC website and tracked with unique identifiers.

DOE Closes Nuclear‑Fuel Cycle Meetings Under the Defense Production Act

Overview

The U.S. Department of Energy’s Office of Nuclear Energy has announced that a series of closed meetings were held in January 2026 to discuss the implementation of a Voluntary Agreement and related Plans of Action under the Defense Production Act (DPA). The meetings focused on key stages of the nuclear fuel cycle—including reactors, enrichment, reprocessing, mining, and utilities—and were conducted virtually via Microsoft Teams.

Because the discussions involved trade‑secret and commercially sensitive information, the DOE invoked §708 of the DPA and 10 CFR 821 to keep the sessions confidential, citing 5 U.S.C. 552b©. The notice, published in the Federal Register on February 24 2026, formally records the closed‑meeting status and the topics covered, while providing contact information for further inquiries.

These meetings represent a coordinated effort to streamline nuclear fuel supply chain operations, enhance national security, and ensure compliance with federal regulations while protecting proprietary data.

Key Elements

• Purpose: Implement a Voluntary Agreement and Plans of Action under the Defense Production Act for the nuclear fuel cycle.
  
• Scope: Covered reactors, enrichment, reprocessing, mining, utilities, fabrication, and deconversion.
  
• Meeting Format: Seven virtual sessions held on specific dates in January 2026 (e.g., Jan 13, 20, 27 for reactors; Jan 15, 22, 29 for utilities).
  
• Confidentiality: Closed to the public due to trade‑secret and commercial/financial information; justified under §708 DPA and 5 U.S.C. 552b©.
  
• Regulatory Framework: Governed by 10 CFR Part 821 and the DPA’s provisions for national defense production.
  
• Agency Leadership: Signed by Assistant Secretary for Nuclear Energy Theodore J. Garrish; contact via Ms. Sarah McPhee‑Charrez, Chief of Staff, Nuclear Fuel Cycle.
  
• Public Record: Notice published in the Federal Register (91 FR 8855) and available in PDF, XML, and other formats for transparency and archival purposes.

PacifiCorp Plans to Shut Down Klamath River Power Plant, Pass Assets to Yreka – Environmental Review Underway

PacifiCorp, the utility that operates the Klamath Hydroelectric Project on the Klamath River and Fall Creek, has filed a request to decommission the Fall Creek Development and transfer the associated infrastructure and lands to the City of Yreka, California. The move would cease power generation, disconnect the turbines from the grid, and drain the units of fluids, but it would not involve any new construction or ground‑disturbing activity. The City intends to use the decommissioned facilities for its water supply, while the California Department of Fish and Wildlife’s hatchery operations at Fall Creek would remain unaffected.

The Federal Energy Regulatory Commission (FERC) has announced its intention to prepare an Environmental Assessment (EA) under the National Environmental Policy Act (NEPA). The EA will evaluate the environmental impacts of the proposed conveyance and decommissioning, and will be issued by April 15, 2026. A 30‑day public comment period will follow the EA release, and all comments will be considered in FERC’s final decision. The comment period for the original application was extended to February 27, 2026, giving stakeholders ample time to submit input.

This action reflects a broader trend of utilities reassessing legacy hydroelectric assets in light of environmental, economic, and community considerations. The EA will provide the scientific basis for determining whether the decommissioning and conveyance can proceed without significant adverse environmental effects, and will inform future decisions on water resource management in the Klamath Basin.

Key Elements

• Decommissioning of Fall Creek Development – PacifiCorp will shut down power generation, disconnect turbines, and drain equipment.
  
• Conveyance to City of Yreka – Decommissioned infrastructure and lands will be transferred for the city’s water supply use.
  
• No New Construction – The proposal involves no ground‑disturbing activities or new facilities.
  
• Fish Hatchery Impact – The California Department of Fish and Wildlife’s hatchery operations at Fall Creek will not be affected.
  
• Extended Comment Period – Public comments on the application were extended to February 27, 2026.
  
• Environmental Assessment (EA) – FERC will issue an EA by April 15, 2026, followed by a 30‑day comment period.
  
• NEPA Compliance – The EA will assess environmental impacts under the National Environmental Policy Act.
  
• Public Participation – Stakeholders can file comments, motions to intervene, or protests through the Office of Public Participation.

FERC Waives Water‑Quality Certification for Erie Boulevard Hydropower Project

Overview
The Federal Energy Regulatory Commission (FERC) announced that the water‑quality certification requirement for Erie Boulevard Hydropower, L.P.’s Schuylerville Hydroelectric Project has been waived. The waiver follows the New York State Department of Environmental Conservation’s (DEC) failure to act on a Clean Water Act Section 401(a)(1) certification request within the one‑year reasonable period set by FERC staff. As a result, the project is no longer required to obtain a water‑quality certification before proceeding.

The notice, published on February 24, 2026, cites 18 CFR 2.1 and 33 U.S.C. 1341(a)(1) as the statutory basis for the waiver. The DEC’s inaction by the February 10, 2026 deadline triggered the automatic waiver, which is effective from that date. Erie Boulevard had previously filed a non‑capacity amendment to its license exemption (Project No. 8606‑010) on October 31, 2023, and the waiver clears a key regulatory hurdle for that amendment.

For stakeholders, the waiver means the project can move forward without the additional administrative burden of obtaining a water‑quality certification. However, the project must still comply with all other applicable environmental and safety regulations, and the waiver does not alter the underlying environmental impact assessments or the need for ongoing monitoring of water quality.

Key Elements

• Waiver Trigger – New York DEC did not act on the Section 401(a)(1) certification request within the one‑year reasonable period, leading to automatic waiver.
  
• Legal Basis – Clean Water Act § 401(a)(1), 33 U.S.C. 1341(a)(1); FERC authority under 18 CFR 2.1.
  
• Effective Date – Waiver applies from February 10, 2026, the deadline for DEC action.
  
• Project Context – Schuylerville Hydroelectric Project, non‑capacity amendment to license exemption (Project No. 8606‑010).
  
• Regulatory Impact – Removes the requirement for a water‑quality certification, but does not exempt the project from other environmental compliance obligations.
  
• Stakeholder Implications – Simplifies permitting for Erie Boulevard Hydropower, L.P.; may affect local water‑quality monitoring and reporting obligations.
  
• Future Oversight – FERC remains responsible for ensuring the project meets all other federal and state environmental standards.

Morrisville Hydroelectric Project: Settlement Agreement Opens Public Comment Window

Overview

The Federal Energy Regulatory Commission (FERC) has published a notice announcing a settlement agreement filed by the Village of Morrisville, Vermont, along with several state and environmental stakeholders. The agreement concerns the relicensing of the Morrisville Hydroelectric Project, which operates on the Green River, Elmore Pond Brook, and Lamoille River in Lamoille County. The parties—Morrisville, the Vermont Agency of Natural Resources, the Vermont Natural Resources Council, American Whitewater, and the Vermont Council of Trout Unlimited—have agreed to resolve compliance issues related to a 2016 Vermont water‑quality certification and the project’s whitewater flow releases.

The settlement aims to ensure that any new FERC license will include conditions that align with the agreed‑upon environmental and recreational standards. By addressing water‑quality and flow‑release concerns, the agreement seeks to balance energy production with ecological protection and recreational use of the river system. The notice invites public comments on the settlement and the proposed license conditions, providing an opportunity for local residents, scientists, and other stakeholders to influence the final regulatory outcome.

The comment period runs from March 23 to April 6, 2026, with both electronic and paper filing options available. FERC encourages the use of its eFiling and eComment systems, and all submissions must identify the project and docket number. The public participation process underscores the importance of transparent decision‑making in the management of small hydroelectric facilities that intersect with natural resource and recreation interests.

Key Elements

• Project Details: Morrisville Hydroelectric Project (P‑2629‑014) on the Green River, Elmore Pond Brook, and Lamoille River, Lamoille County, Vermont.
  
• Settlement Parties: Village of Morrisville, Vermont Agency of Natural Resources, Vermont Natural Resources Council, American Whitewater, Vermont Council of Trout Unlimited.
  
• Purpose of Settlement: Resolve relicensing issues tied to the 2016 Vermont water‑quality certification and whitewater flow releases from the Green River Development.
  
• License Conditions: Any new FERC license must incorporate conditions consistent with the settlement agreement’s environmental and recreational provisions.
  
• Comment Period: March 23 – April 6 2026 (5:00 p.m. Eastern Time).
  
• Filing Options: Electronic filing via FERC Online or QuickComment; paper filings accepted by U.S. Postal Service or other carriers.
  
• Public Participation: Encouraged through FERC’s eFiling system; all intervenors must serve copies to listed parties and relevant resource agencies.
  
• Access to Agreement: Available on FERC’s eLibrary (enter docket number P‑2629).
  
• Contact Information: Village Manager Scott Johnstone (857 Elmore St., Morrisville, VT 05661; (802) 888‑6289; sjohnsontone@mwlvt.com); FERC Project Coordinator Nicholas Ettema (Great Lakes Branch, Division of Hydropower Licensing).

U.S. Eyes Russian Palladium Imports: Final Trade Investigation Set to Begin

Overview

Palladium, a rare platinum‑group metal essential for catalytic converters, electronics, and emerging technologies, has become the focus of a new U.S. trade investigation. The International Trade Commission (ITC) has scheduled the final phase of countervailing duty (CVD) and antidumping duty (ADD) investigations into unwrought palladium imported from Russia. The inquiry follows a preliminary determination by the Department of Commerce that these imports may be sold at less‑than‑fair value and could be subsidized by the Russian government.

The notice outlines the scope of the investigation, covering all forms of unwrought palladium—whether mined, recycled, or blended—except for finished or processed products such as rolled or forged items. It sets key dates: a hearing on April 27, 2026, with pre‑hearing conferences and brief submission deadlines in late April and early May. Interested parties, including manufacturers, suppliers, and consumer groups, are invited to file appearances and submit written testimony through the ITC’s electronic filing system.

If the ITC finds that U.S. industries are materially injured or threatened by these imports, it could impose duties that raise the price of Russian palladium in the U.S. market. Such measures would affect supply chains, pricing for automotive and electronics manufacturers, and could prompt broader trade negotiations or retaliatory actions.

Key Elements

• Scope of Merchandise

  • Unwrought palladium in all physical forms (ingots, blocks, pellets, etc.)
    
  • Includes palladium from mining, recycling, or other production methods
    
  • Excludes finished or processed products (rolled, forged, extruded, etc.)
    

• Investigation Phases

  • Final phase scheduled under the Tariff Act of 1930 (sections 705(b) and 731(b))
    
  • Preliminary determination by Commerce pending; allegations of Russian subsidies
    

• Participation and Filing

  • Parties must file an appearance 21 days before the hearing (by April 22, 2026)
    
  • Electronic filings only via the ITC’s EDIS system
    
  • Non‑party statements allowed until May 4, 2026
    

• Business Proprietary Information (BPI)

  • Protected under an Administrative Protective Order (APO)
    
  • Authorized parties can access BPI 21 days before the hearing
    

• Key Dates

  • Hearing: April 27, 2026 (9:30 a.m.)
    
  • Pre‑hearing conference: April 24, 2026
    
  • Pre‑hearing brief deadline: April 21, 2026
    
  • Post‑hearing brief deadline: May 4, 2026
    
  • Final comments on unreviewed information: May 20–26, 2026
    

• Potential Outcomes

  • Imposition of countervailing or antidumping duties on Russian palladium
    
  • Impact on U.S. automotive, electronics, and industrial sectors
    
  • Possible trade negotiations or retaliatory measures by Russia
    

These provisions shape how U.S. stakeholders can engage with the investigation and anticipate the economic and regulatory consequences of the final phase.

Air Force Adopts 27 National Environmental Policy Act Exclusions to Streamline Operations

Overview

The Department of the Air Force (DAF) has officially adopted 27 categorical exclusions (CATEXs) from several federal agencies—including the Department of Energy, U.S. Geological Survey, U.S. Forest Service, Natural Resources Conservation Service, Department of the Interior, Bureau of Land Management, and Farm Service Agency—under the National Environmental Policy Act (NEPA). These exclusions allow the Air Force to bypass the more time‑intensive environmental assessments for a wide range of routine activities that are unlikely to have significant environmental impacts.

The adopted CATEXs cover diverse activities such as training exercises, construction and modification of power and communication infrastructure, geologic and hydrologic data collection, wetland restoration, and limited agricultural practices. By leveraging these pre‑approved categories, the Air Force can accelerate mission‑critical projects while still complying with NEPA’s requirement to evaluate extraordinary circumstances that might alter the environmental significance of an action.

The notice emphasizes that the Air Force will consult with the originating agencies, document any extraordinary circumstances, and use the established CATEXs only when appropriate. The exclusions become effective immediately, providing a streamlined framework for future Air Force projects that align with the environmental safeguards already in place.

Key Elements

• Adopted Agencies & CATEX Count: 27 exclusions from DOE, USGS, USFS, NRCS, DOI, BLM, and FSA.
  
• Scope of Activities:
  
  • Training and simulation exercises (e.g., firing‑range, emergency response).
    
  • Construction, modification, and removal of power transmission lines, substations, and fiber‑optic cables.
    
  • Installation and operation of solar photovoltaic systems and electric‑vehicle charging stations.
    
  • Geologic, hydrologic, and geophysical data collection and limited trenching.
    
  • Wetland, stream, and riparian restoration; post‑fire rehabilitation.
    
  • Soil control measures on agricultural lands and conservation easement purchases.
    
• Extraordinary Circumstances: DAF must assess and document any conditions that could make an action significant, applying mitigation or preparing an environmental assessment if needed.
  
• Consultation & Documentation: The Air Force worked with each establishing agency (Dec 2024–Apr 2025) to confirm appropriateness, and will complete detailed DAF Form 813 for each use.
  
• Effective Date: All 27 CATEXs are available for Air Force use immediately upon publication (Feb 24 2026).
  
• Purpose: To enhance mission capability, safety, and operational efficiency while maintaining NEPA compliance and protecting environmental quality.

Mississippi River Commission Meets to Tackle Floods, Navigation, and Water‑Resource Management

Overview

The U.S. Army Corps of Engineers has announced a public meeting of the Mississippi River Commission scheduled for March 2, 2026, in Vicksburg, Mississippi. The meeting will provide an update on the current state of the Mississippi River system, including weather conditions, reservoir levels, and spring flood projections. While the public can observe the proceedings, participation is limited to the Commission’s staff and officials.

The agenda focuses on critical water‑resource and infrastructure issues that affect navigation, flood control, and regional ecosystems. Topics include updates on the Yazoo Backwater, Arkabutla Dam operations, channel improvement projects, and the maintenance of a 12‑foot navigation channel. The Commission’s findings will inform future engineering decisions and policy actions that shape the river’s role in commerce, recreation, and environmental stewardship.

For stakeholders in geoscience, energy, and natural resource management, the meeting offers insight into how federal agencies coordinate flood‑risk mitigation, water‑way maintenance, and downstream impacts on ecosystems and local economies.

Key Elements

• Date & Time: March 2, 2026, 8 a.m.–5 p.m.
  
• Location: Mississippi River Commission Building, 1400 Walnut Street, Vicksburg, MS 39180.
  
• Public Access: Open for observation; no public participation.
  
• Agenda Highlights:
  
  • State of the River: weather, reservoir status, spring flood assessment.
    
  • Program updates on river management and infrastructure.
    
  • Yazoo Backwater and Arkabutla Dam operational reports.
    
  • Channel improvement initiatives and maintenance of the 12‑ft navigation channel.
    
• Contact Information: Drew Smith (Acting Executive Director) or Edie Whittington (Administrative Officer) for inquiries.
  
• Agency: U.S. Army Corps of Engineers, Department of Defense.
  
• Purpose: To review current conditions, assess risks, and guide future engineering and policy decisions affecting the Mississippi River basin.

Beaver Falls Power Plant Review: Environmental Assessment Made Public

Overview

The Federal Energy Regulatory Commission (FERC) has released an Environmental Assessment (EA) for the Townsend Water Power Project, a hydroelectric facility operated by the Beaver Falls Municipal Authority on the Beaver River in Beaver County, Pennsylvania. The EA, prepared under the National Environmental Policy Act (NEPA), evaluates the potential environmental impacts of continuing to license and operate the plant. FERC’s analysis concludes that, with appropriate protective measures, the project would not constitute a major federal action that significantly affects the quality of the human environment.

The assessment is now publicly available through FERC’s eLibrary and can be viewed or printed online. Stakeholders, including local residents, environmental groups, and industry participants, are invited to review the EA and submit comments. The comment period closes at 5:00 p.m. Eastern Time on Monday, March 23, 2026, with submissions accepted electronically via FERC’s eFiling or eComment systems, or by paper mail.

This notice reflects FERC’s ongoing commitment to transparency and public participation in the licensing of hydroelectric projects, ensuring that environmental considerations are integrated into energy infrastructure decisions.

Key Elements

• Project Details: Townsend Water Power Project (Project No. 3451) on the Beaver River, Pennsylvania.
  
• EA Conclusion: Licensing the plant, with protective measures, would not be a major federal action under NEPA.
  
• Public Access: EA available on FERC’s eLibrary; PDF link provided in the Federal Register.
  
• Comment Period: Open until 5:00 p.m. ET, Monday, March 23, 2026.
  
• Submission Methods:
  
  • Electronic: eFiling (http://www.ferc.gov/docs-filing/efiling.asp) or eComment (http://www.ferc.gov/docs-filing/ecomment.asp).
    
  • Paper: U.S. Postal Service to 888 First Street NE, Washington, DC 20426 (or other carriers to 12225 Wilkins Avenue, Rockville, MD 20852).
    
• Contact Information:
  
  • FERC Online Support: FERCOnlineSupport@ferc.gov, 866‑208‑3676 (TTY 202‑502‑8659).
    
  • Office of Public Participation: 202‑502‑6595, OPP@ferc.gov.
    
• Regulatory Context: Action taken under 18 CFR part 380 and 18 CFR 2.1; unique NEPA ID EAXX‑019‑20‑000‑1739953194.
  
• Implications for Geoscience & Natural Resources: The assessment addresses hydrological impacts, water quality, and ecological considerations of the Beaver River system, informing future hydroelectric development and resource management in the region.

Streamlining Colorado River Water Reporting: Bureau of Reclamation Seeks Public Input on Data Collection

Overview

The U.S. Bureau of Reclamation has issued a notice to renew and revise its information‑collection program that tracks diversions, return flow, and consumptive use of Colorado River water in the Lower Basin (Arizona, California, and Nevada). Under the Paperwork Reduction Act, the agency is inviting comments on the proposed collection before it is resubmitted to the Office of Management and Budget for approval. The goal is to ensure that water users comply with the 2006 Supreme Court decision in Arizona v. California, which requires the Secretary of the Interior to maintain accurate, annual records of water use to prevent over‑allocation.

The notice outlines the legal framework that governs the collection: the Paperwork Reduction Act, the 2006 Consolidated Decree, and the Bureau’s contractual obligations to water users. Respondents—state agencies, local water districts, tribal entities, and individual users—are required to submit monthly or annual data via Forms LC‑72 and custom forms. The Bureau estimates that 84 respondents will provide 491 responses each year, totaling about 103 hours of reporting time.

For stakeholders in geoscience, water resource management, and related fields, this initiative represents a critical effort to improve data quality and transparency. By refining the collection process, the Bureau aims to reduce administrative burden while strengthening the scientific basis for water allocation decisions that affect agriculture, industry, and ecosystems across the Lower Colorado River Basin.

Key Elements

• OMB Control Number: 1006‑0015
  
• Title of Collection: Diversions, Return Flow, and Consumptive Use of Colorado River Water in the Lower Colorado River Basin
  
• Forms Used: LC‑72 (annual) and custom forms (monthly)
  
• Estimated Respondents: 84 (state agencies, local districts, tribal entities, individuals)
  
• Estimated Annual Responses: 491
  
• Estimated Annual Burden Hours: 103 hours (≈2 minutes per response on average)
  
• Frequency of Collection: Monthly or annually, as specified in each water delivery contract
  
• Comment Period: Open until March 26 2026 (30‑day window)
  
• Contact for Comments: Kerim Dickson, Water Accounting and Verification Group, Lower Colorado Basin Office (email: kdickson@usbr.gov)
  
• Purpose: Ensure compliance with the 2006 Supreme Court decree and maintain accurate, up‑to‑date records of water use to prevent over‑allocation and support sustainable basin management.

Streamlining Offshore Mineral Rules: BOEM Cuts Red Tape for Hard Minerals

Overview

The Bureau of Ocean Energy Management (BOEM) has proposed a set of administrative revisions to the regulations that govern prospecting, leasing, and operations for minerals other than oil, gas, and sulfur on the Outer Continental Shelf (OCS). The changes are intended to remove outdated or redundant provisions, clarify existing requirements, and accelerate the permitting and leasing process in line with Executive Order 14285, which calls for a faster, more efficient approach to developing offshore critical minerals.

The proposal eliminates several sections of 30 CFR 580, 581, and 582 that are either no longer necessary or duplicate other rules. It shortens the time frame for BOEM to respond to unsolicited lease requests from 45 days to 28 days, and it removes references to jurisdictional controversies that are largely irrelevant for hard‑mineral activities. No new substantive requirements are added for applicants, and the rule is expected to have minimal impact on small businesses or state and tribal governments.

Comments on the rule are open until April 27, 2026. Stakeholders—including geoscientists, mineral developers, and environmental groups—are invited to submit input through the federal regulations portal or by mail. The final rule, if adopted, will streamline the regulatory framework for accessing seabed minerals such as nickel, cobalt, manganese, and rare‑earth elements, potentially accelerating the U.S. supply of critical materials for technology and defense.

Key Elements

• Elimination of redundant provisions

  • Sections 580.29–580.34 (environmental monitoring, notification, and appeal procedures)
    
  • Sections 581.5 and 581.9 (false statements and jurisdictional controversies)
    
  • Sections 582.7 and 582.50 (jurisdictional controversies and appeals)
    

• Revised leasing timeline

  • Section 581.11(b) now requires BOEM to respond to unsolicited lease requests within 28 days instead of 45 days, speeding up the leasing process.
    

• No new environmental or small‑business burdens

  • The rule is a categorical exclusion under NEPA and does not impose additional reporting or compliance costs on applicants.
    

• Alignment with Executive Order 14285

  • The revisions support the administration’s goal of expediting offshore critical‑mineral development while maintaining environmental safeguards.
    

• Comment period and public participation

  • Public comments are accepted until April 27, 2026, with submissions available via Regulations.gov or by mail to BOEM’s Office of Regulatory Affairs.
    

These changes aim to modernize the regulatory landscape for OCS hard minerals, making it clearer and more efficient for developers and scientists while preserving the environmental and procedural safeguards that govern offshore activities.

NOAA Re‑opens Seismic Survey Permits in the Gulf of America – Protecting Marine Mammals While Keeping Energy Development on Track

Overview

On February 24, 2026 NOAA announced a proposed rule to re‑implement the incidental‑take regulations (ITRs) that govern the limited, non‑intentional disturbance of marine mammals during geophysical surveys in the Gulf of America. The ITRs, originally issued in 2021 and reaffirmed in 2024 after correcting take estimates, expire on April 19, 2026. Re‑implementation is intended to avoid a regulatory lapse while a new ITR, requested by the EnerGeo Alliance, is still pending.

The rule preserves the existing framework of Letters of Authorization (LOAs) that set out mitigation, monitoring, and reporting requirements. Operators can obtain LOAs for up to five years of survey work, subject to the same Level A (potential hearing injury) and Level B (harassment) take limits that have been shown to be negligible for the species present. The proposal includes a comprehensive “negligible‑impact” analysis that evaluates species‑specific risk, population vulnerability, and the effectiveness of mitigation measures.

Public comment is invited until March 26, 2026. The rule applies to all geophysical survey activities in the Gulf of America—encompassing the Gulf of Mexico, Caribbean Sea, and adjacent waters—outside the Gulf of Mexico Energy Security Act (GOMESA) leasing moratorium area. It is designed to balance energy development with marine‑mammal protection by ensuring that any incidental disturbance is minimal, well‑documented, and compliant with the Marine Mammal Protection Act (MMPA) and the Endangered Species Act (ESA).

Key Elements

• Re‑implementation of ²⁰²¹⁄₂₀₂₄ ITRs to maintain regulatory certainty until a new rule is finalized.
  
• Letters of Authorization (LOAs) allow up to five years of geophysical survey activity under the same mitigation, monitoring, and reporting framework.
  
• Mitigation measures:
  
  • 500‑m exclusion zone around airgun arrays (1,500 m for special circumstances).
    
  • Ramp‑up procedures with pre‑clearance watches.
    
  • Immediate shutdown if a marine mammal enters the exclusion zone.
    
• Monitoring requirements:
  
  • Qualified Protected‑Species Observers (PSOs) for visual and acoustic monitoring.
    
  • Towed Passive Acoustic Monitoring (PAM) for deep‑water surveys.
    
  • Detailed sighting and acoustic encounter reporting.
    
• Take limits: only Level A and Level B harassment permitted; no other forms of taking allowed.
  
• Negligible‑impact analysis: species‑specific risk assessment, population vulnerability, and mitigation effectiveness combined to demonstrate that impacts are unlikely to affect recruitment or survival.
  
• Species focus: Rice’s whales, sperm whales, beaked whales, bottlenose dolphins, and other cetaceans; no Level A harassment expected.
  
• Public comment period: February 24 – March 26, 2026 (Regulations.gov docket code NOAA‑NMFS‑2025‑0638).
  
• Geographic scope: Gulf of America excluding the GOMESA moratorium area; no surveys in the eastern Gulf of Mexico core habitat of Rice’s whales.
  
• Compliance with ESA: Biological Opinion confirms no adverse effect on endangered species; subsistence use remains unaffected.
  
• Administrative efficiency: LOAs streamline permitting compared to older incidental‑harassment authorizations, potentially reducing industry costs while maintaining conservation safeguards.

Streamlining Hydropower License Terminations: New NEPA Exclusion Rule

Overview

The Federal Energy Regulatory Commission (FERC) has proposed a rule to broaden the National Environmental Policy Act’s (NEPA) categorical exclusion (CE) for certain actions involving water‑power licenses and exemptions. Under the current framework, the Commission must prepare an Environmental Assessment (EA) or Environmental Impact Statement (EIS) for most license terminations or revocations, even when the action is unlikely to affect the environment. The new rule would allow the Commission to treat a subset of these terminations—those that involve no or minimal ground‑disturbing activity and only minor or no changes to reservoir conditions or downstream flows—as categorically excluded, eliminating the need for an EA or EIS.

The proposal is grounded in a review of past cases. Since 1978, FERC has never found a termination or revocation that required an EIS, and most EAs concluded that the actions had no significant environmental impact. By codifying this experience into a CE, the Commission aims to reduce administrative burden, speed up the termination process, and free up resources for more substantive environmental reviews.

Stakeholders—including hydropower developers, state agencies, and environmental groups—have 30 days (until March 26 2026) to submit comments. The rule is purely procedural and does not impose new reporting requirements or economic burdens on license holders; it only changes how the Commission applies NEPA to certain termination actions.

Key Elements

• Expanded Categorical Exclusion: Adds a new CE for terminations or revocations that result in minor or no ground‑disturbing activity and minimal changes to reservoir conditions or downstream flows.
  
• No EA/EIS Required: Actions falling under the new CE will not trigger the preparation of an Environmental Assessment or Impact Statement.
  
• Procedural Nature: The rule is a procedural clarification; it does not alter the substantive environmental effects of termination orders.
  
• No New Information Collection: The rule does not impose additional reporting or record‑keeping obligations on license holders.
  
• Small‑Entity Impact: The Commission certifies that the rule will not have a significant economic impact on a substantial number of small entities.
  
• Comment Period: Public comments are accepted until March 26 2026, with submissions required to reference docket number RM26‑7‑000.
  
• Implementation: If finalized, the rule will amend 18 CFR § 380.4(a)(13) to include the new CE categories, simplifying NEPA compliance for FERC and its stakeholders.

Hydroelectric Power Meets Historic Preservation: A Temporary Flow Pause on the Potomac River

Overview

The Federal Energy Regulatory Commission (FERC) has accepted a notice from PE Hydro Generation, LLC requesting a temporary variance from the “water veil” flow requirement under Article 406 of the Federal Power Act. The variance would allow the National Park Service to conduct safety inspections and maintenance on Dam 4 and Dam 5 of the Potomac River hydroelectric projects located in West Virginia’s Chesapeake and Ohio Canal National Historic Park. The requested pause would last roughly 15 days each year, between May 15 and September 15, 2026, during which the licensee would suspend the required one‑ or two‑inch veil flow but would continue to provide the minimum downstream flows mandated by Article 404.

This action balances the operational needs of a renewable energy facility with the safety and preservation responsibilities of a federal historic park. The variance is temporary and limited in scope, designed to minimize ecological impact while enabling essential maintenance. The FERC notice invites public comment, protests, and motions to intervene, providing a formal opportunity for stakeholders—including environmental groups, local communities, and other agencies—to weigh in on the proposal.

The public comment period closes on March 20, 2026, and submissions can be filed electronically or by paper. The notice also encourages cooperating agencies to assist in preparing environmental documentation, though such agencies cannot intervene in the proceeding.

Key Elements

• Project Details

  • Dam 4 (Project P‑2516) and Dam 5 (Project P‑2517) on the Potomac River, West Virginia.
    
  • Located on federal land within the Chesapeake and Ohio Canal National Historic Park.
    

• Variance Request

  • Temporary suspension of the Article 406 water‑veil flow requirement for ~15 days each year (May 15–Sep 15, 2026).
    
  • Licensee will maintain Article 404 minimum downstream flows during the variance.
    

• Purpose

  • Enable National Park Service to conduct safety inspections, evaluations, and maintenance on the dams.
    

• Public Participation

  • Deadline for comments, protests, or motions to intervene: March 20, 2026, 5:00 p.m. ET.
    
  • Electronic filing via FERC eFiling/eComment systems; paper filings accepted.
    

• Cooperating Agencies

  • Federal, state, local, and tribal agencies with environmental expertise may assist in environmental documentation but cannot intervene.
    

• Contact Information

  • Applicant: PE Hydro Generation, LLC (via Eagle Creek Renewable Energy).
    
  • FERC Contact: Ms. Joy Kurtz.
    

• Regulatory Context

  • Filed under the Federal Power Act (16 U.S.C. 791a‑825r).
    
  • FERC’s rules on comments, protests, and interventions (18 CFR 385.210‑214).
    

• Implications for Geoscience and Natural Resources

  • Short‑term alteration of river flow may affect aquatic habitats and sediment transport.
    
  • Maintained downstream flows aim to mitigate ecological disruption.
    
  • The variance underscores the need to balance renewable energy development with historic and environmental stewardship.

Silicon Metal from Thailand: U.S. Sets 31% Countervailing Duties After 2024 Subsidy Probe

Overview

The U.S. Department of Commerce has finalized its countervailing duty (CVD) investigation into silicon metal exports from Thailand, concluding that Thai producers receive substantial government subsidies that distort U.S. markets. The investigation covered the 2024 calendar year and, after a preliminary determination in September 2025, issued a final duty rate of 31.27 % ad valorem for the two companies examined—G.S. Energy Co., Ltd. and Sica New Materials (Thailand) Co., Ltd.—and applied the same rate to all other Thai exporters of silicon metal.

The determination suspends the liquidation of U.S. customs entries of the affected merchandise, requiring cash deposits equal to the estimated duties until the U.S. International Trade Commission (ITC) decides whether U.S. industry is materially injured by these imports. If the ITC confirms injury, the U.S. will impose the duties; if not, the deposits will be refunded. The scope covers all silicon metal containing 85–99.99 % silicon (excluding semiconductor‑grade silicon) and is classified under HTS subheadings 2804.69.1000 and 2804.69.5000.

This action reflects the U.S. commitment to enforce trade laws that protect domestic industries from unfair foreign subsidies, while also ensuring that any duties imposed are based on a rigorous, evidence‑based assessment of subsidy programs and their impact on U.S. markets.

Key Elements

• Final Duty Rate: 31.27 % ad valorem for G.S. Energy, Sica New Materials, and all other Thai silicon metal exporters.
  
• Scope: Silicon metal 85–99.99 % silicon (≤ 4 % iron); excludes semiconductor‑grade silicon (≥ 99.99 % silicon).
  
• Suspension of Liquidation: U.S. Customs must hold cash deposits equal to the estimated duties until the ITC’s injury determination.
  
• ITC Notification: The ITC will decide within 45 days whether U.S. industry is materially injured; duties will be imposed only if injury is found.
  
• All‑Others Rate Method: Derived from the individual rates of the two examined companies, as allowed by the Tariff Act.
  
• Timeline: Investigation period Jan 1–Dec 31 2024; preliminary determination published Sep 26 2025; final determination published Feb 17 2026.
  
• Compliance & Disclosure: No new calculations were made since the preliminary determination; the final notice includes all relevant data and procedural steps.
  
• Trade‑Law Context: The action aligns with U.S. commitments under the Tariff Act of 1930 and the World Trade Organization’s rules on countervailing duties.

BLM Extends 20‑Year Withdrawal of Utah Lands to Protect Water‑Supply System

Overview

The Bureau of Land Management (BLM) has proposed extending Public Land Order (PLO) No. 7668 for an additional 20 years. The order withdraws 6,558.96 acres of National Forest System land in Utah County from the United States mining laws—though it does not restrict leasing under mineral or geothermal statutes—to safeguard the ongoing operation and potential future replacement of the Diamond Fork Systems that supply water to the Bonneville Unit of the Central Utah Project.

The proposal corrects the land description, reducing the withdrawal area to the accurate acreage and identifying two parcels that are actually non‑Federal. These parcels would become subject to the withdrawal only if the U.S. later acquires them. The lands remain open to all other uses authorized by law, such as recreation, grazing, or timber harvest, provided they do not conflict with the withdrawal’s purpose.

Public participation is encouraged: comments are accepted until May 26, 2026, and a virtual public meeting will be held on April 9, 2026, to discuss the proposal. The BLM invites stakeholders—including geoscientists, water‑resource managers, and local communities—to review the corrected boundaries and assess the impact on water‑delivery infrastructure and surrounding ecosystems.

Key Elements

• 20‑year extension of PLO No. 7668 to protect the Diamond Fork water‑delivery system.
  
• Withdrawal from mining laws only; leasing under mineral or geothermal statutes remains allowed.
  
• Accurate land description: 6,558.96 acres in Utah County; two parcels corrected as non‑Federal.
  
• Open to other lawful uses (recreation, grazing, timber) that do not interfere with the withdrawal’s purpose.
  
• No water rights required to fulfill the withdrawal’s objectives.
  
• Public comment period closes May 26, 2026; comments submitted to BLM Utah State Office.
  
• Virtual public meeting scheduled April 9, 2026 (5–6 p.m. MT) to discuss the proposal and answer questions.
  
• Potential future changes: if the U.S. acquires the two non‑Federal parcels, they would become subject to the withdrawal.

BLM Opens 999‑Acres of Utah Land for Non‑Metalliferous Mining

Overview

The Bureau of Land Management (BLM) has announced that a parcel of land in the Salt Lake Meridian, Utah—previously restricted by Executive Order 5327 (1930) and later revoked by Public Land Order 7725 (2009)—is now open for location and entry under U.S. mining laws, but only for non‑metalliferous minerals. The decision follows a BLM analysis confirming that opening the area aligns with existing land‑use plans and does not conflict with other federal or state regulations.

The opening covers 999.41 acres described in the official survey plat. It becomes effective on February 23, 2026, at 9 a.m. Mountain Time. All valid applications received at or before that time will be treated as simultaneously filed; later applications will be processed in order of receipt. Any appropriation of the land before the opening time will be rejected.

This action does not alter the status of oil‑shale leasing or other existing rights on the property. It simply allows non‑metalliferous mineral exploration and development under the U.S. mining laws, subject to existing withdrawals, segregations, and applicable statutes.

Key Elements

• Area opened: 999.41 acres in the Salt Lake Meridian, Utah (T. 15 S., R. 1 E., Sec. 31, lots 1–14, NE ¹⁄₄, E ¹⁄₂ NW ¹⁄₄, NE ¹⁄₄ SW ¹⁄₄, and N ¹⁄₂ SE ¹⁄₄).
  
• Type of mining: Location and entry under U.S. mining laws only for non‑metalliferous minerals (e.g., oil shale, coal, gypsum).
  
• Effective date/time: February 23, 2026, at 9 a.m. Mountain Time.
  
• Application handling: Applications received before the opening time are considered simultaneously filed; later applications are processed in order of receipt.
  
• Existing rights: All valid existing rights, withdrawals, and segregations remain in effect.
  
• Appropriation rule: Any appropriation of the land before the opening time will be rejected.
  
• Regulatory compliance: The opening conforms to 43 CFR 2091.6 and relevant land‑use plans.
  
• Contact information: Brendan Willig, BLM Utah State Office, (801) 539‑4292, bwillig@blm.gov.
  
• Implications for stakeholders: Geoscientists, mineral developers, and energy companies can now explore non‑metalliferous resources in the area, while oil‑shale leasing and other surface uses remain unaffected.

Undersea Tech Consortium Expands Membership, Signals New Collaborative Frontiers

Overview

The Department of Justice’s Antitrust Division has published a notice under the National Cooperative Research and Production Act of 1993 (NCRPA) regarding the Undersea Technology Innovation Consortium (UTIC). The NCRPA requires that any changes in the membership of a federally funded research consortium be reported to the Attorney General and the Federal Trade Commission. UTIC, a group research project focused on advancing undersea technology, has recently added several new companies—including Chance Technologies, Saronic Technologies, and Sofar Ocean Technologies—while a handful of previous members have withdrawn.

This update does not alter the consortium’s research agenda or funding; membership remains open to additional participants. The notice underscores the consortium’s commitment to transparency and compliance with antitrust regulations, ensuring that any potential competition concerns are addressed proactively. For stakeholders in oceanography, marine engineering, and related geoscience fields, the expanded roster signals a broadening of expertise and resources that could accelerate innovations in subsea sensing, autonomous vehicles, and data analytics.

Key Elements

• Legal Framework: Notification required under Section 6(a) of the NCRPA; published under Section 6(b).
  
• Membership Changes:
  
  • New parties added: Chance Technologies, Saronic Technologies, Thomson Reuters Special Services, Defense Unicorns, Washtenaw Precision Engineering, Lean Scaled Architects, Orpheus Ocean, Red Cedar USA, Caci (Federal), General Dynamics Information Technology, Sofar Ocean Technologies, Marestella, Hayward Tyler, Hii Mission Technologies, N8tive Solutions.
    
  • Withdrawn parties: Kenautics, Greensea Systems, Universal Solutions International.
    
• Scope of Impact: No changes to the consortium’s planned activities or research focus; membership remains open for future additions.
  
• Compliance and Transparency: UTIC will continue to file written notifications for any subsequent membership changes, maintaining adherence to antitrust oversight.
  
• Implications for the Field: The broadened consortium brings together a mix of defense, commercial, and academic partners, potentially enhancing cross‑disciplinary collaboration in undersea technology development.

ITC Keeps Antidumping Shield on Chinese Manganese Dioxide, Protecting U.S. Battery Supply Chain

Overview
The U.S. International Trade Commission (ITC) has issued a determination that revoking the antidumping duty order on electrolytic manganese dioxide (EMD) from China would likely cause material injury to U.S. manufacturers within a foreseeable future. EMD is a critical component in lithium‑ion batteries, solar panels, and other high‑performance electronic devices, making it a key raw material for the growing clean‑energy sector.

The ITC’s decision follows a third‑review five‑year investigation that began in June 2025. After an expedited review and a comprehensive record‑keeping process, the Commission concluded that the U.S. industry remains vulnerable to price and supply shocks from Chinese imports. Consequently, the antidumping duties will remain in place, ensuring that domestic producers can compete on a level playing field.

For geoscientists and natural‑resource professionals, this ruling underscores the importance of secure, sustainable manganese supply chains. It highlights how trade policy can influence mining, processing, and environmental stewardship of critical minerals, and it signals that U.S. stakeholders may need to invest further in domestic extraction, recycling, and alternative material research to reduce dependence on foreign sources.

Key Elements

• Determination: Revocation of the antidumping duty order on Chinese EMD would likely lead to continued or recurring material injury to U.S. industry.
  
• Continued Duty Order: Antidumping duties remain in effect, protecting U.S. manufacturers from lower‑priced Chinese imports.
  
• Industry Impact: Affects battery manufacturers, electronics producers, and renewable‑energy equipment suppliers that rely on EMD.
  
• Supply‑Chain Security: Reinforces the need for diversified manganese sourcing, including domestic mining and recycling initiatives.
  
• Environmental Considerations: Stable demand for EMD may influence mining practices, tailings management, and emissions associated with extraction and processing.
  
• Policy Timeline: The determination was filed on February 18, 2026, and published on February 23, 2026, following a third‑review five‑year investigation that began in June 2025.
  
• Broader Implications: Signals ongoing U.S. focus on securing critical minerals for the clean‑energy transition and may prompt further research into alternative materials or supply‑chain resilience strategies.

US Targets Laos Silicon Metal: Final Dumping Determination and Non‑Market Economy Status

The U.S. Department of Commerce has concluded that silicon metal exported from the Lao People’s Democratic Republic (Laos) is being sold in the United States at less than fair value (LTFV). Silicon metal—an intermediate product used in semiconductor manufacturing and solar panel production—has been found to carry a high estimated weighted‑average dumping margin of 94.44 %. The investigation, covering the period from October 1 2024 to March 31 2025, also designates Laos as a non‑market economy (NME) for future trade proceedings, a status that can lead to higher duty rates and stricter enforcement.

Because the determination is affirmative, the U.S. Customs and Border Protection (CBP) has been instructed to suspend the liquidation of all Laos‑origin silicon metal entries and to require cash deposits equal to the estimated duties. These measures remain in effect until the U.S. International Trade Commission (ITC) decides whether U.S. domestic industry is materially injured by the imports. If the ITC finds injury, the U.S. will issue an antidumping order and CBP will assess duties on all subsequent imports. The final determination follows a preliminary notice issued in September 2025; no comments were received, and no on‑site verification was conducted.

For stakeholders in the geoscience, energy, and mineral‑resource sectors, this ruling signals a significant shift in U.S. trade policy toward silicon‑based materials. It underscores the importance of monitoring market‑value pricing, export subsidies, and the classification of trading partners, all of which can influence supply chains, pricing, and the competitiveness of U.S. semiconductor and renewable‑energy industries.

Key Elements

• Dumping margin: 94.44 % for Lao Silicon Co., Ltd. and all other exporters not individually investigated.
  
• All‑others rate: 94.44 % (same as the individual rate).
  
• Non‑market economy status: Laos classified as an NME for future antidumping and countervailing duty proceedings.
  
• Suspension of liquidation: CBP will suspend liquidation of Laos‑origin silicon metal entries from September 30 2025 onward.
  
• Cash deposit requirement: Importers must post cash deposits equal to the estimated duties until the ITC makes an injury determination.
  
• ITC notification: The ITC will assess material injury within 45 days; if injury is found, an antidumping order will be issued.
  
• Procedural notes: No comments on the preliminary determination; no on‑site verification; use of adverse facts available (AFA) to calculate dumping margins.
  
• Scope of investigation: All silicon metal containing 85–99.99 % silicon (excluding semiconductor‑grade silicon).
  
• Implications for trade: Potentially higher tariffs on silicon metal imports from Laos, affecting U.S. semiconductor and solar‑panel supply chains.

Silicon Metal from Angola: U.S. Trade Action and Market‑Economy Designation

Overview

The U.S. Department of Commerce has finalized its investigation into silicon metal imports from Angola, concluding that these products are being sold in the United States at less than fair value (LTFV). The determination covers the period April 1 2024 through March 31 2025 and applies to all forms of silicon metal (85–99.99 % silicon,  % iron), excluding semiconductor‑grade silicon. Because no U.S. respondents participated, the agency relied on adverse‑facts analysis to estimate dumping margins for two Angolan exporters—PC Silicon Co. Ltd. and Wanhongda International Ltd.—and set an all‑others rate of 68.45 %.

The agency also classified Angola as a non‑market economy (NME) for future antidumping proceedings, meaning that future duty calculations will use the NME methodology. The final determination triggers a suspension of liquidation and requires cash deposits for Angolan silicon metal entries that entered the U.S. after September 30 2025. The U.S. International Trade Commission (ITC) will review whether U.S. domestic industry is materially injured or threatened by these imports; if injury is found, the U.S. Customs and Border Protection will impose antidumping duties on subsequent entries.

This action reflects the U.S. commitment to enforce trade laws that protect domestic industries from unfair foreign competition, while also ensuring that the classification of Angola as an NME is consistently applied in future trade disputes.

Key Elements

• Dumping Margins:

  • PC Silicon Co. Ltd. – 68.45 %
    
  • Wanhongda International Ltd. – 68.45 %
    
  • All‑others rate – 68.45 % (based on adverse‑facts analysis)
    

• Scope of Investigation:

  • Covers silicon metal (85–99.99 % Si,  % Fe) under HTSUS subheadings 2804.69.1000 and 2804.69.5000.
    
  • Excludes semiconductor‑grade silicon (≥99.99 % Si).
    

• Suspension of Liquidation & Cash Deposits:

  • CBP must suspend liquidation of Angolan silicon metal entries from September 30 2025 onward.
    
  • U.S. importers must deposit cash equal to the estimated antidumping duties.
    
  • Suspension ends on January 28 2026 unless the ITC issues a final injury determination.
    

• ITC Notification:

  • ITC to decide within 45 days whether U.S. industry is materially injured or threatened.
    
  • If injury is found, antidumping duties will be imposed; if not, deposits are refunded and suspension lifted.
    

• Non‑Market Economy Status:

  • Angola classified as an NME for all future segments of this proceeding.
    
  • NME methodology will be used to calculate antidumping duties in subsequent actions.
    

• Administrative Protective Order (APO):

  • Parties must comply with APO requirements for proprietary information disclosed during the investigation.
    

• Timeline & Deadlines:

  • Final determination published February 23 2026.
    
  • Deadline for final determination was February 17 2026 (adjusted for government shutdown tolling).
    

These provisions collectively aim to level the playing field for U.S. silicon metal producers and to ensure that trade remedies are applied consistently and transparently.

Greenup Hydroelectric Project to Undergo Environmental Review Ahead of Relicensing

The City of Hamilton, Ohio, and American Municipal Power, Inc. have filed a relicense application for the 70‑megawatt Greenup Hydroelectric Project, located on the Ohio River at the U.S. Army Corps of Engineers’ Greenup Locks and Dam. The facility occupies 12.74 acres of federal land and has been in operation for decades, providing renewable power to the region.

On February 18, 2026, the Federal Energy Regulatory Commission (FERC) announced its intent to prepare an Environmental Assessment (EA) for the relicense request. The EA will evaluate whether the project’s continued operation would constitute a major federal action under the National Environmental Policy Act. FERC expects to issue the EA on November 23, 2026, and will circulate it for public comment. All comments will be considered in the final licensing decision.

The notice invites stakeholders—including local residents, environmental groups, and industry participants—to submit comments, interventions, or requests for rehearing. The process underscores FERC’s commitment to transparency and environmental stewardship while ensuring that the Greenup project can continue to supply clean energy to the Ohio River Valley.

Key Elements

• Project Overview

  • 70.27‑MW hydroelectric facility at Greenup Locks and Dam, Ohio River
    
  • Operated by American Municipal Power, Inc., owned by the City of Hamilton
    
  • Covers 12.74 acres of federal Corps land

• Relicensing Application

  • Filed on February 21, 2024, under Project No. 2614‑042
    
  • Seeks to extend the operating license beyond the current term

• Environmental Assessment (EA)

  • FERC’s intent to prepare an EA indicates the project is not expected to be a major federal action
    
  • EA will assess impacts on water quality, fish and wildlife, sediment transport, and downstream communities

• Timeline

  • EA issuance target: November 23, 2026
    
  • Public comment period will follow EA release

• Public Participation

  • Stakeholders may file interventions, comments, or rehearing requests
    
  • Contact: Office of Public Participation (202‑502‑6595, OPP@ferc.gov)

• Regulatory Context

  • Action governed by 18 CFR 2.1 and the National Environmental Policy Act
    
  • Unique EPA identification number: EAXX‑019‑20‑000‑1769181282

• Implications for Geoscience & Energy Communities

  • Provides a case study in balancing renewable energy infrastructure with riverine ecosystem protection
    
  • Highlights the role of federal agencies in ensuring environmental compliance for hydroelectric projects

This notice signals the next step in ensuring that the Greenup Hydroelectric Project continues to operate responsibly while meeting federal environmental standards.

Las Vegas Land Sale: 22 Public Parcels Auctioned Online, Ending Recreation Lease

Overview

The Bureau of Land Management (BLM) has announced a modified competitive sale of 232.9 acres of public land in the Las Vegas Valley, covering parts of Clark County, the City of Las Vegas, and Henderson. The parcels, which were previously classified under a 10‑acre recreation and public purposes (R&PP) lease, will be offered at fair‑market value through an online auction platform, Efficient Markets. The sale is part of the Southern Nevada Public Land Management Act (SNPLMA) and is intended to streamline the process, increase transparency, and encourage broader participation.

The BLM will accept written comments until April 10, 2026, and the auction is scheduled to open on April 28, 2026. Each parcel will have a 24‑hour bidding window, and the highest qualifying bid will be binding. Buyers must provide proof of U.S. citizenship or corporate status, register on the auction site, and meet a bid allowance verified by a financial institution. The sale also terminates the R&PP lease, meaning the parcels will no longer be subject to the lease’s recreational restrictions and will be available for private development, subject to federal mineral reservations and other land‑use constraints.

For geoscientists, energy, and mineral‑resource professionals, the key implications are the preservation of federal mineral rights on the parcels, the potential for future mining or resource extraction, and the requirement to comply with environmental and land‑use regulations. The sale is accompanied by NEPA documentation and a record of decision that confirms no hazardous substances are present, ensuring a clear legal and environmental baseline for future owners.

Key Elements

• Sale Method: Modified competitive bidding via the Efficient Markets online platform; each parcel has a separate 24‑hour auction window.
  
• Parcels: 22 parcels totaling 232.89 acres, located in Clark County, Las Vegas, and Henderson; includes a former 10‑acre R&PP lease parcel (NVNV106380155).
  
• Comments Period: Open until April 10, 2026; comments submitted to BLM Las Vegas Field Office.
  
• Mineral Rights: All minerals on the parcels remain reserved to the United States; owners may use minimal amounts for personal purposes but must obtain permits for larger extraction.
  
• Payment & Fees: Successful bidders must pay 20 % deposit immediately after auction, with the balance due within 180 days; a 1.5 % commission is charged by Efficient Markets.
  
• Access & Use: Parcels may lack public road access; buyers are responsible for securing future access.
  
• Environmental Review: NEPA‑approved environmental assessments confirm no hazardous substances; parcels are withdrawn from mining and geothermal leasing until sale completion.
  
• Legal & Regulatory Compliance: Bidders must meet U.S. citizenship or corporate eligibility, register on the auction site, and comply with FLPMA, SNPLMA, and CERCLA provisions.
  
• Timeline: Auction opens April 28, 2026; sale documents and final decisions will follow after payment completion.

BLM Proposes Direct Sale of 2,062‑Acres in Nevada’s Anaconda Mine Site to Facilitate Cleanup

Overview

The Bureau of Land Management (BLM) has announced a non‑competitive sale of 2,062.42 acres of federal land in Lyon County, Nevada, to Atlantic Richfield Company (ARC). The parcels, part of the historic Anaconda Copper Mine Site (ACMS), are heavily contaminated from past mining operations. While the fair‑market value (FMV) appraisal lists the land at $760,000, the BLM has determined that the contamination renders the property effectively worthless and proposes to convey it for $0 to enable ARC to carry out the CERCLA‑mandated remediation.

The sale includes the underlying mineral estate and is intended to streamline ARC’s responsibility as a potentially responsible party. By transferring ownership, ARC can more efficiently manage cleanup activities, coordinate with state and federal agencies, and avoid the administrative burden of managing contaminated federal land. The transaction is governed by the Federal Land Policy and Management Act (FLPMA) and BLM land‑sale regulations, and it will be subject to a series of reservations, indemnification clauses, and a covenant not to sue the U.S. in connection with remediation efforts.

Comments on the proposed sale are open until April 9, 2026. If no objections arise, the BLM will publish the sale notice in the local newspaper, and ARC will have 30 days to accept the offer and submit the required eligibility certificate. The sale will be finalized upon issuance of a patent, after which the land will be fully segregated from other public‑land uses and subject to local zoning, road, and utility reservations.

Key Elements

• Land and Buyer: 2,062.42 acres in Lyon County, Nevada, to Atlantic Richfield Company (ARC).
  
• Sale Price: Proposed at $0, reflecting the lack of market value due to contamination.
  
• Fair‑Market Value: Appraised at $760,000 under USPAP, but deemed irrelevant because remediation costs exceed FMV.
  
• Mineral Estate: Included in the sale, giving ARC control over potential mineral resources.
  
• Remediation Context: ARC is a potentially responsible party under CERCLA; sale facilitates cleanup of the Anaconda Copper Mine Site.
  
• Legal Framework: Governed by FLPMA, 43 CFR part 2710, and BLM land‑sale regulations.
  
• Reservations and Conditions:
  
  • Rights of way for ditches, canals, roads, utilities, and flood control.
    
  • Indemnification of the U.S. for claims arising from ARC’s use of the land.
    
  • Covenant not to sue the Interior Department regarding remediation investigations.
    
• Segregation: Land will be segregated from other public‑land uses upon publication of the notice.
  
• Comment Period: Open until April 9, 2026; comments reviewed by the Nevada State Director.
  
• Acceptance Window: ARC has 30 days from receipt of the offer to accept and submit a certificate of eligibility.
  
• Finalization: Sale becomes effective upon issuance of a patent; thereafter, the land is fully private property subject to local laws.

Executive Order 14387: Securing Phosphorus and Glyphosate for National Defense and Food Security

Overview On February 18 2026, President Trump issued Executive Order 14387, declaring elemental phosphorus and glyphosate‑based herbicides essential to U.S. national defense and agricultural productivity. The order cites phosphorus’s role in defense technologies—smoke, illumination, incendiary devices, semiconductors, and lithium‑ion batteries—and glyphosate’s status as the most widely used crop protection agent that keeps U.S. food prices low and yields high. With only one domestic producer of phosphorus and herbicides and a reliance on imports for over 6 million kilograms of phosphorus annually, the administration argues that any disruption could jeopardize military readiness and food supply. The order leverages the Defense Production Act (DPA) to prioritize and allocate resources for these materials. It delegates the authority to the Secretary of Agriculture, in consultation with the Secretary of War, to issue orders, rules, and regulations that ensure a continuous supply while protecting the viability of domestic producers. The President also grants immunity to producers under the DPA’s provisions, reinforcing the legal framework for rapid response.

Key Elements

- Critical Material Designation: Phosphorus is listed as a critical mineral under the Energy Act of 2020; glyphosate is deemed essential for maintaining U.S. agricultural advantage. - Defense Production Act Authority: The order invokes Section 101 of the DPA, allowing the President to require contracts and allocate materials to promote national defense. - Delegation to Agriculture: The Secretary of Agriculture is empowered to set nationwide priorities, issue orders, and revise regulations to secure phosphorus and herbicide supplies. - Protection of Domestic Producers: Orders must not jeopardize the corporate viability of existing domestic producers; immunity is granted under Section 707 of the DPA. - Implementation and Oversight: The Secretary must coordinate with the Secretary of War, issue necessary rules, and ensure compliance with 7 CFR part 789. - Budget and Legal Constraints: The order is subject to appropriations, does not alter existing agency authorities, and does not create enforceable rights for private parties.

Hilcorp Receives 5‑Year Permit to Incidental Take Marine Mammals During Oil & Gas Operations in Cook Inlet

Overview

The U.S. National Marine Fisheries Service (NMFS) has issued a final rule authorizing Hilcorp Alaska, LLC to incidentally take marine mammals during its oil and gas exploration, development, production, and decommissioning activities in Cook Inlet, Alaska. Under the Marine Mammal Protection Act (MMPA), Hilcorp may take small numbers of marine mammals by harassment (Level A or Level B) for a period of five years (February 20 2026 – February 19 2031). The rule permits no mortality or serious injury and requires the company to follow strict mitigation, monitoring, and reporting protocols.

The specified activities include towing, holding, or positioning jack‑up rigs; impact pile driving for well development and exploratory drilling; and pipeline installation or replacement involving anchor handling and pipe pulling. NMFS estimates that the total number of takes will be limited to a few dozen individuals per species per year, with a maximum of 147 beluga whale takes over the five‑year period—less than 10 % of the Cook Inlet beluga population. The rule incorporates seasonal restrictions on pile driving, clearance and shutdown zones, “soft‑start” techniques, and the use of protected‑species observers (PSOs) to minimize disturbance.

The agency concluded that the authorized activities will have a negligible impact on marine mammal populations and will not adversely affect subsistence uses by Alaskan Native communities. Adaptive‑management provisions allow NMFS to modify the authorization if new data indicate a need for stronger mitigation or monitoring. The rule also includes a regulatory‑flexibility analysis showing that the compliance burden is limited to Hilcorp, a large oil‑and‑gas operator, and that the rule is a deregulatory action under Executive Order 14192.

Key Elements

• Effective Period: 5 years (Feb 20 2026 – Feb 19 2031).
  
• Permitted Take: Incidental harassment (Level A and B) of 12 marine‑mammal species (15 stocks); no mortality or serious injury.
  
• Estimated Takes:
  
  • Beluga whales: up to 147 takes over 5 years (≈10 % of the stock).
    
  • Other species: 30–50 takes per year, well below one‑third of population estimates.
    
• Specified Activities:
  
  • Tugs towing/holding jack‑up rigs.
    
  • Impact pile driving (production and exploratory wells).
    
  • Pipeline installation/replacement (anchor handling, pipe pulling).
    
• Mitigation Measures:
  
  • Seasonal pile‑driving restrictions (Nov 15 – Apr 15).
    
  • Clearance and shutdown zones (up to 2.4 km for certain species).
    
  • “Soft‑start” pile‑driving to give mammals time to leave.
    
  • PSOs required on all activities, with 30‑minute pre‑start and post‑activity monitoring.
    
• Monitoring & Reporting:
  
  • Monthly interim reports and annual summaries.
    
  • Detailed PSO data sheets, behavioral observations, and mitigation effectiveness.
    
  • Immediate reporting of any injured or dead marine mammals.
    
• Impact Analysis:
  
  • Negligible impact on population recruitment or survival.
    
  • No unmitigable adverse impact on subsistence harvests.
    
  • Small‑numbers determination: takes are less than 4 % of most stocks, 10 % for belugas.
    
• Adaptive Management:
  
  • Annual review of monitoring data to adjust mitigation or reporting if needed.
    
• Regulatory Context:
  
  • Deregulatory action under Executive Order 14192.
    
  • No significant economic impact on small entities (only Hilcorp is affected).
    
  • Paperwork reduction requirements approved under OMB control number 0648‑0151.

West Virginia Secures Federal‑State Authority Over Coal Mining on Public Lands

Overview

The U.S. Department of the Interior has finalized a cooperative agreement that expands West Virginia’s regulatory authority over surface coal mining and reclamation operations on federal lands within the state. The agreement, effective March 23 2026, amends the original 1984 arrangement to give the West Virginia Department of Environmental Protection (WVDEP) the primary responsibility for permitting, inspections, and enforcement, while the Office of Surface Mining Reclamation and Enforcement (OSMRE) retains oversight and coordination with federal agencies such as the Bureau of Land Management (BLM).

The new agreement clarifies that WVDEP may now regulate all coal‑exploration activities on federal lands—except those reserved for BLM under the Mineral Leasing Act—providing a more streamlined, state‑driven permitting process. Funding for the program comes from federal grants that cover the full cost of state administration, subject to appropriations, and the agreement includes detailed provisions for permit fees, penalties, and performance bonds that are deposited into state reclamation funds.

Overall, the rule is designed to reduce duplication between state and federal agencies, enhance environmental protection through consistent application of the Surface Mining Control and Reclamation Act (SMCRA), and maintain a clear framework for inspections, enforcement, and land‑use determinations. The Interior has determined that the rule will not impose significant economic burdens on small entities or create major environmental impacts.

Key Elements

• Effective Date – March 23 2026, following 30 days after publication in the Federal Register.
  
• Primary Authority – WVDEP administers the program; OSMRE provides oversight and coordination with federal agencies.
  
• Expanded Scope – WVDEP may regulate all coal‑exploration operations on federal lands (excluding BLM‑reserved activities).
  
• Funding – Federal grants cover the full cost of state administration, contingent on appropriations; no new unfunded mandates.
  
• Permit Process – WVDEP reviews and approves permits; OSMRE consults on leased federal coal; BLM handles leasing decisions.
  
• Fees & Penalties – Permit fees, civil and criminal penalties collected by WVDEP are deposited into state reclamation funds; bonds are required for all operations.
  
• Inspections & Enforcement – WVDEP conducts inspections; OSMRE may step in for federal enforcement; joint enforcement actions are coordinated.
  
• Land‑Use Determinations – Unsuitability petitions, valid existing rights (VER), and compatibility determinations are processed jointly by WVDEP and OSMRE.
  
• Administrative Flexibility – The agreement includes provisions for termination, reinstatement, and amendment by mutual agreement of the governor and the secretary.
  
• Impact Assessment – No significant economic impact on small businesses; no major environmental or regulatory burden beyond existing SMCRA requirements.

EIA Extends Nuclear Fuel Data Survey to Sharpen Spent‑Fuel Management

The U.S. Energy Information Administration (EIA) has announced a three‑year extension of its Form GC‑859, the Nuclear Fuel Data Survey. The extension, required under the Paperwork Reduction Act, will keep the survey in force through 2029 and introduces several refinements aimed at reducing respondent burden while improving data quality. The notice invites public comment until March 23, 2026, and is part of the Department of Energy’s ongoing effort to collect detailed information on spent nuclear fuel (SNF) from commercial reactors and other holders of irradiated fuel.

The survey gathers data on reactor operations, fuel assembly characteristics, and the disposition of SNF, including dry‑storage and pool‑storage inventories. The information feeds the Office of Nuclear Energy, the Office of Environmental Management, and national laboratories, supporting research on waste management options, safety analyses, and infrastructure planning. By clarifying definitions, removing redundant sections, and adding fields that capture both assembly‑average and maximum planar‑average enrichment, the EIA aims to provide a more accurate picture of SNF characteristics without imposing unnecessary paperwork on utilities.

Key Elements

• Three‑year extension of Form GC‑859 (OMB Control No. 1901‑0287) under the Paperwork Reduction Act.
  
• Revised instructions and definitions to reduce confusion and clarify data requirements.
  
• Removal of Section B.2 (reactor license data) because license status is publicly available from the NRC.
  
• Addition of optional field for assembly‑average initial enrichment to aid shielding and thermal analyses.
  
• Reinstatement of Section C.2 (projected assembly discharges) to capture planned changes in reactor operations and fuel types.
  
• Simplification of non‑fuel component reporting by moving NFC columns to the dry‑storage table and eliminating location tracking in pools.
  
• New column for damaged fuel canisters in the dry‑storage table to improve canister unloading clarity.
  
• Updated appendices with user‑friendly reactor and storage site names, and refined fuel assembly type codes.
  
• Estimated burden: 3,707 hours per year (~$352,000), with no additional costs beyond routine recordkeeping.
  
• Public comment deadline: March 23, 2026; comments can be submitted via email to GC859‑FRN‑Comments@pnnl.gov.

A New Small‑Scale Hydropower Project Opens Public Review in New Hampshire

Overview
The Federal Energy Regulatory Commission (FERC) has announced that Ashuelot River Hydro, Inc.’s application for a subsequent minor license for the Minnewawa Hydroelectric Project is ready for environmental analysis. The project, located on Minnewawa Brook in Marlborough, New Hampshire, involves a 245‑foot concrete dam that creates a 10‑acre reservoir and a 1,000‑kW Francis turbine. The company plans to continue operating the plant in a run‑of‑river mode, add a 75‑kW turbine, and install a tap‑and‑isolation valve on the existing penstock.

The notice invites public comments, recommendations, terms and conditions, and prescriptions. Comments must be filed by 5:00 p.m. Eastern Time on April 14, 2026, with reply comments due by May 29, 2026. FERC encourages electronic submissions through its eFiling system, but paper filings are also accepted. The application will undergo environmental review under the Federal Power Act, and the applicant must provide water‑quality certification or a waiver by the April deadline.

Key Elements
- Project Scope: 1,000‑kW turbine, 10‑acre reservoir, 155‑acre‑foot storage, 5,717‑ft penstock, 790‑ft tailrace.
- Proposed Additions: 75‑kW fixed‑geometry turbine and tap‑and‑isolation valve.
- Run‑of‑River Operation: Minimum downstream flow of 4 cfs or less than impoundment inflow.
- Location: Minnewawa Brook, Marlborough, Cheshire County, New Hampshire.
- Environmental Requirements: Water‑quality certification or waiver required by April 14, 2026.
- Public Comment Period: April 14 – May 29, 2026; electronic filing preferred.
- Procedural Schedule: Final amendments due March 16, 2026; environmental analysis to follow.
- Contact Information: FERC Secretary Debbie‑Anne A. Reese (888 First St NE, Washington, DC) and FERC Online Support (866‑208‑3676).

Central Valley Power Contractors to Fund Habitat Restoration Through New Billing Rules

Overview

The Central Valley Project Improvement Act of 1992 created a dedicated Restoration Fund to finance habitat restoration, improvement, and acquisition projects across California’s Central Valley. The Western Area Power Administration’s Sierra Nevada (WAPA‑SN) region has been tasked with collecting annual mitigation payments from Central Valley Project (CVP) power contractors and depositing those funds into the Restoration Fund. The new collection procedures, published in the Federal Register on February 20 2026, take effect on the first full billing period after April 1 2026 and remain in force until superseded.

These procedures outline how the Bureau of Reclamation determines each contractor’s Power Restoration Payment Obligation (PRPO), how WAPA‑SN allocates that obligation based on each contractor’s contractual Base Resource percentage, and how monthly bills are issued and collected. Contractors receive a bill on or about the 25th of each month, with payment due within 20 days. Late payments incur a 0.05 % daily charge, and all collected funds—including late charges—are transferred to the Restoration Fund by the 27th of the following month.

The policy also addresses special cases such as the exchange program, which can cause over‑ or under‑payments, and the exclusion of First Preference customers whose energy entitlements are tied to re‑operated facilities that already meet restoration requirements. WAPA‑SN will review the collection process every five years or if significant changes occur, ensuring continued fairness and compliance with environmental and regulatory standards.

Key Elements

• Restoration Fund: Dedicated account established under Section 3407 of the CVPIA to finance habitat projects.
  
• Power Restoration Payment Obligation (PRPO): Annual amount assigned by the Bureau of Reclamation to each CVP power contractor.
  
• Billing Cycle: Monthly bills issued around the 25th; payments due within 20 days; late charges of 0.05 % per day.
  
• Deposit Schedule: Funds transferred to the Restoration Fund by the 27th of the month following collection.
  
• Exchange Program Reconciliation: Annual true‑up in August to adjust for energy exchanged among contractors, ensuring accurate payment based on Base Resource percentages.
  
• First Preference Exclusion: Restoration payments are excluded for First Preference customers in areas where re‑operated facilities already satisfy restoration obligations.
  
• Review Process: Five‑year review or upon significant legislative or operational changes to maintain equity and compliance.
  
• Environmental Compliance: Classified as a categorical exclusion under DOE NEPA, requiring no environmental impact statement.
  
• Public Participation: 30‑day comment period in August 2025; no comments received.
  
• Effective Date: Procedures become active on the first full billing period after April 1 2026.

EPA Opens the Books on New Environmental Impact Statements: What It Means for Transit, Nuclear, and Mineral Projects

The U.S. Environmental Protection Agency (EPA) has announced the availability of several new Environmental Impact Statements (EISs) that were filed by other federal agencies between February 9 and February 13, 2026. Under the National Environmental Policy Act (NEPA) and Section 309(a) of the Clean Air Act, the EPA is required to review these documents and publicly post its comments. The notice, published in the Federal Register on February 20, 2026, lists three specific EISs: a transit expansion project in New York, a nuclear fuel fabrication facility in Tennessee, and a draft study on locatable minerals in the National Forest System.

This announcement underscores the EPA’s role as a watchdog and facilitator of public participation in federal environmental decision‑making. By making its comments available, the agency provides stakeholders—including local communities, industry groups, and environmental organizations—with insight into how federal projects may affect air quality, ecosystems, and resource use. The public comment period for the draft mineral study extends to April 21, 2026, giving interested parties ample time to weigh in before the final decision is made.

Key Elements

• Weekly Receipt Window: EPA received EISs filed from Feb 9–13, 2026, and will publish its comments within the same week.
  
• EISs Covered
  
  • 20260013: Final EIS for the Buffalo‑Amherst‑Tonawanda Corridor Transit Expansion Project (Federal Transit Administration, NY).
    
  • 20260014: Final EIS for the TRISO‑X Special Nuclear Material License Application (Nuclear Regulatory Commission, TN).
    
  • 20260015: Draft EIS on Locatable Minerals (U.S. Forest Service, National Forest System).
    
• Comment Period: The draft mineral study’s comment period ends April 21, 2026.
  
• Public Access: EPA’s comment letters are posted online at the EPA NEPA portal (https://cdxapps.epa.gov/cdx-enepa-II/public/action/eis/search).
  
• Legal Basis: The notice is grounded in the Clean Air Act’s Section 309(a) and NEPA’s requirement for federal agencies to consider environmental impacts.
  
• Contact Information:
  
  • Transit project: James A. Goveia, 212‑668‑2325.
    
  • Nuclear project: Jill Caverly, 301‑415‑7674.
    
  • Mineral study: Tracy Parker, 202‑644‑5974.
    
• Implications for Stakeholders: The EPA’s review can influence project design, mitigation measures, and ultimately the approval or modification of federal actions affecting air quality, land use, and resource extraction.

NOAA Grants Limited Marine‑Mammal Take for Pacific Ridge Survey

Overview

The U.S. National Marine Fisheries Service (NMFS) has issued an Incidental Harassment Authorization (IHA) to the Lamont‑Doherty Earth Observatory (L‑DEO) for a marine geophysical survey of the East Pacific Rise in the Eastern Tropical Pacific Ocean. The IHA permits the “take” (harassment) of small numbers of marine mammals that may be unintentionally disturbed by the survey’s seismic airgun array, but only under strict conditions that ensure a negligible impact on the species and their habitats.

The authorization is effective for one year from the date of notification (February 11 2026) and is subject to monitoring, reporting, and mitigation measures outlined in the IHA. NMFS determined that the activity meets the Marine Mammal Protection Act (MMPA) criteria for incidental take, and that it does not jeopardize endangered or threatened species, as confirmed by a Biological Opinion under the Endangered Species Act. The action also qualifies for a categorical exclusion under the National Environmental Policy Act, meaning no further environmental review is required.

This decision follows a December 2025 public notice in which NMFS presented its preliminary analysis and received no public comments. The final IHA retains the same species list, take estimates, and mitigation measures as the proposed notice, reflecting no new information that would alter the original conclusions.

Key Elements

• Authorized Activity: Marine geophysical survey of the East Pacific Rise using seismic airguns.
• Permit Holder: Lamont‑Doherty Earth Observatory (L‑DEO).
• Effective Period: 1 year from notification (Feb 11 2026) or issuance (Feb 17 2026), whichever is later.
• Species Covered: All marine mammals that may be present in the survey area; specific species and stock estimates are listed in the IHA.
• Take Limits: Incidental harassment only; no intentional capture or killing.
• Mitigation Measures: Minimum‑impact protocols, exclusion zones, real‑time monitoring of marine mammal presence, and shutdown procedures if animals enter restricted areas.
• Monitoring & Reporting: L‑DEO must log all take events, submit periodic reports to NMFS, and provide a final survey report.
• Environmental Review: Categorical exclusion under NEPA (no significant impact on human environment).
• ESA Compliance: Biological Opinion confirms no jeopardy to listed species (e.g., humpback, fin, sei, sperm, and blue whales).
• Public Access: Full IHA documents and supporting materials are available online via the NMFS Marine Mammal Protection portal.
• Contact: Jenna Harlacher, Office of Protected Resources, NMFS (301‑427‑8401).

Ampersand Hollow Dam to Be Decommissioned: Environmental Assessment Released

The Federal Energy Regulatory Commission (FERC) has announced the availability of an Environmental Assessment (EA) for the surrender and decommissioning of the Hollow Dam Hydroelectric Project (Project No. 6972) owned by Ampersand Hollow Dam Hydro LLC. The project, located on the West Branch of the Oswegatchie River near Fowler, New York, is not on federal land and has been in operation for several decades. The EA evaluates the environmental impacts of removing the power unit, de‑energizing the substation, and leaving the dam, fencing, portage, and parking area intact.

FERC’s analysis concludes that the proposed surrender, with recommended mitigation measures, would not constitute a major federal action under the National Environmental Policy Act (NEPA). The assessment notes that no ground disturbance is planned, and the remaining infrastructure will continue to serve local recreational and ecological functions. The EA is publicly available on FERC’s website and invites stakeholders to review the findings before the public comment period closes.

Stakeholders—including local residents, environmental groups, and industry partners—have until March 16, 2026, 5:00 p.m. Eastern Time to submit comments. FERC encourages electronic submissions via its eFiling and eComment systems, but paper comments may also be mailed to the Commission’s offices. The outcome of the comment process will inform FERC’s final decision on the surrender application.

Key Elements

• Project Details: Hollow Dam Hydroelectric Project (Project No. 6972), West Branch of the Oswegatchie River, Fowler, St. Lawrence County, NY.
• Proposed Action: Surrender of the license, removal of the power unit and control room equipment, de‑energization of the substation; dam, fencing, portage, and parking area remain.
• Environmental Assessment Findings: No major federal action; minimal environmental impact; no ground disturbance; existing infrastructure will continue to support local recreation and ecological functions.
• Public Comment Period: Open until March 16, 2026, 5:00 p.m. Eastern Time; electronic and paper submissions accepted.
• Access to EA: Available on FERC’s eLibrary (docket P‑6972) and in PDF format on the Commission’s website.
• Contact Information: Comments via eFiling/eComment; paper comments to Debbie‑Anne A. Reese, Secretary, FERC, Washington, DC (or Rockville, MD for other carriers).
• Regulatory Context: Action reviewed under 18 CFR part 380 and NEPA; Commission staff’s conclusion that the action is not a major federal action.

USGS Announces Public Landslide Advisory Committee Meetings in Asheville, NC

Overview

The U.S. Geological Survey (USGS) has issued a notice under the Federal Advisory Committee Act (FACA) to invite the public to attend the Advisory Committee on Landslides (ACL) meetings scheduled for March 4–5, 2026. The ACL, composed of at least 11 experts in landslide science and risk management, advises the Secretary of the Interior on the National Landslide Hazards Reduction Program (NLHRP). By holding these meetings in person and via web conference, the USGS seeks to ensure transparency, gather stakeholder input, and refine strategies to reduce landslide hazards across the United States.

The meetings will take place at the Flat Iron Hotel in Asheville, North Carolina, and will run from 9 a.m. to 5:30 p.m. on March 4 and from 9 a.m. to 5 p.m. on March 5 (Eastern Standard Time). Attendance requires pre‑registration—at least seven business days in advance for in‑person participants and three for virtual attendees—to secure building access or web‑conference instructions. The USGS encourages public comments, both oral and written, to be submitted at least three business days before the meeting.

The agenda will cover the outcomes of ACL subcommittees, final recommendations, updates on NLHRP activities, and briefings on the latest landslide hazard science. The committee’s work informs national policy and funding decisions that protect communities, infrastructure, and natural resources from landslide risks. Stakeholders, including scientists, local officials, and residents, are invited to contribute to this critical dialogue.

Key Elements

• Meeting Dates & Times

  • March 4, 2026: 9 a.m.–5:30 p.m.
    
  • March 5, 2026: 9 a.m.–5 p.m. (Eastern Standard Time)

• Location & Access

  • Flat Iron Hotel, 20 Battery Park Ave., Asheville, NC 28801
    
  • In‑person and web‑conference options available

• Registration Requirements

  • In‑person: pre‑register at least 7 business days prior
    
  • Virtual: pre‑register at least 3 business days prior
    
  • Contact Designated Federal Officer (DFO) for details

• Public Participation

  • Open to all U.S. residents; non‑citizens may need additional documentation
    
  • Oral comments limited by time; written comments accepted up to 3 business days before the meeting

• Accessibility & Accommodations

  • Requests for sign language interpreters, assistive listening, translation, or other services must be made at least 7 business days in advance

• Committee Purpose

  • Advise on landslide hazard reduction, review subcommittee work, finalize recommendations, and brief on science and risk mitigation

• Contact Information

  • Dr. Jonathan Godt, Landslide Hazards Program Coordinator
    
  • Email: jgodt@usgs.gov | Phone: (303) 905‑9468

• Legal Framework

  • Conducted under FACA, the Sunshine Act, and 41 CFR part 102‑3, ensuring public transparency and accountability.

BLM Eyes Reinstatement of Oil & Gas Leases in New Mexico’s Lea & Eddy Counties

Overview

The Bureau of Land Management (BLM) has issued a notice proposing to reinstate a series of competitive oil and gas leases that were terminated in Lea and Eddy counties, New Mexico. Under the Mineral Leasing Act of 1920, lessees who have paid the required rentals and met other statutory conditions may petition for reinstatement. The BLM received petitions from several companies—including FAE II LLC, Murchison Oil & Gas, Blackbeard Operating, MR NM Operating, V‑F Petroleum, Ridge Runner, David J. Disiere, and Coterra Energy—and is now evaluating whether to restore their rights to drill on federal lands.

If approved, the leases would resume under updated terms: a rental of $20 per acre (or fraction thereof) per year and a royalty rate of 20 percent. The lessees have also agreed to revised stipulations and have paid the necessary administrative fee. No other leases currently affect the lands in question, so reinstatement would not conflict with existing agreements.

The notice invites public comment and provides contact information for the BLM New Mexico State Office. Stakeholders—including local communities, environmental groups, and industry participants—can review the proposed changes and submit feedback within the statutory comment period.

Key Elements

• Leases Proposed for Reinstatement

  • NMNM 134896 (FAE) – effective Oct 1 2023
    
  • NMNM 134897 (FAE) – effective Oct 1 2023
    
  • NMNM 138884 (Murchison) – effective Nov 1 2019
    
  • NMNM 138885 (Blackbeard) – effective Nov 1 2020
    
  • NMNM 138887 (Blackbeard) – effective Nov 1 2020
    
  • NMNM 141006 (MR NM) – effective Jan 1 2024
    
  • NMNM 141409 (V‑F) – effective Jan 1 2024
    
  • NMNM 141418 (Ridge Runner) – effective Jan 1 2022
    
  • NMNM 142575 (Disiere) – effective Jun 1 2022
    
  • NMNM 105821017 (Coterra) – effective Jul 1 2024
    
  • NMNM 105821018 (Coterra) – effective Jul 1 2024
    

• Financial Terms

  • Rental: $20 per acre (or fraction) per year.
    
  • Royalty: 20 percent of gross revenue.
    

• Compliance and Conditions

  • Lessees have paid all accrued rentals and the BLM’s administrative fee.
    
  • Lessees have agreed to amended lease stipulations.
    
  • Reinstatement is subject to the original lease terms and the new rental/royalty rates.
    

• Administrative Details

  • Notice published in the Federal Register (91 FR 8269).
    
  • Contact: Ross Klein, Natural Resource Specialist, BLM New Mexico State Office.
    
  • Public comment period available; stakeholders can submit feedback through the BLM website or by contacting the office.
    

• Implications for Stakeholders

  • Potential for renewed drilling activity and associated economic benefits.
    
  • Environmental oversight remains governed by federal regulations and the BLM’s stewardship responsibilities.
    
  • Local communities and environmental groups have an opportunity to influence the decision through the comment process.

Gulf of America to Open New Offshore Oil & Gas Lease Sale – Public Comment Period Opens

Overview

The Bureau of Ocean Energy Management (BOEM) has announced the availability of a Proposed Notice of Sale (NOS) for the Gulf of America (GOA) Outer Continental Shelf Oil and Gas One Big Beautiful Bill Act (OBBBA) Lease Sale 3 (Lease Sale BBG3). This sale will offer new leasing opportunities for offshore oil and gas development in the Gulf of America, a region that is strategically important for U.S. energy production and maritime commerce.

The notice invites governors and local governments affected by the sale to submit comments on the proposed size, timing, and location of the lease area. Comments must be received by April 21, 2026. BOEM will publish a final NOS at least 30 days before the bid opening, which is scheduled for August 12, 2026. Interested parties can obtain the Proposed NOS and related documents from BOEM’s Gulf of America Region office or download them from the agency’s website.

This sale is governed by the OBBBA and the Outer Continental Shelf Lands Act, ensuring that lease terms, royalty rates, rental rates, and minimum bids meet federal requirements. The process provides an opportunity for stakeholders—including energy companies, environmental groups, and local communities—to influence the development of offshore resources while balancing economic, environmental, and social considerations.

Key Elements

• Sale Framework: Governed by the One Big Beautiful Bill Act (OBBBA) and the Outer Continental Shelf Lands Act.
  
• Lease Details: Proposed size, timing, and location of the lease area are outlined in the NOS.
  
• Financial Terms: Includes lease stipulations, royalty rates, rental rates, and minimum bid requirements.
  
• Comment Period: Governors and affected local governments must submit comments by April 21, 2026.
  
• Bid Opening: Scheduled for August 12, 2026; final NOS to be published at least 30 days prior.
  
• Information Access: Documents available at BOEM Gulf of America Region office (1201 Elmwood Park Blvd., New Orleans, LA) and online at boem.gov/Sale-BBG3.
  
• Contact Persons: Bridgette Duplantis (leasing supervisor) and Benjamin Burnett (leasing policy manager) for inquiries.
  
• Regulatory Authority: Notice issued under 30 CFR 556 and 43 U.S.C. 1331, ensuring compliance with federal leasing regulations.

Streamlining Mining on National Forests: New Rules for Locatable Minerals

Overview

The U.S. Forest Service has proposed a comprehensive update to its Part 228 regulations that govern mining on National Forest System (NFS) lands. The goal is to modernize permitting, increase transparency, and reduce surface‑resource impacts while ensuring the United States can secure critical minerals for defense, infrastructure, and clean‑energy technologies. The rule replaces 1974‑era guidance, incorporates lessons from a 2016 GAO review, and clarifies procedures for operations on lands withdrawn under the Wilderness or Wild‑and‑Scenic Rivers Acts.

The proposal introduces a three‑tier system—limited operations, operating notices, and plans of operations—based on clear thresholds (e.g., disturbance of more than five acres or non‑exploratory work). Operators must now hold a pre‑submittal meeting with a Forest Service officer, provide detailed information in notices or plans, and submit a financial assurance that covers reclamation costs. Interim management plans and mineral‑classification reports are required for certain activities, and enforcement tools such as suspension orders and forfeiture of financial assurance are clarified.

These changes are expected to cut the number of full‑plan reviews by about 62 operations per year, align Forest Service rules more closely with Bureau of Land Management regulations, and provide a clearer, faster pathway for responsible mining while protecting surface resources, tribal interests, and ecological values.

Key Elements

• Three‑tier operational framework

  • Limited operations (minimal, non‑disruptive activities) exempt from prior notice.
    
  • Operating notices for work disturbing ≤5 acres, ≤1,000 tons, or exploratory projects; valid up to six years with extensions.
    
  • Plans of operations required for larger or more complex projects; include maps, schedules, reclamation, monitoring, and financial assurance.

• Pre‑submittal meetings

  • Mandatory discussion with a Forest Service officer to review land status, surface‑resource protection, and applicable laws before filing a notice or plan.

• Enhanced notice and plan requirements

  • Detailed equipment lists, justification of mining activity, schedule, reclamation plan, cost estimate, and compliance with surface‑resource standards.

• Interim management plans

  • Required for any temporary shutdowns, outlining stabilization, hazardous‑material control, and financial assurance status.

• Financial assurance and trust‑fund rules

  • Annual or as‑needed review of reclamation cost estimates; adjustments to bonds, letters of credit, or trust funds; forfeiture procedures for non‑compliance.

• Mineral‑classification and escrow provisions

  • Interim operations on segregated or withdrawn lands require a mineral‑classification report; removed material held in escrow until classification is complete.

• Enforcement tools

  • Written notices, suspension orders, immediate suspension for imminent harm, and civil action options to protect surface resources and public health.

• Stakeholder engagement

  • Early coordination with tribes, state, and local agencies; clear guidance on incidental activities and surface‑resource protection standards.

These provisions collectively aim to streamline the permitting process, enhance transparency, and safeguard environmental and cultural resources while enabling the development of locatable minerals on National Forest lands.

Rescinding the 2024 Ten‑Day Notice Rule: A Return to the 2020 Framework

Overview

The Office of Surface Mining Reclamation and Enforcement (OSMRE) has rescinded the “Ten‑Day Notices and Corrective Action for State Regulatory Program Issues” rule issued in April 2024. The new final rule, effective March 23, 2026, largely restores the 2020 rule that governs how the federal government can issue ten‑day notices (TDNs) to state regulators and how it can conduct federal inspections of surface‑coal mining operations. The change is intended to streamline oversight, reduce duplication between federal and state enforcement, and reinforce the principle that states retain primary jurisdiction over mining activities on non‑federal, non‑Indian lands.

The rescission clarifies several key aspects of the SMCRA (Surface Mining Control and Reclamation Act) enforcement process. It restores the ability of OSMRE to consider “any information readily available”—including data from state regulators—when deciding whether it has a “reason to believe” a violation exists. It also re‑establishes the requirement that citizens who request a federal inspection must first notify the state regulator, preserving the cooperative federalism framework that SMCRA was designed to support. The rule maintains the use of action plans to address state‑program issues while ensuring that site‑specific violations can still trigger a TDN and, if necessary, a federal inspection.

Overall, the final rule seeks to balance federal oversight with state primacy, reduce administrative burdens on both federal and state agencies, and provide clearer guidance for citizens, operators, and regulators involved in surface‑coal mining and reclamation.

Key Elements

• Rescission of the 2024 rule – The 2024 rule is largely repealed; the 2020 rule is reinstated with minor updates.
  
• Re‑establishment of the “reason to believe” standard – OSMRE may use any readily available information, including state‑regulator data, to determine whether a violation exists.
  
• Citizen complaint process – Citizens must notify the state regulator before or simultaneously with filing a federal inspection request; the request must state why the regulator has not acted.
  
• Ten‑day notice (TDN) procedure – TDNs are issued only when OSMRE has a reason to believe a violation exists; the state regulator has ten days to respond with appropriate action or good cause.
  
• Action plans for state‑program issues – When a state program issue is identified, OSMRE may develop an action plan; if the issue is not resolved within 180 days, the plan is implemented.
  
• Federal inspections – OSMRE may conduct inspections when a violation is identified or when a state regulator fails to act within the TDN period.
  
• Clarified definitions – The rule removes the 2024 definitions of “citizen complaint” and “ten‑day notice” from § 842.5, aligning the regulations with SMCRA’s statutory language.
  
• Cooperative federalism emphasis – The rule reinforces that states have exclusive jurisdiction over permitting and enforcement, while the federal government retains oversight for violations and programmatic issues.
  
• No new information‑collection burden – The rule does not add new paperwork requirements for citizens, operators, or state regulators.
  
• Effective date – The rescission takes effect on March 23, 2026, after a 30‑day notice period.

BLM Removes Hardrock Acreage Limits, Streamlining Mineral Leasing

Overview

The U.S. Bureau of Land Management (BLM) has finalized a rule that eliminates the statewide acreage cap on hard‑rock mineral permits and leases, as well as the regulatory framework that previously required development contracts for such operations. The change, effective March 23 2026, follows a direct‑final rule issued in July 2025 and a substantive comment received in August 2025. By removing the cap, the BLM allows a single entity to hold as much hard‑rock mineral acreage as needed within a state, without the need for separate development contracts or processing agreements.

The policy does not authorize new mining activities; it merely rescinds administrative limits that were not mandated by statute. The BLM maintains that environmental safeguards remain in place: each prospecting permit or lease proposal will still undergo the required environmental reviews under the National Environmental Policy Act (NEPA), the Federal Water Pollution Control Act, and the Endangered Species Act. The agency argues that the removal of the acreage limitation will not hinder compliance with these laws.

For stakeholders in the geoscience, energy, and mineral‑resource sectors, the rule represents a shift toward greater flexibility in land‑use planning and project development. It also underscores the BLM’s willingness to adjust regulations in response to stakeholder feedback while preserving its environmental review obligations.

Key Elements

• Rescission of 43 CFR 3503.37(f): Eliminates the statewide acreage limit on hard‑rock mineral permits and leases.
  
• Removal of 43 CFR Subpart 3517 (Sections 3517.10‑3517.16): Cancels the requirement for hard‑rock mineral development contracts that previously provided an exemption from the acreage cap.
  
• No New Permits Issued: The rule does not create new leasing authority; it only removes existing limits.
  
• Continued Environmental Review: All prospecting permits and lease proposals remain subject to NEPA, the Federal Water Pollution Control Act, and the Endangered Species Act.
  
• Effective Date: The rescission takes effect on March 23 2026, following the confirmation of the July 2025 direct‑final rule’s effective date of September 15 2025.
  
• Stakeholder Input: The rule was issued in response to a substantive comment, demonstrating the BLM’s engagement with industry and environmental groups.
  
• Administrative Flexibility: By allowing entities to hold larger acreage blocks, the BLM aims to reduce regulatory burden and streamline hard‑rock mineral development processes.

U.S. Flags Russian Palladium as Undervalued: Trade Action Takes Shape

Overview

Palladium, a rare transition metal prized for its catalytic properties in automotive exhaust systems, electronics, and emerging hydrogen‑fuel technologies, is a critical component of the global supply chain for clean‑energy and high‑tech industries. In recent years, Russia has become a major exporter of unwrought palladium—raw material in forms such as ingots, blocks, and pellets—making it a focal point for U.S. trade policy.

On February 19 2026, the U.S. Department of Commerce’s International Trade Administration announced a preliminary affirmative determination that unwrought palladium from the Russian Federation is being sold in the United States at less‑than‑fair value (LTFV). The investigation covers sales from January 1 through June 30 2025 and estimates a weighted‑average dumping margin of 132.83 %. To protect U.S. industry while the case proceeds, Customs and Border Protection will suspend liquidation of the subject merchandise and require a cash deposit equal to the calculated dumping margin.

The determination is part of a broader antidumping investigation that will culminate in a final decision within 75 days. If the final determination is affirmative, the U.S. International Trade Commission will assess whether imports are materially injuring U.S. industry. Interested parties—including manufacturers, exporters, and trade associations—have 30 days to submit case briefs, and may request a hearing within the same period. The action underscores the U.S. commitment to safeguarding domestic supply chains for critical metals amid geopolitical tensions and supply‑chain uncertainties.

Key Elements

• Scope: Unwrought palladium in any primary form (ingots, blocks, pellets, etc.), regardless of production method, including recycled material and commingled products.
  
• Dumping Margin: Estimated weighted‑average dumping margin of 132.83 % for the Russia‑wide entity.
  
• Suspension of Liquidation: Customs will suspend liquidation of the subject merchandise from the date of publication until further notice.
  
• Cash Deposit Requirement: Importers must provide a cash deposit equal to the dumping margin (no adjustment for subsidies yet).
  
• No Separate Rates: No respondents applied for separate rates; thus, a single Russia‑wide rate applies.
  
• Verification: No verification will be conducted because the respondent was deemed uncooperative.
  
• Timeline: Final determination due within 75 days; ITC notification follows if the final determination is affirmative.
  
• Public Participation: 30‑day window for case briefs, rebuttals, and hearing requests.
  
• Implications for Trade: Potential tariffs and cash deposit requirements could raise costs for U.S. manufacturers and downstream industries that rely on palladium.

Hudson River Reserve Gets a Public Review: NOAA Calls for Input

Overview

The National Oceanic and Atmospheric Administration (NOAA) has announced a virtual public meeting to gather feedback on the upcoming performance evaluation of the Hudson River National Estuarine Research Reserve (HRNERR). The meeting, scheduled for April 15 2026 from 12 p.m. to 1 p.m. Eastern Time, will allow stakeholders—scientists, local residents, and interested parties—to share observations and concerns that will shape the final assessment. Written comments are also welcome and must be submitted by April 24 2026.

The evaluation is mandated by Section 315(f) of the Coastal Zone Management Act (CZMA). NOAA will review how the New York State Department of Environmental Conservation has met national objectives, adhered to the reserve’s management plan, and complied with CZMA financial assistance terms. Findings will be published in the Federal Register once the review is complete, ensuring transparency and public accountability.

This notice invites broad participation, emphasizing that NOAA values input from a diverse range of perspectives to inform the reserve’s future stewardship and research priorities.

Key Elements

• Meeting Details

  • Date & time: April 15 2026, 12 p.m.–1 p.m. ET (virtual).
    
  • Registration required by April 14 2026, 5 p.m. ET via the provided Google form.
    
  • Speakers listed in order of registration; anonymity allowed.

• Comment Submission Options

  • Oral comments during the virtual meeting.
    
  • Written comments via email to Carrie Hall (czma.evaluations@noaa.gov) with subject “Comments on Performance Evaluation of Hudson River Reserve.”
    
  • Deadline for written comments: April 24 2026.

• Evaluation Scope

  • Assesses compliance with CZMA Section 315(f) and the reserve’s management plan.
    
  • Considers New York State Department of Environmental Conservation’s performance and financial assistance terms.
    
  • Final findings to be released in the Federal Register.

• Legal Basis & Authority

  • Coastal Zone Management Act, Section 315(f).
    
  • NOAA’s Office for Coastal Management oversees the process under 16 U.S.C. 1451 et seq.

• Access to Information

  • Previous evaluation findings, management plan, site profile, and progress reports available on NOAA’s website or by request from Carrie Hall.
    
  • Final evaluation results will be published in the Federal Register after completion.

California Expands Disaster Aid to Marin County After January Storms

The U.S. Small Business Administration (SBA) has amended its administrative declaration of disaster for California, adding Marin County as a primary area affected by the early‑January 2026 storm, tidal flooding, and king tides. The amendment, published in the Federal Register on February 19 2026, extends the original declaration (dated February 3 2026) to include the new county while keeping all other provisions unchanged. The incident period covered is December 31 2025 through January 5 2026, and the disaster is identified as CA‑20039.

This update is part of the SBA’s broader disaster assistance program, which offers both physical and economic injury disaster loans (EIDL) to small businesses. The amendment specifies new application deadlines: physical loan applications must be submitted by April 6 2026, and EIDL applications by November 3 2026. Businesses can apply through the MySBA Loan Portal.

Key Elements - Incident: Early January 2026 storm, tidal flooding, and king tides.
- Incident Period: December 31 2025 – January 5 2026.
- Affected Areas: Marin County (primary); Contra Costa, San Francisco, and Sonoma counties (contiguous).
- Disaster Number: CA‑20039.
- Loan Deadlines: Physical loans by April 6 2026; EIDL loans by November 3 2026.
- Agency: U.S. Small Business Administration, Office of Disaster Recovery & Resilience.
- Publication: Notice issued in the Federal Register (91 FR 8053).
- Scope: The amendment expands the geographic coverage of the disaster declaration without altering other eligibility or assistance criteria.

Southern Ute Tribe Seeks Energy Autonomy: Final TERA Submitted to Interior Department

Overview

The U.S. Department of the Interior’s Bureau of Indian Affairs has announced that it has received a final proposed Tribal Energy Resource Agreement (TERA) from the Southern Ute Indian Tribe of the Southern Ute Reservation in Colorado. A TERA is a legal instrument that allows a federally recognized tribe to negotiate and manage energy‑related leases, business agreements, and rights‑of‑way on its own lands, thereby advancing tribal self‑determination in the energy sector.

Under the Indian Tribal Energy Development and Self‑Determination Act of 2005 (amended in 2017), the Southern Ute Tribe has applied to enter into a TERA that will give it discretion to develop renewable and non‑renewable energy projects, secure partnerships with private companies, and control the use of its land for energy infrastructure. The agreement is currently in the final review stage, and the Secretary of the Interior must approve or disapprove it within 270 days of receipt.

The notice invites public comment on the final proposed TERA and any related National Environmental Policy Act (NEPA) reviews. Comments are due by March 23, 2026, and can be submitted via email or mail to the Bureau of Indian Affairs. The outcome of this review will determine whether the Southern Ute Tribe can proceed with its energy development plans and how it will shape the economic and environmental future of the reservation.

Key Elements

• Legal Basis: Indian Tribal Energy Development and Self‑Determination Act of 2005, amended 2017.
  
• Purpose of TERA: Grants tribes authority to negotiate energy leases, business agreements, and rights‑of‑way on tribal lands.
  
• Timeline: Secretary must approve or disapprove within 270 days; if no action, the TERA becomes effective on the 271st day.
  
• NEPA Review: The Secretary is conducting an environmental assessment and soliciting public input under the National Environmental Policy Act.
  
• Comment Period: Open until March 23, 2026; submissions accepted by email (TERA@bia.gov) or mail to 13922 Denver West Parkway, STE350, Lakewood, CO 80401.
  
• Contact: Ms. Johnna Blackhair, Deputy Bureau Director, Office of Trust Services, Washington, DC 20240.
  
• Implications for Geoscience & Energy: Enables the Southern Ute Tribe to manage natural resource development, potentially influencing local energy markets, land use, and environmental stewardship.

ITC Rescinds Import Ban on Diamond‑Based Materials After Settlement

The U.S. International Trade Commission (ITC) has concluded a modification proceeding that rescinds a limited exclusion order (LEO) previously imposed on Shenzhen Haimingrun Superhard Materials Co., Ltd. (Haimingrun). The LEO had barred the company from importing certain polycrystalline diamond compacts and articles that infringed U.S. patents. A settlement agreement between Haimingrun and US Synthetic Corporation (USS) granted Haimingrun a license to the relevant patents, effectively eliminating the infringement concern. The ITC therefore removed Haimingrun from the LEO and terminated the modification proceeding.

This action follows a lengthy investigation under Section 337 of the Tariff Act, which examines whether imported products infringe U.S. patents and harm domestic industry. After a series of hearings, the ITC found that the patents in question were invalid or ineligible, and ultimately determined that Haimingrun had violated the law. The settlement resolved the dispute, allowing Haimingrun to resume trade in the affected products without the previous import ban.

Key Elements - Limited Exclusion Order (LEO): Initially prohibited Haimingrun from importing diamond compacts that infringed specific U.S. patents. - Settlement Agreement: Grants Haimingrun a license to the patents, removing the infringement issue. - Modification Proceeding: ITC institutes a proceeding to rescind the LEO based on the settlement. - Limited Service of Confidential Exhibit: The ITC allows the unredacted settlement agreement to be served only to USS and Haimingrun, protecting sensitive information. - Termination of Proceeding: The modification proceeding is closed once the LEO is amended and the settlement is acknowledged. - Implications for Trade: Haimingrun can now legally import the previously banned diamond products, potentially affecting supply chains and market dynamics in advanced materials.

Tongass National Forest Plan Gets a 30‑Year Overhaul

Overview

The U.S. Forest Service is revising the Tongass National Forest Land and Resource Management Plan, the governing document for the world’s largest national forest. The current plan, last updated in 1997, will be replaced with a new version that reflects nearly three decades of ecological change, new scientific data, and evolving economic priorities in Southeast Alaska. The revision will guide decisions on timber harvest, fisheries, recreation, and subsistence use for the next 10–15 years, while ensuring compliance with federal laws such as the National Forest Management Act and the Alaska National Interest Lands Conservation Act.

Public input is a key part of the process. Comments are accepted through March 20, 2026, and the Forest Service will use this feedback to shape a draft plan and an accompanying Environmental Impact Statement (EIS). The draft plan and EIS are expected in fall 2026, with a 90‑day comment period, and the final documents should be available by May 2027. The revision will also consider the status of roadless areas and the potential removal of road‑construction restrictions that have been a long‑standing issue for the Tongass.

The plan revision is designed to balance multiple uses—timber, tourism, fisheries, and subsistence—while protecting ecological integrity and cultural resources. It will incorporate indigenous knowledge, streamline management areas, and update timber and watershed science to support sustainable resource use and climate resilience.

Key Elements

• Timeline & Public Participation

  • Scoping period: 02 18 – 03 20 2026.
    
  • Draft plan & EIS: Fall 2026; final documents: May 2027.
    
  • Comments accepted via webform or hard copy; objections possible after substantive comments.

• Scope of Revision

  • Update and simplify the 30‑year‑old plan, reducing overlapping land‑use designations.
    
  • Integrate new science on timber demand, climate impacts, and watershed health.
    
  • Address the 1990 Tongass Timber Reform Act and Alaska National Interest Lands Conservation Act provisions.

• Management Focus Areas

  • Timber: Reassess suitability, sustain yield limits, and balance old‑growth protection with commercial harvest.
    
  • Fisheries & Watersheds: Protect salmon habitats, manage riparian zones, and evaluate impacts of roadless area changes.
    
  • Recreation & Tourism: Adapt to growing cruise‑ship traffic, emerging recreation technologies, and seasonal use patterns.
    
  • Subsistence & Indigenous Knowledge: Ensure continued access for hunting, fishing, and gathering; incorporate tribal and Alaska Native Corporation input.
    
  • Ecological & Climate Resilience: Evaluate risks of flooding, landslides, and temperature shifts; promote habitat connectivity.

• Alternatives & Decision Framework

  • “No‑action” alternative (retain current plan).
    
  • Multiple management‑area scenarios (General Forest, High‑Use Recreation, Old‑Growth Habitat, Conservation Watersheds, etc.).
    
  • Decision guided by economic, ecological, fisheries, subsistence, recreation, and designated‑area impacts.

• Regulatory Context

  • Consistent with the 2012 Planning Rule, National Forest Management Act, and Executive Orders 14153 & 14225.
    
  • Potential interaction with the proposed rescission of the 2001 Roadless Rule, which could affect road construction and timber harvesting in inventoried roadless areas.

• Stakeholder Engagement

  • Cooperation with State of Alaska, local boroughs, EPA, tribal governments, and Alaska Native Corporations.
    
  • Public meetings, webinars, and electronic outreach to gather diverse perspectives.

This revision will shape how the Tongass National Forest is managed for the next decade, balancing resource use with conservation and cultural stewardship in a rapidly changing environmental and economic landscape.

Savannah River Site Opens Its Advisory Board to the Public: A Call for Input on Cleanup and Land Stewardship

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 Savannah River Site (SRS). The board serves as an independent advisory body that reviews and recommends actions on cleanup, waste and nuclear material management, excess facility disposition, future land use, and long‑term stewardship of the site. Its work supports federal environmental laws such as NEPA, CERCLA, and RCRA, ensuring that cleanup decisions are transparent and scientifically sound.

The meeting will take place on Tuesday, March 24, 2026, from 9 a.m. to 4 p.m. EDT at the Advanced Manufacturing Collaborative in Aiken, South Carolina, and will also be streamed live on YouTube. No registration is required, and the board welcomes public attendance and written or oral comments. Minutes and additional information will be posted on the SRS website.

This notice underscores the DOE’s commitment to public participation in environmental decision‑making at a site that has historically managed nuclear materials and contaminated sites. By inviting community input, the board aims to refine cleanup strategies, improve waste handling, and shape future land use in a way that protects public health and the environment.

Key Elements

• Purpose of the EM SSAB: Advise on cleanup activities, waste and nuclear material management, excess facilities, future land use, and long‑term stewardship; fulfill NEPA, CERCLA, RCRA, and other federal public‑participation requirements.
  
• Meeting Details:
  
  • Date & Time: March 24, 2026, 9 a.m.–4 p.m. EDT
    
  • Location: Advanced Manufacturing Collaborative, 4345 Trolley Line Road, Aiken, SC
    
  • Livestream: YouTube channel @SRSCAB/streams
    
• Agenda Highlights (subject to change): Chair update, agency updates, program presentations, board business, public comments.
  
• Public Participation:
  
  • 15 minutes for oral comments (minimum 2 min per speaker).
    
  • Written comments accepted at least two working days before or after the meeting.
    
  • Contact for comments: srscitizensadvisoryboard@srs.gov.
    
• Accessibility: Board will accommodate persons with disabilities; requests should be made at least seven days in advance.
  
• Minutes & Records: Available at www.cab.srs.gov.
  
• Contact Information: James Tanner, Office of External Affairs, Savannah River Operations Office (phone: 803‑646‑2167, email: james.tanner@srs.gov).

DOE Opens Virtual Session to Guide Northern New Mexico’s Clean‑Up and Land‑Use Decisions

The Department of Energy’s Office of Environmental Management has announced a virtual meeting of the Environmental Management Site‑Specific Advisory Board (EM SSAB) for Northern New Mexico. The board is a federally mandated advisory committee that advises on cleanup activities, waste and nuclear material management, excess facility disposition, future land use, and long‑term stewardship of DOE sites. Its recommendations help shape the application of the National Environmental Policy Act, CERCLA, RCRA, and other environmental statutes in the region.

The meeting will take place on Thursday, March 19, 2026, from 1 p.m. to 4 p.m. MDT. It is open to the public, with opportunities for oral and written comments. Participants can request virtual access and special accommodations by contacting the board’s executive director at least two days before the meeting. Minutes and additional information will be posted on the DOE website.

For geoscientists, energy and mineral resource professionals, and local stakeholders, the board’s work directly influences how contaminated sites are remediated, how nuclear and hazardous wastes are handled, and how former DOE facilities can be repurposed. The meeting offers a chance to shape policies that balance environmental protection, public health, and sustainable land use in a region with a complex legacy of federal energy activities.

Key Elements

• Purpose of the Board: Advise on cleanup, waste management, excess facilities, future land use, and long‑term stewardship of DOE sites in Northern New Mexico.
  
• Meeting Details: Virtual session on March 19, 2026, 1–4 p.m. MDT; access information provided by the board’s executive director.
  
• Public Participation: Open to all; 15 minutes for oral comment, written comments accepted up to two days before or after the meeting.
  
• Agenda Highlights: Presentations, agency updates, and discussion of site‑specific issues; agenda subject to change.
  
• Legal Framework: Board operates under the Federal Advisory Committee Act and supports compliance with NEPA, CERCLA, RCRA, and related agreements.
  
• Accessibility: Accommodations for disabilities available; requests should be made at least seven days prior.
  
• Documentation: Minutes and meeting materials will be posted on the DOE website for public review.

Michigan Hydropower Project Gets One‑Year Window to Secure Water Quality Approval

The Federal Energy Regulatory Commission (FERC) has issued a notice concerning a water‑quality certification request for a proposed hydropower project in Charter Township of Van Buren, Michigan. The request, submitted by STS Hydropower, LLC and the township, was received by the Michigan Department of Environment, Great Lakes, and Energy (EGLE) on February 3, 2026. Under the Clean Water Act, EGLE must review and either approve or deny the certification within a “reasonable period of time,” which FERC has defined as one year.

This certification is a prerequisite for the project’s environmental assessment and licensing process. If EGLE fails to act within the specified period, the certification is deemed waived, allowing the project to proceed without the formal approval. The waiver provision underscores the importance of timely environmental review and the potential for accelerated development of renewable energy infrastructure.

Stakeholders—including local communities, environmental groups, and the hydropower industry—will monitor EGLE’s decision closely. The outcome will influence the project’s compliance with federal water‑quality standards, its environmental impact assessment, and the broader trajectory of clean‑energy development in the region.

Key Elements

• Project and Parties: STS Hydropower, LLC and Charter Township of Van Buren, Michigan.
  
• Certification Request Received: February 3, 2026.
  
• Reasonable Period of Time: One year, ending February 3, 2027.
  
• Authority: Michigan Department of Environment, Great Lakes, and Energy (EGLE).
  
• Clean Water Act Basis: Section 401(a)(1) certification under 33 U.S.C. 1341(a)(1).
  
• Waiver Provision: If EGLE does not act by the deadline, the certification is deemed waived, allowing the project to proceed without formal approval.
  
• Implications: Affects environmental assessment, licensing schedule, and compliance with federal water‑quality standards.

Lake Lynn Hydroelectric Project Relicensing: Environmental Assessment Made Public

Overview

Lake Lynn Generation, LLC has submitted a request to the Federal Energy Regulatory Commission (FERC) to renew the operating license for its 51.2‑megawatt hydroelectric plant on the Cheat River, straddling West Virginia and Pennsylvania. The plant has supplied clean, renewable power to the region since the 1970s and is a key component of the local energy mix.

FERC’s Office of Energy Projects has completed an Environmental Assessment (EA) under the National Environmental Policy Act (NEPA). The EA evaluates the potential environmental effects of continuing to operate the facility and concludes that, with appropriate protective measures, relicensing would not constitute a major federal action that would significantly affect the quality of the human environment. The assessment identifies specific mitigation strategies—such as fish passage improvements and water‑quality monitoring—to address identified impacts.

The notice invites public participation: comments on the EA must be submitted by 5:00 p.m. Eastern Time on March 13, 2026. The EA is available online through FERC’s eLibrary and can be accessed by entering the docket number (P‑2459‑279). Stakeholders—including local communities, environmental groups, and industry participants—can review the assessment, propose additional safeguards, or raise concerns before the Commission finalizes the relicensing decision.

Key Elements

• Project Scope: 51.2‑MW hydroelectric plant on the Cheat River, serving West Virginia and Pennsylvania.
  
• Regulatory Context: Relicensing under 18 CFR part 380, reviewed pursuant to NEPA.
  
• EA Findings: Relicensing deemed not a major federal action; environmental impacts can be mitigated.
  
• Mitigation Measures: Fish passage enhancements, water‑quality monitoring, habitat restoration.
  
• Public Comment Window: Deadline March 13, 2026; submissions via FERC eFiling or QuickComment.
  
• Access to EA: Available online via FERC eLibrary (docket P‑2459‑279) and in PDF form on govinfo.gov.
  
• Implications for Energy & Environment: Continuation of renewable power generation with safeguards for aquatic ecosystems and water quality.
  
• Contact Points: FERC Online Support, Office of Public Participation, and Secretary Debbie‑Anne A. Reese for inquiries.

EPA Eyes Cleaner Alaska: A Programmatic Plan to Tackle Legacy Contamination on Native Lands

Overview

The U.S. Environmental Protection Agency (EPA) Region 10 has announced its intent to prepare a programmatic Environmental Assessment (EA) under the National Environmental Policy Act (NEPA) for the Contaminated Alaska Native Claims Settlement Act (ANCSA) Lands Assistance Program. The program, funded by Congress, provides grants to Alaska Native regional and village corporations, federally recognized tribes, and other eligible entities to assess and remediate contamination that existed on ANCSA‑conveyed lands at the time of transfer. Contaminants include arsenic, asbestos, lead, mercury, pesticides, PCBs, and petroleum products, posing risks to human health, wetlands, and subsistence resources vital to Alaska Native communities.

In addition to the EA, EPA is initiating a public scoping process and a Section 106 consultation with the Alaska State Historic Preservation Officer (SHPO). The goal is to develop a Section 106 Programmatic Agreement that will streamline the identification, evaluation, and mitigation of impacts on historic properties, archaeological sites, sacred places, and traditional cultural landscapes. The agreement will also establish protocols for inadvertent discovery, confidentiality of sensitive cultural information, and coordination with federal partners such as the U.S. Army Corps of Engineers and the State of Alaska.

The scoping period runs from the notice’s publication until March 20, 2026, inviting comments on potential environmental and sociocultural impacts, reasonable alternatives, and mitigation measures. By creating a programmatic framework, EPA aims to reduce regulatory burdens for grant recipients while ensuring compliance with NEPA, the National Historic Preservation Act, the Clean Water Act, and other relevant statutes. The initiative underscores a commitment to balancing environmental cleanup with the protection of Alaska’s unique cultural and natural heritage.

Key Elements

• Programmatic EA under NEPA: Evaluates representative cleanup actions funded by the ANCSA Lands Assistance Program, determining whether a Finding of No Significant Impact (FONSI) or a full Environmental Impact Statement (EIS) is required.
  
• Section 106 Consultation: EPA is consulting with the Alaska SHPO, federally recognized tribes, and Alaska Native corporations to address historic and cultural resource impacts.
  
• Programmatic Agreement: A forthcoming agreement will set standards for identifying, evaluating, and mitigating effects on historic properties, archaeological sites, sacred sites, and traditional cultural places.
  
• Public Scoping: Stakeholders can submit comments on environmental, cultural, and subsistence impacts, as well as propose alternatives or mitigation measures, until March 20, 2026.
  
• Cooperating Agencies: Includes the U.S. Army Corps of Engineers (for Clean Water Act Section 404 permitting and archaeological expertise), the State of Alaska, and other federal partners.
  
• Focus Areas:
  
  • Archaeological and cultural resources (sacred sites, traditional cultural places).
    
  • Protected subsistence resources (fish, wildlife, marine mammals).
    
  • Wetlands and aquatic resources (hydrology, habitat, water quality).
    
  • Sociocultural and community considerations (public health, equity, community engagement).
    
• Regulatory Streamlining: The programmatic approach aims to reduce the complexity of environmental reviews for grant recipients, while maintaining rigorous protection of Alaska’s environmental and cultural assets.

Tennessee Winter Storm Declared Major Disaster: SBA Opens Door to Relief for Affected Communities

The U.S. President has officially declared a major disaster for the state of Tennessee, triggered by a severe winter storm that struck the region from January 22 to January 27, 2026. The declaration, issued on February 6, 2026, authorizes the Small Business Administration (SBA) to provide public assistance loans to private non‑profit organizations and other eligible entities that suffered physical damage or economic injury during the storm. The focus is on restoring essential services and infrastructure—roads, utilities, and public facilities—critical for the state’s recovery and resilience.

Under this declaration, affected counties—including Davidson, Cheatham, and Hardin, among others—can apply for two types of SBA disaster loans: Physical Damage Loans and Economic Injury Disaster Loans (EIDL). The SBA has set clear application deadlines: April 7, 2026 for physical damage loans and November 6, 2026 for EIDLs. Interest rates for both loan categories are set at 3.625 %, regardless of the borrower’s prior credit availability. The SBA encourages applicants to use the MySBA Loan Portal or local SBA offices for assistance, and provides dedicated contact channels for those with disabilities.

Key Elements

• Declaration Details

  • President’s major disaster declaration (FEMA‑4898‑DR)
    
  • Incident period: January 22–27, 2026
    
  • Affected counties: Davidson, Cheatham, Chester, Clay, Hardin, Henderson, Hickman, Lewis, Macon, McNairy, Perry, Sumner, Trousdale, Wayne, Williamson
    

• Loan Programs

  • Physical Damage Loans (catalog number 21436B)
    
  • Economic Injury Disaster Loans (catalog number 214370)
    

• Application Deadlines

  • Physical Damage Loans: April 7, 2026
    
  • EIDL: November 6, 2026
    

• Interest Rates

  • 3.625 % for all loan types, regardless of credit availability
    

• Application Process

  • Online via MySBA Loan Portal (https://lending.sba.gov)
    
  • In‑person assistance at locally announced SBA locations
    

• Contact Information

  • Sharon Henderson, Office of Disaster Recovery & Resilience, SBA
    
  • Phone: (202) 205‑6734 | Email: disastercustomerservice@sba.gov
    
  • 1‑800‑659‑2955 (with 711 relay for hearing‑impairment support)
    

• Additional Resources

  • Official PDF: https://www.govinfo.gov/content/pkg/FR-2026-02-18/pdf/2026-03134.pdf
    
  • SBA Disaster Assistance Customer Service Center for further guidance.

China’s Aluminum Foil Subsidy Verdict: U.S. Imposes High Countervailing Duties

Overview

The U.S. Department of Commerce’s International Trade Administration has finalized an administrative review of countervailing duties (CVDs) on aluminum foil imported from the People’s Republic of China for the 2023 period. Countervailing duties are tariffs imposed to offset subsidies that foreign producers receive from their governments, ensuring a level playing field for U.S. competitors. The review examined whether Chinese exporters and producers of aluminum foil received government‑provided financial contributions that gave them an unfair advantage in the U.S. market.

The final results reveal that two Chinese companies—Jiangsu Zhongji Lamination Materials Co. and Shanghai Shenyan Packaging Materials Co.—were found to have received substantial subsidies. The Department calculated net countervailable subsidy rates of 22.10 % for Zhongji and a striking 120.81 % for Shenyan. For other companies that were not individually examined, an “all‑others” rate of 24.02 % was established. These rates will be applied as ad‑valorem duties on future U.S. imports of the affected aluminum foil.

The decision has immediate trade‑policy implications. Customs and Border Protection will assess the duties on all qualifying shipments, and importers will be required to pay cash deposits equal to the estimated duties until the final assessment is completed. The ruling also underscores the U.S. commitment to enforcing trade rules against subsidized imports, potentially influencing future supply chains, pricing, and the competitiveness of domestic aluminum producers.

Key Elements

• Period of Review: January 1 – December 31 , 2023
  
• Subsidy Findings
  
  • Jiangsu Zhongji Lamination Materials Co.: 22.10 % ad‑valorem rate
    
  • Shanghai Shenyan Packaging Materials Co.: 120.81 % ad‑valorem rate
    
  • Non‑selected companies: 24.02 % all‑others rate
    
• Cash Deposit Requirement: Importers must deposit the estimated duty amount upon entry or withdrawal of the aluminum foil.
  
• Assessment Timeline: Customs will issue assessment instructions no earlier than 35 days after publication; a 90‑day window is provided for statutory injunction requests.
  
• Administrative Protective Order: Parties must destroy or return proprietary information disclosed under the order.
  
• Impact on Trade: The high duty rates may reduce U.S. imports of Chinese aluminum foil, affect downstream industries (e.g., packaging, construction), and prompt Chinese exporters to seek alternative markets or adjust production strategies.
  
• Policy Context: The review follows a preliminary notice issued in August 2025; delays due to a federal shutdown extended the deadline to February 12 , 2026.
  
• Stakeholder Engagement: The Department will disclose detailed calculations and analysis within five days of publication, allowing interested parties to review the methodology.

US Tightens Trade Rules on Indian Stainless Steel Bars: Final Dumping Duty Review and Partial Rescission

The U.S. Department of Commerce’s International Trade Administration has issued the final results of its 2023‑2024 antidumping duty (AD) administrative review for stainless steel bars (SS Bar) imported from India. The review confirms that several Indian producers sold SS Bar in the United States at prices below the normal value, establishing dumping margins that will be used to calculate new AD duties. The notice also rescinds the review for two companies—Bhansali Bright Bars and Chandan Steels Limited—because no suspended entries of their products were found during the review period.

Key aspects of the decision include the determination of weighted‑average dumping margins for each examined exporter, the assignment of a 30.92 % margin to Atlas Stainless Corporation (based on adverse facts available) and a 0 % margin to Aamor Inox Limited. For companies not individually examined, a 15.46 % “all‑others” rate is applied. The final results set the cash deposit rates that importers must pay on new shipments, and they outline the procedures for Customs to assess duties and liquidate entries. Importers are reminded to file reimbursement certificates and to comply with any applicable Administrative Protective Order (APO) requirements.

Key Elements

• Dumping Margins Established

  • Atlas Stainless Corporation: 30.92 % (adverse facts available)
    
  • Aamor Inox Limited: 0 %
    
  • Non‑examined companies (Ambica, Laxcon, Ocean, Metlax, Parvati, Mega, Meltroll): 15.46 %
    

• Partial Rescission

  • Review for Bhansali Bright Bars and Chandan Steels Limited rescinded due to lack of suspended entries during the review period.
    

• Cash Deposit Requirements

  • Importers must deposit the same rates as the final AD assessment rates for covered companies; a default 12.45 % rate applies to all other producers or exporters.
    

• Customs Assessment and Liquidation

  • CBP will assess duties on all appropriate entries based on the final rates, with instructions to liquidate entries no earlier than 35 days after publication.
    

• Compliance Notices

  • Importers must file reimbursement certificates before liquidation to avoid double duties.
    
  • Parties under an APO must return or destroy proprietary information as required.
    

• Timeline

  • Final results published February 18, 2026; assessment instructions to follow within 35 days.
    

These measures aim to protect U.S. stainless steel producers from unfair competition while ensuring transparent and enforceable trade practices.

DOE Extends Data Collection for Energy Project Loan Guarantees – A Call for Input

Overview

The U.S. Department of Energy (DOE) has announced a three‑year extension of its information‑collection request for the DOE Loan Guarantees for Energy Projects program, a key component of the Title 17 Energy Financing Program. Under the Paperwork Reduction Act, the agency seeks to refine the data it gathers from applicants seeking federal loan guarantees for projects ranging from renewable energy plants to advanced fossil‑fuel technologies. The extension will allow DOE to continue collecting detailed project information—such as resource type, environmental assessments, and financial metrics—to assess eligibility and compliance with federal standards.

The notice invites public comment on the necessity, accuracy, and burden of the proposed data collection. DOE estimates that the annual burden will be 13,250 hours, with a total reporting and record‑keeping cost of roughly $3.4 million (about $33,700 per respondent). The agency expects around 100 respondents each year, reflecting the relatively small but high‑impact cohort of projects that qualify for Title 17 guarantees.

Stakeholders—including geoscientists, energy developers, and environmental groups—have until April 20, 2026 to submit feedback. Comments can influence how DOE structures its application forms, the use of automated data capture, and the overall clarity and utility of the information required. The agency encourages input on ways to reduce administrative burden while maintaining rigorous oversight of projects that shape the nation’s energy future.

Key Elements

• Purpose: Gather data to evaluate eligibility for DOE’s Title 17 loan‑guarantee programs (Section 1703 and 1706).
  
• OMB Control No.: 1910‑5134; Type of Review: Revision and extension of an approved collection.
  
• Estimated Burden: 13,250 annual hours; $3.4 million total reporting cost (~$33,700 per respondent).
  
• Respondent Profile: Approximately 100 annual applicants, typically energy developers, project sponsors, and engineering firms.
  
• Statutory Authority: Title 17 of the Energy Policy Act of 2005 (42 U.S.C. 16511 et seq.).
  
• Comment Period: Open until April 20, 2026; comments can be submitted by mail, email, or via Regulations.gov.
  
• Contact: Uchechukwu “Emeka” Eze, Office of Loan Guarantees, DOE – phone (202) 586‑1092 or email LPO.IFR@hq.doe.gov.
  
• Relevance to Geoscience & Energy Sectors: Data collected includes resource characterization, environmental impact assessments, and technical feasibility—critical for assessing the viability of projects that tap into mineral, fossil‑fuel, or renewable resources.
  
• Potential Impact: Feedback may shape the design of application forms, reduce paperwork, and improve the efficiency of DOE’s oversight of large‑scale energy projects.

Federal Energy Regulatory Commission Signals Environmental Review for Michigan Hydropower Project

The Federal Energy Regulatory Commission (FERC) has announced its intent to prepare an Environmental Assessment (EA) for the relicense application of the 1.65‑megawatt French Landing Hydroelectric Project on Michigan’s Huron River. The project, owned by STS Hydropower, LLC and operated in partnership with the Charter Township of Van Buren, seeks to extend its operating license under Project No. 9951‑057. The EA will evaluate the potential environmental impacts of continuing the hydroelectric facility, including effects on water quality, fish and wildlife, and local ecosystems.

FERC’s notice indicates that the agency does not anticipate the relicense to constitute a major federal action under the National Environmental Policy Act, but it will still conduct a thorough assessment. The EA will be issued on December 8, 2026, followed by a 30‑day public comment period. All comments will be considered in the final licensing decision, and interested parties—including local residents, environmental groups, and industry stakeholders—are invited to submit interventions, comments, or requests for rehearing.

The announcement underscores FERC’s commitment to transparent environmental review and public participation. It provides clear contact information for inquiries and outlines the procedural schedule, ensuring that stakeholders have ample opportunity to influence the outcome of the licensing process.

Key Elements

• Project Details: 1.65‑MW French Landing Hydroelectric Project on the Huron River, Wayne County, Michigan.
  
• Relicensing Application: Filed by STS Hydropower, LLC and Charter Township of Van Buren; Project No. 9951‑057.
  
• EA Preparation: FERC intends to issue an Environmental Assessment on December 8, 2026.
  
• Comment Period: 30 days following EA release; all public comments will be reviewed.
  
• Public Participation: Contact Office of Public Participation (202) 502‑6595 or OPP@ferc.gov for interventions, comments, or rehearing requests.
  
• Schedule: EA issuance, comment period, and potential revisions to the timeline are outlined in the notice.
  
• Environmental Focus: Assessment will consider impacts on water quality, fish and wildlife, and broader ecological effects.
  
• Regulatory Context: The action is governed by 18 CFR 2.1 and the National Environmental Policy Act.

FERC’s 2026 Sunshine‑Act Meeting: A Window into Energy Policy and Natural Resource Decisions

Overview

The Federal Energy Regulatory Commission (FERC) announced a public meeting scheduled for February 19, 2026, in Washington, D.C. The notice, issued under the Sunshine Act, invites stakeholders and the general public to observe deliberations on a wide range of energy‑related matters, from electric transmission and renewable projects to gas pipeline operations and hydroelectric licensing. By publishing the agenda and docket numbers, FERC ensures transparency and allows interested parties to review relevant documents before the meeting.

The meeting’s agenda covers administrative items, electric and gas projects, hydroelectric license actions, and certificate issuances. Topics include the approval of new solar facilities, reliability and market operations, disputes over gas pipeline services, and categorical exclusions for hydroelectric license terminations. These decisions can influence the development of renewable resources, the stability of electric grids, and the management of water‑powered energy assets—issues that directly affect geoscientists, energy engineers, and natural resource managers.

The notice also provides practical information: the meeting will be webcast live, a press briefing will follow, and contact details are supplied for further inquiries. This openness reflects FERC’s commitment to public participation in shaping the nation’s energy infrastructure and natural resource stewardship.

Key Elements

• Meeting Details

  • Date & Time: February 19, 2026, 10:00 a.m.
    
  • Location: Room 2C, 888 First Street NE, Washington, D.C. 20426
    
  • Open to the public; webcast available on FERC’s website
    

• Agenda Categories

  • Administrative: Agency matters, customer reliability, market operations
    
  • Electric: Solar project approvals (e.g., Constellation Energy, Stay Ready Solar, Branch Street Solar), reliability coordination, and transmission issues
    
  • Gas: Pipeline service disputes (e.g., Baltimore Gas & Electric vs. Transcontinental), production company litigation
    
  • Hydro: Categorical exclusions for water‑power license terminations, Tennessee Valley Authority hydro decisions, specific hydroelectric company orders
    
  • Certificates: Fuel gas supply certifications, regulatory adjustments for construction authorizations
    

• Notable Docket Items

  • E‑1 (EC25‑43‑001): Constellation Energy and Calpine Corporation projects
    
  • E‑3 (EL26‑25‑000): Solar dispute involving Stay Ready Solar and Entergy New Orleans
    
  • H‑1 (RM26‑7‑000): National Environmental Policy Act exclusions for hydro license terminations
    
  • G‑1 (PL23‑1‑000): Oil pipeline affiliate committed service
    

• Public Engagement

  • Webcast and live streaming for remote participation
    
  • Press briefing immediately after the meeting, viewable in the overflow room
    
  • Contact: Debbie‑Anne A. Reese, Secretary, (202) 502‑8400
    

These elements outline how FERC’s upcoming meeting will address critical decisions affecting energy production, transmission, and natural resource management, offering stakeholders a clear view of the regulatory process.

PacifiCorp Extends Comment Window on Klamath River Hydroelectric Project

Overview

The Federal Energy Regulatory Commission (FERC) has reopened the public comment period for PacifiCorp’s non‑capacity amendment application concerning the Klamath Hydroelectric Project (Project No. 2082). The project, located on the Klamath River and Fall Creek in Oregon and California, sits on federal lands managed by the U.S. Bureau of Reclamation. The Department of the Interior requested an extension to allow additional review of the project’s potential effects on multiple federal interests, and FERC has granted this request, moving the deadline to February 27, 2026.

This extension gives stakeholders—environmental groups, local communities, water‑resource managers, and industry participants— more time to submit comments, motions to intervene, or protests. The amendment seeks to modify the project’s capacity, which could influence water flow, fish habitat, and power generation in the region. The extended period reflects the complex interplay between energy development and ecological stewardship on federal lands.

Key Elements

• Project Scope: PacifiCorp’s Klamath Hydroelectric Project (Project No. 2082) on the Klamath River and Fall Creek, spanning Klamath County, Oregon, and Siskiyou County, California.
  
• Federal Lands: The project occupies land managed by the U.S. Bureau of Reclamation, implicating federal water‑resource and environmental regulations.
  
• Comment Period Extension: Original deadline was February 5, 2026; extended to February 27, 2026, at 5:00 p.m. Eastern Time.
  
• Filing Channels: Electronic filing via FERC’s eFiling system or eComment portal; paper filings accepted at specified addresses.
  
• Stakeholder Impact: Potential effects on river flow, fish habitat, water rights, and regional power supply; comments can influence regulatory decisions.
  
• Regulatory Authority: Action taken under 18 CFR 2.1, with oversight by the Department of Energy and FERC.
  
• Contact Information: Public inquiries directed to the Office of Public Participation (202‑502‑6595) or OPP@ferc.gov; filing assistance via FERC Online Support.

Aspen’s Ruedi Dam Revamp: Faster Environmental Review Set for March 2026

Overview
The Federal Energy Regulatory Commission (FERC) has announced a revised schedule for the environmental assessment (EA) of the City of Aspen’s proposed upgrades to the Ruedi Hydroelectric Project on Colorado’s Fryingpan River. The EA, originally slated for August 5 2026, will now be issued by March 27 2026, giving the public an earlier opportunity to review and comment on the planned changes. The EA will be followed by a 30‑day comment period, during which all submissions will be considered in FERC’s final decision.

The proposed upgrades include constructing a new powerhouse, extending the penstock, adding a second turbine and generator, building a new tailrace, installing a bypass line, and modernizing the electrical system—all within the existing project boundaries. These modifications aim to increase the plant’s capacity by 1.2 MW and improve operational efficiency while maintaining compliance with federal and state environmental regulations.

Stakeholders, including local residents, environmental groups, and industry participants, are encouraged to submit comments or intervene in the process. FERC’s Office of Public Participation and the City of Aspen’s contact points are provided for inquiries and filing assistance.

Key Elements

• Agency & Project: FERC, City of Aspen, Ruedi Hydroelectric Project (Project No. 3603‑018) on the Fryingpan River, Colorado.
  
• Proposed Modifications:
  
  • New 22 × 28‑ft powerhouse.
    
  • 110‑ft extension of a 30‑inch penstock.
    
  • Second turbine/generator (1.2 MW).
    
  • 48 × 48‑ft, 60‑ft concrete tailrace.
    
  • 24‑inch bypass line within the powerhouse.
    
  • Electrical system modernization.
    
• Environmental Assessment Schedule:
  
  • Original EA issuance date: August 5 2026.
    
  • Revised EA issuance date: March 27 2026.
    
  • 30‑day public comment period following EA release.
    
• Public Participation:
  
  • Comments, interventions, and rehearing requests accepted.
    
  • Contact: Office of Public Participation (202) 502‑6595 / OPP@ferc.gov.
    
  • Specific inquiries: Maryam Akhavan (202) 502‑6110 / Maryam.Akhavan@ferc.gov.
    
• Regulatory Basis: FERC’s authority under 18 CFR 2.1.
  
• Documentation: EA unique ID EAXX‑019‑20‑000‑1750060234; official PDF available via GovInfo.

Minnesota’s New 9‑MW Hydropower Project Opens Public Review

Overview

The Federal Energy Regulatory Commission (FERC) has accepted the application of Eagle Creek Sartell Hydro, LLC for a new major license to operate the Sartell Hydroelectric Project on the Mississippi River in Stearns and Benton Counties, Minnesota. The project will upgrade an existing 46‑foot dam, expand a 2,350‑acre reservoir, and add 11 generating units totaling 8.95 MW of clean, renewable power. The facility also includes a 715‑foot transmission line that will feed electricity into the regional grid.

FERC’s notice announces that the application is now ready for environmental analysis under the Federal Power Act. It invites the public, environmental groups, and other stakeholders to file motions to intervene, protests, comments, recommendations, terms and conditions, and prescriptions by April 13, 2026, with reply comments due May 28, 2026. All filings must be submitted electronically through FERC’s eFiling system or via paper, and must include the project name and docket number.

The review will assess the project’s environmental impacts—particularly on river flow, fish and wildlife habitat, water quality, and downstream communities—before a final license decision is made. The notice also requires the applicant to provide a water‑quality certification or waiver, ensuring compliance with the Clean Water Act. Stakeholders have a critical window to influence the environmental assessment and the eventual licensing outcome.

Key Elements

• Project Scope: 46‑ft dam with four sections, 2,350‑acre reservoir, 11 turbines (8.95 MW), 715‑ft transmission line.
  
• Regulatory Status: New major license application accepted; ready for environmental analysis under the Federal Power Act.
  
• Public Participation Deadlines:
  
  • Motions to intervene, protests, comments, recommendations, terms and conditions, prescriptions: April 13, 2026.
    
  • Reply comments: May 28, 2026.
    
• Submission Channels: Electronic filing via FERC Online or paper submissions to specified addresses.
  
• Water‑Quality Requirements: Applicant must file a water‑quality certification, request for certification, or evidence of a waiver by the April deadline.
  
• Environmental Focus: Assessment of impacts on river hydrology, fish and wildlife, water quality, and downstream communities.
  
• Stakeholder Rights: Any party filing a motion to intervene may become a formal participant; protests and comments are considered but not automatically parties.
  
• Access to Documents: Full notice and related files available on FERC’s website and in public inspection.
  
• Contact Points: FERC Online Support, Office of Public Participation, and the applicant’s regulatory affairs office for inquiries and filing assistance.

BLM Approves Transfer of 1,085 Acres to Alaska Native Corporation Doyon, Limited

Overview
The U.S. Bureau of Land Management (BLM) has issued a decision approving the conveyance of both surface and subsurface estates in a parcel of land near Flat, Alaska, to Doyon, Limited—an Alaska Native regional corporation established under the Alaska Native Claims Settlement Act (ANCSA) of 1971. This action follows the BLM’s statutory duty to administer land transfers to ANCSA corporations and represents a formal transfer of ownership rights from federal to tribal control.

The lands encompass approximately 1,085 acres, divided into two tracts: about 147 acres in T. 26 N., R. 47 W. (Sections 5–8) and roughly 938 acres in T. 27 N., R. 47 W. (Sections 1–3, 10–12, 16, 21, 27–28, 31–33). The decision covers both surface and subsurface interests, ensuring that Doyon, Limited will hold full title to the resources and land use rights within these boundaries.

Key implications include the reservation of public access easements under ANCSA Section 17(b), the requirement for the BLM to publish notice of the decision in the Fairbanks Daily‑News Miner for four consecutive weeks, and the provision for interested parties to appeal the decision under 43 CFR Part 4. Appeals must be filed within specified time limits—30 days for certified mail recipients and until March 20, 2026 for others—before rights are deemed waived.

Key Elements

• Conveyance Approval: BLM approves transfer of surface and subsurface estates to Doyon, Limited under ANCSA.
• Land Description: 1,085 acres near Flat, Alaska; two tracts (147 acres and 938 acres) defined by specific survey sections.
• Public Access Easements: Reserved to the United States per ANCSA §17(b); details to be maintained in the final deed.
• Publication Requirement: Weekly notice in the Fairbanks Daily‑News Miner for four weeks to inform the public.
• Appeal Process: Parties may appeal under 43 CFR Part 4; deadlines vary by method of service (30 days for certified mail, March 20, 2026 for others).
• Contact Information: Appeals and inquiries directed to Chelsea L. Kreiner, Acting Deputy State Director, BLM Alaska State Office (phone 907‑271‑4205, email ckreiner@blm.gov).
• Accessibility: TTY services available for individuals with hearing or speech disabilities.

Clean Air Crackdown: Antero Resources Faces $3.8 Million Penalty Over Oil‑Field Emissions

Overview

The U.S. Department of Justice has lodged a proposed consent decree against Antero Resources Corporation, a major oil and natural‑gas producer operating in West Virginia and Ohio. The decree stems from alleged violations of the Clean Air Act, specifically failures to design, operate, and maintain adequate vapor‑control systems on storage tanks, leading to the release of volatile organic compounds (VOCs) and other pollutants into the atmosphere.

The proposed settlement requires Antero to implement a series of mitigation projects aimed at reducing VOC emissions, comply with injunctive relief provisions, and pay a civil penalty of $3.8 million. If the company fully complies, it will be released from liability for past violations related to new or modified storage vessels and related state law.

The notice opens a 30‑day public comment period, inviting stakeholders—including environmental scientists, industry representatives, and the general public—to weigh in on the decree’s terms. Comments can be submitted electronically or by mail to the Assistant Attorney General, Environment and Natural Resources Division.

Key Elements

• Violation Focus: Improper design, operation, and maintenance of storage‑tank vapor‑control systems, causing VOC emissions.
  
• Injunctive Relief: Antero must adopt corrective measures to bring facilities into compliance with Clean Air Act regulations.
  
• Mitigation Projects: Specific projects to reduce VOC emissions must be completed within the agreed timeframe.
  
• Civil Penalty: $3,800,000 payable to the U.S. Treasury.
  
• Release of Liability: Full compliance will absolve Antero of past civil liability for the cited violations.
  
• Public Comment Period: 30 days from publication; comments directed to the DOJ’s Environment and Natural Resources Division.
  
• Legal Context: The decree is filed in the U.S. District Court for the Northern District of West Virginia under Civil Action No. 26‑cv‑00010.
  
• Implications for the Industry: Highlights the importance of robust vapor‑control systems and may prompt broader regulatory scrutiny of oil‑field storage practices.

NASA Streamlines Environmental Review by Adopting 18 Existing Exclusions

Overview

On February 18 2026, NASA announced that it will adopt 18 categorical exclusions (CATEXs) originally established by other federal agencies, including the Department of Energy, U.S. Coast Guard, Federal Railroad Administration, and several DoD branches. These exclusions allow NASA to bypass the full Environmental Impact Statement (EIS) or Environmental Assessment (EA) process for a wide range of routine activities—such as vehicle drop tests, power‑line construction, pipeline installation, solar‑panel deployment, and decommissioning of aging aircraft—provided no extraordinary environmental circumstances exist.

The notice explains that NASA has consulted with each originating agency to confirm that the proposed uses align with the intended scope of the CATEXs. It also outlines the criteria NASA will apply to identify “extraordinary circumstances” that would trigger a more detailed review. By adopting these exclusions, NASA aims to accelerate project timelines while maintaining compliance with the National Environmental Policy Act (NEPA).

The public notice serves to inform stakeholders—including scientists, engineers, and local communities—about the new procedural framework and the types of activities that will now be subject to streamlined environmental review. NASA’s adoption is effective immediately, and the agency invites comments on the scope and application of the exclusions.

Key Elements

• Adopted CATEXs: 18 exclusions covering testing, construction, remediation, decommissioning, and hazardous‑material abatement.
  
• Scope of Activities:
  
  • Vehicle and propellant drop tests (e.g., spacecraft landing systems).
    
  • Power‑line and pipeline construction within existing rights‑of‑way.
    
  • Solar photovoltaic installations on buildings or disturbed land.
    
  • Transfer and decommissioning of aging aircraft and vessels.
    
  • Environmental restoration and remediation projects.
    
  • Hazardous‑material removal (asbestos, lead, PCBs).
    
• Interagency Consultation: NASA consulted with the FRA, FBI, DOE, NTIA, USCG, USFS, DoD branches, and others to ensure appropriateness.
  
• Extraordinary Circumstances: NASA will evaluate each action for potential significant environmental impacts, including effects on protected species, wetlands, historic sites, or unique technologies.
  
• Public Notice and Documentation: The Federal Register notice documents the adoption, provides contact information, and outlines the procedural steps for future projects.
  
• Effective Date: February 18 2026; all NASA projects falling within the defined categories are now subject to the streamlined review.
  
• Implications for Geoscience and Energy Projects: The exclusions reduce regulatory burden for infrastructure and testing activities critical to space exploration, energy research, and environmental monitoring, while preserving safeguards for sensitive natural and cultural resources.

DOE’s New Pricing Rules: What They Mean for Science, Energy, and the Public

Overview

The U.S. Department of Energy (DOE) has proposed a comprehensive update to its 1980 pricing regulation (10 CFR Part 1009). The goal is to bring the policy in line with modern statutes, executive orders, and DOE’s own internal guidance. The rule will set the prices and charges that DOE charges to non‑federal customers—including foreign governments, private companies, and research institutions—for materials, services, and access to facilities.

Key changes include: - Full‑cost pricing for most items, with a new, lower Federal Administrative Charge of 1 % (down from 3 %) effective 1 Oct 2025.
- Expanded lists of exclusions (e.g., natural‑gas sales, power‑marketing activities, isotope sales, and certain data‑dissemination fees).
- Clarified special‑pricing programs such as the Nuclear Material Removal Program, Research Reactor Infrastructure Program, museums, and user‑facility access.
- Updated definitions and procedures for determining fair value, replacement cost, and indirect costs.

The proposal is currently open for public comment until April 20 2026. DOE expects the rule to improve transparency, reduce administrative costs for non‑federal users, and better align pricing with the Department’s mission in energy, nuclear security, and scientific research.

Key Elements

• Full‑Cost Basis

  • Prices for materials and services sold to non‑federal entities are set at the full cost incurred by DOE or its contractors, including direct, indirect, and administrative costs.

• Federal Administrative Charge (FAC)

  • Reduced to 1 % of total direct and indirect costs for reimbursable work, effective 1 Oct 2025.
    
  • Applies to a wide range of cooperative agreements (CRADAs, ACTs, technology‑transfer projects).
    
  • In‑kind contributions are exempt.

• Expanded Exclusions

  • Natural‑gas regulations (10 CFR Parts 580‑590).
    
  • Power‑marketing activities of Bonneville, Southeast, Southwest, and Western Area Power Administrations.
    
  • Isotope sales, source/special nuclear material, and byproduct material governed by the Atomic Energy Act.
    
  • FOIA, Privacy Act, and EIA data dissemination.
    
  • Strategic Petroleum Reserve, excess/surplus property, uranium sales, and various intergovernmental and royalty arrangements.

• Special Pricing Activities

  • Nuclear Material Removal Program: cost‑sharing and acceptance fees for high‑income‑economy countries.
    
  • Research Reactor Infrastructure Program: free support for domestic research reactors; cost‑sharing for commercial use.
    
  • Museums & Exhibits: no admission fees unless specifically authorized.
    
  • User Facilities:
    
  • Non‑proprietary research often free; incremental costs may apply.
    
  • Proprietary research charged at full cost; startup rates may be reduced during facility build‑out.
    
  • Royalties: negotiated separately; not based on development cost.

• Transparency & Dissemination

  • Prices and charges are publicly available from the responsible DOE office or the Office of the Chief Financial Officer.
    
  • Estimated costs may be provided for items not yet fabricated or procured.

• Regulatory Context

  • Not a significant energy action under EO 13211; no major environmental impact.
    
  • No preemption of state law; no substantial intergovernmental mandate.
    
  • Comment period closed 4 Apr 2026; final rule pending.

These updates aim to streamline DOE’s pricing practices, reduce costs for external users, and clarify how the Department recovers expenses while supporting its scientific, energy, and national‑security missions.

EPA Seeks Public Input on Tweaking Hazardous‑Substance Spill Plans

Overview

The U.S. Environmental Protection Agency (EPA) has issued an advanced notice of proposed rulemaking (ANPRM) to reconsider the 2024 regulations that require non‑transportation onshore facilities to prepare Facility Response Plans (FRPs) for worst‑case releases of hazardous substances into or near navigable waters. The goal is to gather stakeholder feedback on how to simplify the rule’s applicability criteria, clarify technical requirements, and reduce compliance burdens while still protecting human health and the environment.

The ANPRM focuses on facilities that hold hazardous substances in quantities that meet or exceed a threshold (1,000 × the Reportable Quantity) and are located within half a mile of a navigable water or a conveyance to such water. If those conditions are met, the facility must determine whether a “substantial harm” scenario exists—considering impacts on public water systems, fish and wildlife, and public receptors—and, if so, submit a detailed FRP.

Comments are due by March 20, 2026. EPA invites industry, environmental groups, and the public to propose changes to threshold multipliers, proximity definitions, planning‑distance calculations, and other technical aspects that could streamline compliance without compromising the Clean Water Act’s protective intent.

Key Elements

• Scope & Applicability

  • Applies to non‑transportation onshore facilities that store hazardous substances near navigable waters.
    
  • Uses a 1,000 × Reportable Quantity (RQ) threshold and a half‑mile proximity rule.
    

• Substantial Harm Determination

  • Four criteria: recent reportable discharge, potential impact on public water systems, harm to fish/wildlife, and harm to public receptors.
    
  • Requires detailed distance calculations to each endpoint.
    

• Facility Response Plan Requirements

  • General plan: alignment with national contingency plans, qualified individual, equipment availability, training, and periodic updates.
    
  • Emergency response information: facility data, hazard evaluation, personnel and equipment, notification lists, and containment measures.
    
  • Emergency response action plan: first‑two‑hour actions, incident command, evacuation, and monitoring.
    

• Implementation Challenges Highlighted

  • Complexity of multi‑chemical applicability calculations.
    
  • Lack of de‑minimis thresholds for container size or concentration.
    
  • Ambiguity in measuring proximity to water (facility boundary vs. release point).
    
  • Need for user‑friendly planning‑distance tools.
    

• Proposed Reconsiderations

  • Alternative RQ multipliers or a single threshold for all hazardous substances.
    
  • Establishing de‑minimis container sizes or concentrations.
    
  • Clarifying the definition of “conveyance” and simplifying proximity criteria.
    
  • Adjusting substantial‑harm thresholds (e.g., five‑year reportable discharge limits).
    
  • Exploring exemptions for facilities already subject to oil FRP rules or wastewater treatment plants.
    

• Stakeholder Engagement

  • Comment period ends March 20, 2026.
    
  • Submit comments via Regulations.gov (preferred) or by mail to the EPA Docket Center.
    
  • Contact: Rebecca Broussard, Office of Land and Emergency Management, EPA.
    

This ANPRM is a pre‑rulemaking step; EPA may use the feedback to draft a new or amended rule that balances regulatory clarity with robust protection of water resources.

EU Court Dismisses Cosmetics Industry Challenge to New Wastewater Regulation

Overview

The General Court of the European Union has ruled that Cosmetics Europe – The Personal Care Association cannot challenge the European Parliament and Council’s Directive ²⁰²⁴⁄₃₀₁₉, which introduces an extended producer responsibility (EPR) scheme for cosmetics and medicinal products. The directive aims to reduce micropollutants in urban wastewater by requiring producers to finance quaternary treatment processes. Cosmetics Europe argued that the new rules unfairly burden the industry, but the court found the association lacked the legal standing to bring the case.

The court’s decision focuses on the principle of “individual concern” under Article 263 TFEU. It concluded that Cosmetics Europe, acting in its own name or on behalf of its member associations, was not directly and individually affected by the contested provisions. Consequently, the action was dismissed as inadmissible, and the association was ordered to pay the costs.

This ruling underscores the strict criteria for standing in EU annulment actions and confirms that the EPR scheme for cosmetics will proceed without judicial obstruction. The decision may influence how industry groups approach future challenges to EU environmental legislation.

Key Elements

• Directive ²⁰²⁴⁄₃₀₁₉: Recasts the 1991 urban wastewater directive, adding quaternary treatment to remove micropollutants, especially from cosmetics and medicines.
• Extended Producer Responsibility (EPR): Requires producers of cosmetics and medicinal products to finance the treatment of their waste, aiming to internalize environmental costs.
• Standing Requirement: The court applied Article 263 TFEU, finding Cosmetics Europe was not “directly and individually concerned” by the EPR provisions.
• Inadmissibility: The action was dismissed before substantive review, meaning the directive remains in force.
• Cost Order: Cosmetics Europe must cover the legal costs of the European Parliament and Council; intervening parties (Commission, BDEW, VKU) bear their own costs.
• Implications for Industry: The decision removes a potential legal hurdle for the implementation of the EPR scheme, reinforcing the EU’s commitment to reducing pharmaceutical and cosmetic residues in wastewater.

Border Build‑Up: DHS Waives Environmental Laws to Fast‑Track Texas Barrier Construction

The Department of Homeland Security (DHS) has issued a formal determination under Section 102 of the Illegal Immigration Reform and Immigrant Responsibility Act (IIRIRA) to waive a wide array of federal, state, and local environmental, historic, and wildlife protection statutes. The waiver is aimed at expediting the construction of physical barriers and roads along a 120‑mile stretch of the U.S.–Mexico border in the Big Bend Sector of Texas, an area identified by DHS as a hotspot for illegal crossings and drug smuggling.

This action follows the President’s Executive Order on Securing Our Borders and the Secure Fence Act of 2006, which mandate DHS to achieve “operational control” of the southern border. By invoking Section 102© of IIRIRA, the Secretary can bypass requirements such as the National Environmental Policy Act (NEPA), the Endangered Species Act, and the Clean Water Act, among others, to accelerate infrastructure development. The waiver is effective as of February 17, 2026, and is limited to the specified project area, defined by GPS coordinates in the Big Bend Sector.

While the determination prioritizes border security, it raises significant environmental and land‑use concerns. The waiver removes safeguards that normally require environmental impact assessments, wildlife habitat protection, and historic preservation reviews. Geoscientists, natural resource managers, and energy professionals should note that the project may alter hydrology, soil stability, and ecological corridors, and that future monitoring or mitigation measures will be governed by the DHS’s discretion under the same statutory authority.

Key Elements

• Scope of Waiver

  • Applies to a 120‑mile segment of the U.S.–Mexico border in Texas (GPS coordinates 31.037623, −105.579877 to 29.325866, −104.046466).
    
  • Covers construction of barriers, roads, lighting, cameras, sensors, and associated infrastructure.

• Legal Basis

  • Section 102(a) and (b) of IIRIRA: authority to install barriers and roads.
    
  • Section 102© of IIRIRA: authority to waive all applicable legal requirements deemed necessary for expeditious construction.

• Statutes Waived

  • National Environmental Policy Act (NEPA)
    
  • Endangered Species Act (ESA)
    
  • Clean Water Act (CWA)
    
  • National Historic Preservation Act (NHPA)
    
  • Migratory Bird Treaty Act and Conservation Act
    
  • Clean Air Act (CAA)
    
  • Archeological and Paleontological Resources Protection Acts
    
  • Federal Cave Resources Protection Act
    
  • National Trails System Act
    
  • Safe Drinking Water Act
    
  • Noise Control Act
    
  • Solid Waste Disposal Act (RCRA)
    
  • Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA)
    
  • Antiquities Act, Historic Sites Act, Eagle Protection Act, Native American Graves Protection and Repatriation Act, and others.

• Implications for Geoscience and Natural Resources

  • Removal of environmental impact assessments may affect soil erosion, groundwater recharge, and surface water quality.
    
  • Potential disruption of wildlife corridors and habitats, especially for endangered species and migratory birds.
    
  • Alteration of historic and archaeological sites without prior review.
    
  • Possible conflicts with state and local land‑use planning and conservation objectives.

• Future Waivers and Oversight

  • The determination does not supersede other waivers under Section 102©.
    
  • DHS retains the authority to issue additional waivers as needed.
    
  • No explicit requirement for post‑construction monitoring or mitigation is included in the waiver.

This determination underscores the tension between national security priorities and environmental stewardship, highlighting the need for ongoing dialogue among policymakers, scientists, and stakeholders in the geoscience and natural resource communities.

China’s Graphite Gamble: U.S. Declares Dumping of Battery‑Grade Anode Material

Overview

The U.S. Department of Commerce has issued a final affirmative determination that active anode material—high‑purity graphite used in lithium‑ion batteries—originating from the People’s Republic of China is being sold in the United States at less than fair value. The investigation covers the period from April 1 to September 30 2024 and focuses on graphite with at least 90 % carbon content, typically used in battery anodes. The determination follows a preliminary ruling and a series of comment periods, and it sets the stage for potential antidumping duties if the U.S. International Trade Commission (ITC) finds that domestic industry is materially injured or threatened.

The final ruling assigns a weighted‑average dumping margin of 93.50 % for most individual exporter/producer combinations and a higher China‑wide entity rate of 102.72 %. These rates will be used to calculate cash deposits that importers must post to cover estimated duties. The U.S. has also suspended the liquidation of entries of the subject merchandise, meaning that customs officials will not release the goods until duties are paid or the ITC’s final injury determination is made. If the ITC determines no injury, the suspension will be lifted and deposits refunded.

For stakeholders in the battery supply chain—mining companies, graphite processors, battery manufacturers, and downstream users—this decision signals a tightening of U.S. trade enforcement on a critical component of electric‑vehicle and energy‑storage technology. It also underscores the broader geopolitical and economic tensions surrounding China’s dominance in the global graphite market.

Key Elements

• Product Scope: Active anode material (graphite ≥90 % carbon, 80 µm max in powder form, energy density ≥330 mAh/g, graphitization ≥80 %) used in battery anodes, excluding finished batteries or vehicles.
  
• Dumping Margins:
  
  • Individual exporter/producer combinations: 93.50 %
    
  • China‑wide entity: 102.72 % (based on adverse‑inference facts).
    
• Cash Deposit Requirements: Importers must post deposits equal to the applicable dumping margin, adjusted for any countervailing duty offsets.
  
• Suspension of Liquidation: Customs will hold all entries of the subject merchandise until duties are paid or the ITC’s injury determination is issued.
  
• ITC Notification: The ITC will decide within 45 days whether U.S. industry is materially injured or threatened by these imports.
  
• Potential Outcomes:
  
  • If injury is found: Antidumping duties imposed, customs releases delayed until payment.
    
  • If no injury: Suspension lifted, deposits refunded, and the investigation concludes.
    
• Implications for the Energy Sector: The ruling could affect the cost and availability of graphite for battery manufacturers, potentially influencing electric‑vehicle pricing and the deployment of grid‑scale storage.
  
• Geoscience Impact: The decision highlights the strategic importance of graphite mining and processing, encouraging U.S. and allied countries to diversify supply chains and invest in domestic graphite production.

Aluminum Sheet from Bahrain: U.S. Antidumping Duty Final Decision

Overview

The U.S. Department of Commerce has concluded an administrative review of sales of common alloy aluminum sheet from Bahrain during the period April 1 2023 – March 31 2024. The review found that Gulf Aluminium Rolling Mill B.S.C. (GARMCO) sold the product to the United States at a dumping margin of 15.74 %. This margin is the weighted‑average rate that will be applied to future imports of the same product from Bahrain.

The decision follows a preliminary announcement in August 2025 and a period of extended deadlines caused by a federal shutdown. The final notice, published February 17 2026, includes the full calculation methodology, assessment instructions for U.S. Customs and Border Protection, and cash‑deposit requirements that importers must meet to cover the duty.

For U.S. manufacturers, exporters, and importers of aluminum sheet, the ruling means higher duties on Bahrain‑origin products and stricter compliance obligations. For Bahrain’s aluminum industry, the decision signals a significant increase in the cost of exporting to the U.S. market.

Key Elements

• Dumping Margin: 15.74 % for GARMCO; all‑others rate of 4.83 % applies to other exporters not covered in this review.
• Cash Deposit: Importers must deposit an amount equal to the applicable dumping margin (or the all‑others rate) before the product is released from customs.
• Assessment Instructions: Customs will assess duties on all entries of the subject merchandise in accordance with the final margin; entries where the exporter was unaware of U.S. destination will be liquidated at the all‑others rate.
• Compliance Requirements: Importers must file a certificate of reimbursement before liquidation; failure may trigger double duties or increased assessments.
• Administrative Protective Order: Parties must return or destroy proprietary information disclosed under the order; non‑compliance can lead to sanctions.
• Timeline: Final results published February 17 2026; assessment instructions to be issued at least 35 days later; cash‑deposit rules effective immediately for shipments entered after publication.
• Impact on Trade: The higher duty rate may reduce U.S. imports of Bahrain aluminum sheet and affect downstream industries such as construction, automotive, and aerospace that rely on this material.

FERC Extends Water‑Project Declaration Filing Requirement for Three Years

Overview

The Federal Energy Regulatory Commission (FERC) has announced a three‑year extension of its FERC‑515 Declaration of Intention information‑collection program. The extension, which runs through 2028, keeps the current reporting requirements unchanged and is part of FERC’s compliance with the Paperwork Reduction Act.

The Declaration of Intention is a pre‑licensing filing that allows FERC to determine whether it has jurisdiction over a proposed water‑related project. Applicants submit a written application, maps, and land‑ownership data; FERC staff then assess whether the project falls under federal jurisdiction. If the Commission finds the project non‑jurisdictional, the applicant can avoid the more burdensome license or exemption process.

Stakeholders—including engineers, geoscientists, and developers of hydroelectric, irrigation, or other water‑use projects—are invited to comment on the necessity, burden, and potential improvements to the collection. Comments are due by April 20, 2026 and can be submitted electronically or by mail.

Key Elements

• Three‑year extension of the FERC‑515 information‑collection program (no changes to reporting requirements).
  
• Purpose: to assess federal jurisdiction over proposed water‑project works under Section 23(b) of the Federal Power Act.
  
• Respondents: entities planning to construct project works on certain waters (e.g., hydroelectric, irrigation, flood control).
  
• Estimated burden: 4 respondents per year, 80 hours and $8,240 per response, totaling 320 hours and $32,960 annually.
  
• Comment period: open until April 20, 2026; submissions via email to DataClearance@FERC.gov or by mail to the Commission’s Washington or Rockville offices.
  
• Potential benefit: a non‑jurisdictional finding can eliminate the need for a full license or exemption application, reducing paperwork and cost.
  
• Contact: Kayla Williams, Data Clearance Officer, (202) 502‑6468.

Transwestern Pipeline Seeks FERC Approval for New Natural‑Gas Link to Power AI Data Center

Overview

The Federal Energy Regulatory Commission (FERC) has published a notice regarding Transwestern Pipeline Company, LLC’s request to construct a 17.8‑mile, 24‑inch natural‑gas pipeline in Doña Ana County, New Mexico. The line, part of the “Green Chile Project,” would deliver 400,000 dekatherms per day to Green Chile Ventures, LLC, which plans to use the gas to generate electricity for an artificial‑intelligence/data‑center facility. Transwestern estimates the project cost at roughly $60 million, and the request is filed under the Natural Gas Act (NGA) using a blanket authorization already granted in a separate docket.

Under the NGA, FERC can approve or deny the request after a public comment period. The notice sets a 30‑day protest window: any protest filed by 5:00 p.m. Eastern Time on April 13, 2026, will be considered; otherwise the project is deemed authorized the following day. In addition, interested parties may file motions to intervene or submit comments, all due by the same deadline. Intervenors gain the right to request rehearings and to challenge FERC orders in court.

The notice emphasizes public participation, offering electronic filing through FERC’s eFiling system or paper submissions. It also provides contact information for Transwestern’s senior director and for FERC’s Office of Public Participation, encouraging stakeholders—landowners, ratepayers, local residents, and environmental groups—to engage in the review process.

Key Elements

• Project scope: 17.77‑mile, 24‑inch pipeline with metering facilities in Doña Ana County, New Mexico.
  
• Purpose: Deliver 400,000 dekatherms/day of natural gas to power an AI/data‑center electricity generation facility.
  
• Estimated cost: Approximately $60.2 million.
  
• Regulatory basis: Request filed under sections 157.205, 157.208, 157.211 of the NGA; relies on a blanket certificate from docket CP82‑534‑000.
  
• Protest deadline: 5:00 p.m. ET on April 13, 2026.
  
• Intervention deadline: Same as protest deadline; motions must state intent to intervene.
  
• Comment submission: Open to all; not sufficient to become a party without intervention.
  
• Filing methods: eFiling (online) or paper mail to FERC’s Secretary; protests/interventions must be served to Transwestern’s senior director.
  
• Public participation resources: eLibrary for docket documents, eSubscription for updates, and contact info for FERC’s Office of Public Participation.
  
• Implications for stakeholders: Opportunity to influence pipeline approval, address environmental and land‑use concerns, and participate in the regulatory process that governs natural‑gas infrastructure.

Fortifying the Grid: President Orders Coal Power to Shield National Defense

Overview

In a bold move to secure the United States’ electric infrastructure, President Biden issued Executive Order 14386, declaring coal a critical asset for national defense. The order stresses that the military’s operations, command centers, and defense‑industrial bases depend on a reliable, continuous power supply that cannot be compromised by intermittent renewable sources or foreign fuel dependencies. By emphasizing the country’s vast coal reserves and the proven reliability of coal‑fired plants, the administration seeks to guarantee that military installations remain fully powered during natural disasters, wartime contingencies, or any prolonged energy disruptions.

The executive order builds on earlier directives that re‑energize the coal industry and strengthen grid resilience. It formally integrates coal into the national energy emergency plan, positioning it as a cornerstone of strategic deterrence and energy dominance. The policy signals a shift toward prioritizing baseload generation that can operate continuously, thereby reducing the risk of blackouts that could jeopardize defense readiness and public safety.

Implementation will involve the Department of War (now the Department of Defense) and the Department of Energy negotiating long‑term Power Purchase Agreements (PPAs) with coal‑fired facilities. These contracts will focus on projects that enhance grid reliability, secure on‑site fuel supplies, and assure mission‑critical operations. The order also clarifies that it does not alter existing statutory authorities, is subject to appropriations, and does not create enforceable rights for private parties.

Key Elements

• National Defense Focus: Coal is designated as essential for maintaining continuous power to military installations and defense‑industrial bases.
  
• Grid Resilience: The order underscores the need for a reliable, non‑intermittent energy source to prevent blackouts that could impair operational readiness.
  
• Policy Continuity: Builds on Executive Orders 14261, 14262, and the 2025 National Energy Emergency declaration, reinforcing coal’s role in national security.
  
• Power Purchase Agreements: The Department of Defense, in partnership with the Department of Energy, will secure long‑term PPAs with coal plants, prioritizing projects that improve grid reliability, fuel security, and mission assurance.
  
• Geoscience Implications: Highlights the United States’ abundant coal resources as a strategic natural asset, encouraging continued exploration, extraction, and utilization of coal reserves.
  
• Implementation Constraints: The order is subject to appropriations, does not alter existing agency authorities, and does not create enforceable rights for private entities.
  
• Administrative Costs: Publication and administrative costs are to be borne by the Department of Defense.

Montana’s Updated Surface‑Mining Regulatory Program: A Final Rule for 2026

Overview

The U.S. Interior Department’s Office of Surface Mining Reclamation and Enforcement (OSMRE) has finalized an amendment to Montana’s state program under the Surface Mining Control and Reclamation Act (SMCRA). The rule, effective March 16, 2026, approves a comprehensive set of changes to Montana’s Administrative Rules of Montana (ARM) that bring the state’s regulations into full alignment with federal SMCRA requirements. The amendments address key areas such as ownership and control, the Applicant Violator System, permit application and renewal procedures, criminal penalties, and information requirements for permittees.

The primary goal of the amendment is to strengthen Montana’s oversight of surface coal mining on non‑federal and non‑Indian lands. By updating definitions, data‑collection protocols, and enforcement mechanisms, the state can more effectively monitor compliance, identify potential violations, and enforce penalties. The rule also clarifies the roles of the Montana Department of Environmental Quality (MDEQ) and the state’s permitting process, ensuring that all parties—operators, applicants, and the public—have clear guidance on responsibilities and rights.

Because the amendments mirror the federal framework, the rule is expected to have no significant economic impact on small entities, imposes no unfunded mandates, and does not trigger a major environmental review under NEPA. The final rule reflects a collaborative effort between Montana and OSMRE, with input from federal agencies and the public, and represents a key step in maintaining safe and environmentally responsible mining practices across the state.

Key Elements

• Ownership & Control – New ARM provisions (e.g., 17.24.301, 17.24.1266) establish procedures for challenging ownership or control listings in the Applicant Violator System.
  
• Applicant Violator System – Updated rules (17.24.1264, 17.24.1265) require MDEQ to enter detailed applicant and operator data, including financial, compliance, and historical information, and to conduct eligibility reviews.
  
• Permit Application & Renewal – Revisions to 17.24.303 and 17.24.416 clarify required information, taxpayer identification numbers, and renewal processes.
  
• Criminal Penalties & Civil Actions – New language in 17.24.1229 expands enforcement options, including the use of criminal justice agencies and alternative enforcement mechanisms.
  
• Information Requirements for Permittees – 17.24.1267 mandates that permittees update their information in the Applicant Violator System after cessation orders or changes in personnel.
  
• Environmental & Safety Standards – Minor edits to 17.24.304, 17.24.308, 17.24.313, and 17.24.314 reinforce baseline environmental data, operations plans, reclamation plans, and hydrologic protection.
  
• Administrative Review & Inspections – Updates to 17.24.425 and 17.24.1201 streamline administrative review procedures and inspection frequencies.
  
• Federal Consistency – All amendments are reviewed to ensure they are “no less stringent” and “no less effective” than the corresponding federal SMCRA regulations.
  
• Effective Date & Implementation – The rule becomes effective on March 16, 2026, allowing Montana to implement the updated program in its state permitting and enforcement activities.

North Dakota Tightens Coal Mining Bond Rules to Match Federal Standards

Overview

The U.S. Interior Department’s Office of Surface Mining Reclamation and Enforcement (OSMRE) has finalized an amendment to North Dakota’s state regulatory program under the Surface Mining Control and Reclamation Act (SMCRA). The change updates the state’s definition of a “collateral bond” to include a perfected first‑lien security interest in real property and adds specific conditions that must be met when real property is pledged as collateral. These provisions bring North Dakota’s rules into closer alignment with the federal regulations that govern surface coal mining and reclamation on non‑federal and non‑Indian lands.

The amendment was submitted by the state in December 2022, followed by a brief public comment period that yielded a single anonymous comment. No federal agencies, including the Environmental Protection Agency, provided additional input, and the rule was determined to have no significant environmental, tribal, or economic impacts. The Office of Surface Mining will enforce the updated requirements beginning March 16, 2026, 30 days after publication.

For geoscientists, energy and mineral resource professionals, and land‑use planners, the key takeaway is that North Dakota’s bond and collateral framework now mirrors the federal standard, ensuring consistent financial safeguards for mine reclamation projects across the state.

Key Elements

• Collateral Bond Expansion – Real property can now serve as a perfected first‑lien security interest in the state’s definition of a collateral bond.
  
• New Conditions for Property Pledges – Applicants must:
  
  1. Grant a first‑mortgage or deed of trust with the right to foreclose.
     
  2. Provide a detailed schedule of the pledged property, including independent appraisals and proof of title.
     
  3. Ensure pledged land is not disturbed while it serves as security.
     
• Alignment with Federal Rules – The changes mirror 30 CFR 800.5(b)(5) and 30 CFR 800.21©, maintaining consistency between state and federal standards.
  
• Effective Date – The amendment takes effect on March 16, 2026, 30 days after publication.
  
• Minimal Impact – The rule is exempt from major regulatory review, has no significant economic effect on small entities, and does not impose unfunded mandates or trigger environmental or tribal consultations.
  
• Scope – Applies to surface coal mining and reclamation operations on non‑federal and non‑Indian lands within North Dakota.

Texas Eastern Transmission Seeks to Abandon 10 Miles of Natural‑Gas Pipeline, Opens Public Comment Window

Overview

Texas Eastern Transmission, LP has filed a request with the Federal Energy Regulatory Commission (FERC) to abandon approximately 10.58 miles of its 6.625‑inch Line 16‑B supply lateral, along with several meter and regulating stations in Hidalgo County, Texas. The abandonment is being pursued under a blanket authorization issued in a prior docket (CP82‑535‑000) and is intended to eliminate the costs associated with maintaining and repairing facilities that are no longer needed for gas transportation.

The notice, published in the Federal Register on February 13 2026, invites public participation. Interested parties may file protests, motions to intervene, or comments by April 10 2026. No fee is required for these filings, and FERC encourages electronic submissions through its eFiling system. The process allows landowners, ratepayers, residents, and other stakeholders to influence the decision before the Commission reviews the request.

If no protest is filed within the deadline, the abandonment will be deemed authorized the day after the protest period ends. A protest or intervention can delay the decision and give the Commission time to consider the concerns raised.

Key Elements

• Project Scope: Abandonment of 10.58 miles of Line 16‑B supply lateral and associated meter/regulating stations (73385, 73381, 73362, 70366, 72222) in Hidalgo County, Texas.
  
• Regulatory Basis: Request made under sections 157.205 and 157.216 of the Natural Gas Act, leveraging a blanket certificate from docket CP82‑535‑000.
  
• Public Participation Window:
  
  • Protests: May be filed by any person or FERC staff; deadline 5:00 p.m. ET on April 10 2026.
    
  • Interventions: Motion to intervene must be filed by the same deadline; intervenors gain rights to challenge orders and request rehearings.
    
  • Comments: Open to all; deadline April 10 2026.
    
• Filing Process:
  
  • Electronic filing via FERC’s eFiling portal (new users must register).
    
  • Paper filings accepted at the Commission’s Washington, D.C., or Rockville, MD addresses.
    
  • All submissions must reference docket number CP26‑78‑000.
    
• No Filing Fees: Protests, interventions, and comments are free of charge.
  
• Service List: Intervenors will be added to the Commission’s service list and receive copies of all documents filed in the proceeding.
  
• Outcome if Unchallenged: Without a protest or intervention, the abandonment will be authorized effective the day after the protest period ends.

EPA Unveils New Environmental Impact Statements: A Window into Energy, Water, and Wildland Futures

Overview

On February 13 2026, the Environmental Protection Agency (EPA) published a notice in the Federal Register announcing the availability of several Environmental Impact Statements (EISs) filed by other federal agencies. The notice underscores EPA’s statutory duty under the Clean Air Act to review and publicly comment on EISs that could affect air quality, and it provides a central portal for accessing those comments. By making the comments available, EPA facilitates transparency and allows stakeholders—including scientists, industry, and the public—to see how federal decisions may influence environmental and resource management.

The notice lists four specific EISs: a final EIS from the Federal Energy Regulatory Commission (FERC) on the Anderson Dam hydroelectric project in California; a draft watershed plan EIS from the U.S. Department of Agriculture’s Natural Resources Conservation Service (NRCS) for the Milk River and St. Mary River watersheds in Montana; and two final supplement EISs from the Tennessee Valley Authority (TVA) concerning the continued operation of the Cumberland and Kingston fossil plants in Tennessee. Each entry includes the EIS number, agency, status (final or draft), and contact information for further inquiries.

For geoscientists, energy analysts, and natural resource professionals, this notice signals upcoming opportunities to review detailed assessments of hydropower, watershed management, and coal‑plant operations. The public comment periods—ending March 16 for the Anderson Dam EIS and March 30 for the NRCS watershed plan—invite input that could shape project design, mitigation measures, and regulatory approvals. EPA’s role in synthesizing these comments and ensuring compliance with environmental standards highlights the interconnectedness of federal agencies in safeguarding air, water, and land resources.

Key Elements

• EPA’s Review Mandate: Under Section 309(a) of the Clean Air Act, EPA must publicly comment on EISs that could impact air quality, ensuring that air‑emission considerations are integrated into project decisions.
• Public Comment Access: EPA’s comment letters are archived online at the EPA EIS portal, enabling researchers and stakeholders to examine the agency’s assessments and recommendations.
• EIS Highlights:
  • FERC, CA – Anderson Dam Hydroelectric Project: Final EIS addressing dam retrofit and potential surrender of the hydroelectric exemption.
  • NRCS, MT – Milk River & St. Mary River Watersheds: Draft EIS evaluating watershed management plans and their environmental impacts.
  • TVA, TN – Cumberland & Kingston Fossil Plants: Final supplement EISs reviewing continued operation and associated emissions.
• Comment Periods:
  
  • Anderson Dam EIS: Review period ends March 16 2026.
    
  • NRCS Watershed Plan EIS: Comment period ends March 30 2026.
• Contact Points: Each EIS lists a primary contact—ranging from EPA’s Office of External Affairs to TVA’s project managers—providing direct lines for inquiries or clarification.
• Implications for Stakeholders: The notice invites input on project feasibility, environmental mitigation, and compliance with federal environmental statutes, influencing future energy production, water resource management, and ecological conservation efforts.

U.S. Delays Decision on Indian Chromium Trioxide Trade Investigation

Overview
On December 29 2025 the U.S. Department of Commerce opened a countervailing duty (CVD) investigation into imports of chromium trioxide from India. Chromium trioxide is a key industrial chemical used in the production of pigments, dyes, and certain specialty materials, and its supply chain is of interest to geoscientists and mineral‑resource professionals who monitor global commodity flows. The investigation seeks to determine whether Indian producers are receiving unfair subsidies that distort U.S. markets.

The preliminary determination—an early assessment of whether duties should be imposed—was originally due by March 4 2026, 65 days after the investigation’s launch. On February 4 2026, the petitioner, American Chrome & Chemical, Inc., requested a postponement, arguing that the case is “extraordinarily complicated” and that additional time is needed to build a robust record. The Department granted the request, extending the deadline to May 8 2026, 130 days after the investigation began. The final determination will still be issued 75 days after the new preliminary deadline.

For stakeholders, the delay means a longer period of uncertainty for U.S. manufacturers, exporters, and suppliers of chromium trioxide. It also provides the industry and trade partners more time to gather evidence, negotiate, and prepare for potential tariff adjustments that could affect pricing, supply chains, and investment decisions in the broader mineral‑resource sector.

Key Elements

• Investigation Initiated: December 29 2025, targeting chromium trioxide imports from India.
  
• Preliminary Determination Deadline: Originally March 4 2026; now postponed to May 8 2026.
  
• Postponement Basis: Section 703©(1) of the Tariff Act allows delay if the petitioner requests it or if the investigation is “extraordinarily complicated.”
  
• Petitioner: American Chrome & Chemical, Inc., which submitted a timely request on February 4 2026.
  
• Legal Framework: 19 CFR 351.205(e) governs the postponement request; 19 CFR 351.210(b)(1) sets the final determination timeline.
  
• Final Determination: Must be issued within 75 days after the new preliminary deadline (i.e., by early July 2026).
  
• Notification: The Department issued a formal notice on February 13 2026, informing all interested parties of the new schedule.
  
• Implications for Trade: Potential tariff adjustments could alter the cost structure for U.S. producers and consumers of chromium‑based products, influencing global commodity markets and investment in mineral‑resource extraction.

Extension Request for Columbia Gas Transmission’s Pennsylvania Pipeline Project

Overview

Columbia Gas Transmission, LLC (Columbia) has asked the Federal Energy Regulatory Commission (FERC) to grant an extension of time until May 1, 2026 to complete construction of a new injection/withdrawal well, connecting pipeline, and associated facilities at its Donegal Storage Field in Washington County, Pennsylvania. The request follows a seven‑month delay in securing a storage drilling permit from the Pennsylvania Department of Environmental Protection (PADEP), which postponed the start of construction from the originally planned September 15, 2025.

The notice invites public comment and potential intervention by interested parties. FERC will consider whether Columbia has demonstrated “good cause” for the extension, but will not revisit earlier decisions such as the issuance of the certificate of public convenience and necessity or the environmental analysis required under the National Environmental Policy Act (NEPA). If the request is uncontested, the Commission’s Director of Energy Projects will issue an order; if contested, an order is expected within 45 days.

For stakeholders in geoscience, energy, and natural resource fields, this extension highlights the regulatory interplay between state permitting, federal oversight, and project timelines for natural gas infrastructure. It underscores how permitting delays can cascade into extended construction schedules and the importance of timely public participation in the regulatory process.

Key Elements

• Project Scope: New injection/withdrawal well, connecting pipeline, and appurtenant facilities at Donegal Storage Field.
• Requested Deadline: May 1, 2026, to bring the project into service.
• Reason for Delay: Extended PADEP review and multiple comment rounds on the storage drilling permit.
• Current Status: Construction began September 15, 2025; remaining work includes drilling Well 12653, installing pipeline, and final tie‑ins.
• Comment Period: 15‑day window ending 5:00 p.m. Eastern Time, February 24, 2026.
• Intervention Process: Parties may file motions to intervene under FERC Rules of Practice and the Natural Gas Act.
• Regulatory Context: FERC will not re‑evaluate the original certificate or NEPA analysis; focus is solely on the extension request.
• Decision Timeline: Uncontested requests handled by the Director of Energy Projects; contested requests addressed within 45 days.
• Public Participation: Encouragement of electronic filings via FERC’s eFile system; paper filings accepted with proper docket reference.

Polar Bears and Legacy Well Remediation: A One‑Year Incidental Harassment Authorization

Overview

The U.S. Fish and Wildlife Service (FWS) has issued a draft environmental assessment proposing an Incidental Harassment Authorization (IHA) for the Southern Beaufort Sea (SBS) stock of polar bears during oil‑well remediation activities on the North Slope of Alaska. The authorization would allow the Bureau of Land Management (BLM) to take up to ten polar bears by Level B harassment (behavioral disturbance) over a one‑year period, beginning in winter 2025‑2026. No Level A harassment (injury) or lethal take is authorized.

The proposed activities include plugging and reclaiming a legacy well (East Simpson #1), soil sampling, constructing snow trails, pads, and an airstrip, and conducting summer cleanup. The FWS estimates that these activities will result in a negligible impact on the SBS polar bear population, with no expected adverse effects on subsistence hunting by Alaska Native communities.

The draft assessment invites public comment until March 16, 2026. If finalized, the IHA will require the BLM to implement a suite of mitigation, monitoring, and reporting measures designed to minimize disturbance to polar bears and to protect subsistence use.

Key Elements

• Authorized Take

  • Up to 10 polar bears may be taken by Level B harassment (behavioral disturbance) during the 1‑year authorization period.
    
  • No Level A harassment or lethal take is authorized.

• Specified Activities

  • Well plugging and reclamation of East Simpson #1.
    
  • Soil sampling and characterization.
    
  • Snow trail, pad, and airstrip construction (≈ 281 km of snow trails, 1.6 km airstrip).
    
  • Summer cleanup and inspections (helicopter operations, ground cleanup).

• Mitigation Measures

  • Aerial infrared (AIR) surveys of potential polar bear dens before winter and early spring.
    
  • 1.6‑km exclusion zones around identified dens during the denning season.
    
  • Minimum flight altitude of 457 m (1,500 ft) over polar bear concentrations; no flights below 457 m within 805 m of an observed bear.
    
  • Attractant management: wildlife‑resistant waste receptacles, daily food waste incineration, secure storage of hazardous materials.
    
  • Polar bear safety, awareness, and interaction plan (training, monitoring, reporting).

• Monitoring & Reporting

  • Continuous on‑site observation of polar bears and potential dens.
    
  • Weekly progress reports and 48‑hour incident reports to FWS.
    
  • Final monitoring report within 90 days after IHA expiration.

• Subsistence Use

  • The FWS finds no unmitigable adverse impact on the availability of polar bears for subsistence hunting by local Alaska Native communities.
    
  • A Plan of Cooperation (POC) will be developed if community concerns arise.

• Regulatory Context

  • Marine Mammal Protection Act (MMPA): small‑number, negligible‑impact findings support the IHA.
    
  • Endangered Species Act (ESA): intra‑service consultation will confirm no jeopardy to threatened or endangered species.
    
  • National Environmental Policy Act (NEPA): a draft environmental assessment is sufficient; no environmental impact statement required.
    
  • Paperwork Reduction Act: no new information collection beyond existing IHA requirements.

• Comment Period

  • Public comments are accepted until March 16, 2026 via Regulations.gov or the FWS contact listed in the notice.

Wyoming Takes the Lead on Non‑Uranium Source Material Regulation

Overview

The U.S. Nuclear Regulatory Commission (NRC) has issued a notice inviting public comment on a proposed amendment to its existing agreement with the State of Wyoming. The amendment would transfer NRC regulatory authority over source material recovered from any mineral resources that are processed for purposes other than extracting uranium or thorium. Under the current 2018 agreement, Wyoming already regulates byproduct material and source material associated with uranium‑thorium milling; the new amendment expands that scope.

NRC staff have reviewed Wyoming’s regulatory program and concluded that the state’s Department of Environmental Quality has the necessary personnel, regulations, and procedures to protect public health and safety. The assessment confirms that Wyoming’s program is compatible with NRC standards and meets the criteria set out in the Atomic Energy Act and NRC policy statements. The NRC will retain authority over certain byproduct materials, special nuclear material, and other activities that remain under federal jurisdiction.

The NRC is seeking comments through March 2, 2026. If approved, the amendment would become effective on a date to be determined, superseding the 2018 agreement and allowing Wyoming to issue its own licenses, conduct inspections, and enforce regulations for the newly covered source material.

Key Elements

• Expanded Regulatory Scope – Wyoming will assume NRC authority over source material from minerals processed for non‑uranium purposes (e.g., coal, oil shale, or other minerals).
  
• Retention of Federal Authority – The NRC will keep control of byproduct material under certain sections of the Atomic Energy Act, special nuclear material, and activities related to enrichment, export, and disposal.
  
• Program Adequacy – Wyoming’s staff (≈3 full‑time professionals) meet NRC criteria for education, experience, and training in radiation protection.
  
• Regulatory Compatibility – Wyoming’s regulations mirror NRC’s 10 CFR parts 19, 20, 40, 61, 71, and 150, ensuring consistent licensing, inspection, and enforcement procedures.
  
• Cooperation & Reciprocity – The agreement includes provisions for information exchange, joint standard‑setting, and reciprocal recognition of licenses between the NRC and Wyoming.
  
• Public Comment Period – Stakeholders can submit written comments by March 2, 2026, influencing the final agreement and NRC’s regulatory approach.
  
• Compliance Oversight – The NRC will periodically review Wyoming’s performance and may suspend or terminate the agreement if public‑health or safety standards are not met.
  

This amendment represents a significant shift in how radioactive source material is regulated in Wyoming, potentially streamlining state oversight while maintaining federal safeguards for high‑risk materials.

U.S. Eyes China’s Undersea Ambitions: Public Hearing on Sea‑Domain Competition

Overview

The U.S.-China Economic and Security Review Commission (USCC) has announced a public hearing scheduled for March 2, 2026 at 9:15 a.m. in Washington, D.C., with a live webcast available on the commission’s website. The hearing, titled “Part of Your World: U.S.-China Competition Under the Sea,” is part of the commission’s annual mandate to assess the national‑security implications of the U.S.–China economic relationship.

The focus will be on China’s expanding capabilities in the undersea domain—particularly submarine cable networks, seabed mining, and the deployment of emerging technologies that could erode U.S. maritime and cyber‑security advantages. Experts will examine how these developments affect U.S. interests in the Indo‑Pacific, the protection of critical infrastructure, and the future of deep‑sea resource extraction.

Members of the public, including scientists, engineers, and industry stakeholders, can attend in person near the U.S. Capitol or view the session online. Written statements may be submitted by the hearing date, and a Q&A period will allow commissioners to engage directly with witnesses and participants.

Key Elements

• Date & Time: March 2, 2026, 9:15 a.m.
  
• Location: Washington, D.C. (specific room to be announced) and live webcast at uscc.gov.
  
• Topic: U.S.–China competition in the undersea domain, covering submarine cables, seabed mining, and emerging technologies.
  
• Co‑chairs: Chair Randall Schriver and Vice Chair Michael Kuiken.
  
• Public Participation: No reservation required; written statements accepted until the hearing date.
  
• Geoscience & Resource Focus: Examination of China’s undersea infrastructure and deep‑sea resource extraction strategies, with implications for U.S. mineral resource security and trade.
  
• National Security Lens: Assessment of how undersea capabilities may influence U.S. maritime security, cyber‑infrastructure, and Indo‑Pacific strategic balance.
  
• Contact: Jameson Cunningham, 444 North Capitol Street NW, Suite 602, Washington, DC 20001; phone 202‑624‑1496; email jcunningham@uscc.gov.

EPA Corrects Superfund Site Name After Deletion from the National Priorities List

The Environmental Protection Agency (EPA) issued a correction to a final rule published on March 5, 2025 that removed one site and partially removed three sites from the Superfund National Priorities List (NPL). The correction addresses an inadvertent error in the name of the deleted site, ensuring that the official record accurately reflects the company involved.

The affected site is Lawrence Aviation Industries, Inc., located in Port Jefferson Station, New York. In the original rule the company’s name was mistakenly listed as “Lawrence Aviation, Inc.” The amendment updates Appendix B of 40 CFR Part 300 to reflect the correct name and confirms the partial deletion status of the site.

This change does not alter any existing cleanup responsibilities, funding allocations, or regulatory requirements for the site. It simply corrects the public record to avoid confusion for stakeholders, including local communities, environmental scientists, and regulatory agencies that rely on the NPL for information about hazardous waste sites.

Key Elements

• Correction of Site Name – The EPA amends the NPL entry to read “Lawrence Aviation Industries, Inc.” instead of the erroneous “Lawrence Aviation, Inc.”
  
• Partial Deletion Status – The site remains partially deleted (denoted by “P” in the NPL table), indicating that cleanup activities are still ongoing or that certain portions of the site are excluded from the deletion.
  
• Effective Date – The correction takes effect on February 12, 2026, while the original deletion rule was applicable from March 5, 2025.
  
• Docket Information – The action is under EPA‑HQ‑OLEM‑2024‑0294 (FRL‑12112‑03‑OLEM), with all related documents available on Regulations.gov.
  
• No Change to Environmental Obligations – The amendment does not modify cleanup schedules, funding, or regulatory enforcement actions for the site.
  
• Contact Points – EPA Region 2 and Headquarters staff are listed for inquiries, ensuring transparency and accessibility for stakeholders.

Glendale Superfund Site: New 2030 Deadline for Cleanup Work and Delayed Completion Certificate

Overview

In 1999, the United States and the State of California sued several parties under the Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA) for groundwater contamination at the Glendale North and South Operable Units of the San Fernando Valley Superfund Site. A consent decree was entered in 2000, obligating the defendants—known as Settling Work Defendants—to perform cleanup activities in coordination with the City of Glendale.

On February 4, 2026, the Department of Justice lodged a proposed Third Joint Stipulation to modify that consent decree. The modification extends the period during which the Settling Work Defendants and the City must continue their respective cleanup work until November 30, 2030 and requires that no Certificate of Completion be requested before that date. The change reflects the ongoing need for remediation and the complexity of fully restoring the contaminated groundwater.

The notice invites public comment on the proposed modification. Comments must be submitted within 30 days of publication, either by email or mail, and will be considered by the Assistant Attorney General, Environment and Natural Resources Division. The public can also download the full Third Joint Stipulation from the Justice Department’s website for review.

Key Elements

• Parties involved: United States, State of California, ITT LLC and other Settling Work Defendants, City of Glendale.
  
• Location: Glendale North and South Operable Units, San Fernando Valley, California.
  
• Legal framework: CERCLA (Comprehensive Environmental Response, Compensation, and Liability Act) and the 2000 consent decree.
  
• Proposed change: Extension of cleanup work until Nov 30, 2030; no Certificate of Completion before that date.
  
• Public comment period: 30 days from publication; comments directed to the DOJ’s Environment and Natural Resources Division.
  
• Access to documents: Full Third Joint Stipulation available for download on the DOJ website.
  
• Implications for geoscience: Continued monitoring and remediation of groundwater contamination; potential for new data on hydrogeology and pollutant transport.
  
• Implications for natural resource management: Extended timeline may affect land use planning, water resource allocation, and community health assessments.

Rescission of the 2024‑2025 Antidumping Review on Ukrainian Steel Wire Rods

Overview

The U.S. Department of Commerce has formally cancelled the administrative review of the antidumping duty (AD) order on carbon and alloy steel wire rod from Ukraine for the period March 1 2024–February 28 2025. The review was initiated after industry petitioners requested it, but no qualifying imports were recorded during the review period, so the Department concluded that a review was unnecessary.

Because the review is rescinded, the existing cash‑deposit requirements for Ukrainian steel remain unchanged, and the Department will continue to assess antidumping duties on any future eligible imports at the rates equal to the cash deposit of estimated duties. The notice also reminds parties subject to an Administrative Protective Order (APO) to return or destroy proprietary information disclosed during the proceeding.

This decision has no immediate impact on U.S. steel producers or consumers, but it clarifies that the current AD order remains in force and that any future imports of Ukrainian steel wire rod will be subject to the same duty regime.

Key Elements

• Rescission of Review – The administrative review for 2024‑2025 is cancelled because no suspended entries of Ukrainian steel wire rod were found during the period.
  
• Cash Deposit Rules – No changes to cash‑deposit requirements; they remain in effect until further notice.
  
• Duty Assessment – Antidumping duties will still be assessed on future eligible imports at rates equal to the cash deposit of estimated duties.
  
• APO Compliance – Parties must return or destroy proprietary information disclosed under the APO, or convert to a judicial protective order.
  
• No Comments Received – Neither the initial review nor the intent‑to‑rescind notice elicited comments from interested parties.
  
• Timeline – The Department will issue assessment instructions to Customs and Border Protection no earlier than 35 days after publication of this notice.
  
• Legal Basis – The action follows 19 CFR 351.213(d)(3) and the Tariff Act of 1930, ensuring that the review is only conducted when there are reviewable entries.

Southern Star Seeks FERC Approval for New Well and Pipeline at Oklahoma Storage Field

Overview

On February 6 2026, Southern Star Central Gas Pipeline, Inc. filed a notice with the Federal Energy Regulatory Commission (FERC) requesting authorization to drill a vertical replacement well (Well No. 222) and install a lateral pipeline connecting that well to its existing infrastructure at the Webb Storage Field in Grant County, Oklahoma. The request is made under the Natural Gas Act’s blanket‑authorization framework, which allows the company to proceed with multiple related activities without separate approvals for each component.

The proposed project, estimated to cost $8.5 million, aims to maintain the safe, reliable, and compliant operation of the Webb Storage Field. The new well will replace an aging unit, while the lateral pipeline will link it to the company’s existing network, improving operational efficiency and reducing the need for surface disruptions. Detailed technical and environmental information is available in the public docket (CP26‑77‑000) and can be accessed through FERC’s eLibrary.

FERC has opened a public participation window, allowing stakeholders to file protests, motions to intervene, or comments. All submissions must be received by 5:00 p.m. Eastern Time on April 7 2026. The notice explains how to file electronically or by paper, outlines the rights of intervenors, and provides contact information for assistance.

Key Elements

• Blanket Authorization: Southern Star is invoking its existing blanket certificate (CP82‑479‑000) to streamline approval for the replacement well and lateral pipeline.
  
• Project Scope:
  
  • Drill vertical replacement well (Well No. 222).
    
  • Construct a lateral pipeline to connect the well to the Webb Storage Field infrastructure.
    
  • Install associated appurtenant facilities.
    
• Estimated Cost: $8.5 million, covering drilling, pipeline installation, and related infrastructure.
  
• Geoscience Impact:
  
  • Involves subsurface drilling in Grant County, Oklahoma, with potential effects on local geology and groundwater.
    
  • Pipeline routing will be evaluated for environmental compliance and minimal surface disturbance.
    
• Public Participation Deadlines:
  
  • Protests, motions to intervene, and comments due by 5:00 p.m. ET on April 7 2026.
    
• Filing Procedures:
  
  • Electronic filing via FERC’s eFiling system or paper submissions to the Commission’s address.
    
  • Protestors may also serve as intervenors if they state that intent.
    
• Intervention Rights: Intervenors gain the right to request rehearings and challenge Commission orders in federal appellate courts.
  
• Information Access: Full docket documents, including the request and supporting materials, are available in PDF and Word formats on FERC’s eLibrary.
  
• Contact Points:
  
  • Southern Star: Jennifer Matthews, Manager, Regulatory (phone (270) 316‑2972).
    
  • FERC Office of Public Participation: (202) 502‑6595.
    

These provisions outline the regulatory framework, project details, and avenues for stakeholder engagement relevant to geoscience, energy infrastructure, and natural resource management.

Anderson Dam Gets a Green‑Light: Final Environmental Review Released

The Federal Energy Regulatory Commission (FERC) has published the final Environmental Impact Statement (EIS) for the Santa Clara Valley Water District’s proposed retrofit of the Anderson Dam and the surrender of its exemption status. The EIS, completed under the National Environmental Policy Act (NEPA), evaluates the environmental consequences of upgrading the dam’s structure and power‑generation facilities, as well as the implications of relinquishing the exemption that currently exempts the project from certain federal oversight.

The Anderson Dam, located on Coyote Creek in Santa Clara County, California, is a 240‑foot‑high, 1,385‑foot‑long concrete structure that creates a reservoir covering up to 1,240 acres and storing 89,278 acre‑feet of water. The proposed retrofit includes strengthening the dam, installing a new 54‑inch penstock, and expanding the 800‑kW powerhouse. Surrendering the exemption would bring the project fully under FERC’s regulatory framework, potentially affecting water rights, power sales, and environmental monitoring requirements.

Stakeholders—including local residents, environmental groups, Native‑American tribes, and the water district—contributed comments during the public comment period. The final EIS documents the Commission’s assessment of alternatives, cumulative impacts on water quality, fish and wildlife habitats, recreation, and downstream water users, and outlines mitigation measures to address identified concerns.

Key Elements

• Dam Retrofit Scope: Structural reinforcement, new penstock, expanded powerhouse, and 100‑foot transmission line to the grid.
  
• Exemption Surrender: Transition from exempt status to full FERC regulation, affecting licensing, reporting, and compliance obligations.
  
• Environmental Impact Assessment: NEPA‑compliant analysis covering water quality, fish and wildlife, recreation, and downstream water use.
  
• Stakeholder Input: Public comments, tribal consultations, and NGO feedback incorporated into the final EIS.
  
• Access to the EIS: Available online via FERC’s eLibrary and in PDF form on the Federal Register website.
  
• Regulatory Context: Project governed by 18 CFR Part 380, with implications for water rights, power generation, and environmental monitoring.
  
• Potential Benefits: Improved dam safety, increased renewable energy generation, and enhanced water storage capacity.
  
• Mitigation Measures: Proposed actions to protect fish habitats, maintain water quality, and preserve recreational opportunities.

FEMA’s Disaster Case Management Data Collection Reinstated—A Call for Public Input

Overview

The Federal Emergency Management Agency (FEMA) has announced the reinstatement of its Disaster Case Management (DCM) information collection, a tool that guides case managers in gathering data from survivors after major disaster declarations. The collection, which was previously approved under OMB No. 1660‑0152, will be resubmitted to the Office of Management and Budget (OMB) for clearance under the Paperwork Reduction Act. FEMA invites the public to comment on the collection’s necessity, burden, and potential improvements during a 30‑day comment period ending March 13, 2026.

The DCM program collects detailed information on survivors’ unmet needs—such as food, shelter, medical care, emotional support, and home repair—through two forms: the intake form (FF‑104‑FY‑21‑146) and a consent form (FF‑104‑FY‑21‑147). Case managers use these forms to identify resources and referrals, then enter the data into a secure electronic database. The program is expected to involve roughly 30,750 respondents annually, with an estimated 19,680 burden hours and a federal cost of about $51.7 million.

For professionals in geosciences, environmental science, and natural resource management, this data collection is critical. It provides insights into how disasters affect land use, infrastructure, and resource availability, informing recovery strategies and policy decisions that shape the resilience of ecosystems and communities.

Key Elements

• Reinstatement of the FEMA‑Administered Disaster Case Management information collection (OMB No. 1660‑0152).
  
• Purpose: to guide case managers in collecting data on survivors’ disaster‑caused unmet needs and to facilitate referrals to available resources.
  
• Forms Used:
  
  • FF‑104‑FY‑21‑146: DCM Intake Form.
    
  • FF‑104‑FY‑21‑147: Consent Form.
    
• Estimated Impact:
  
  • 30,750 respondents per year.
    
  • 19,680 burden hours.
    
  • $51,693,869 annual federal cost.
    
• Comment Period: 30 days, closing March 13, 2026.
  
• Data Elements: food, clothing, shelter, first aid, emotional/spiritual care, household items, home repair, rebuilding, etc.
  
• Data Handling: survivors sign consent; case managers enter data into a secure database; potential for electronic submission to reduce burden.
  
• Relevance to Geoscience & Natural Resources: informs recovery planning, land‑use changes, environmental impact assessments, and resource allocation after events like floods, hurricanes, and earthquakes.
  
• Public Participation: comments can influence the collection’s design, burden estimates, and the adoption of automated or electronic collection methods.
  
• Contact for Comments: FEMA‑Information‑Collections‑Management@fema.dhs.gov or via Regulations.gov (Docket FEMA‑2025‑0047).