Geoscience and Policy Intersections

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

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

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

• Storm and Impact

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

• SBA Disaster Numbers

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

• Loan Types & Interest Rates

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

• Application Process

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

• Timeline

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

• Scope

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

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

US Forest Service Seeks Feedback on Nationwide Woodland Owner Survey Renewal

Overview

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

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

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

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

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

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

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

Key Elements

• Revised EIS Schedule

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

• Stakeholder Engagement

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

• Scope of the EIS

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

• Regulatory Context

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

• Implications for Energy and Water Resources

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

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

Overview

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

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

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

Key Elements

• Purpose & Authority

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

• Scope of Operations Covered

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

• Core Forms & Permits

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

• Reporting & Monitoring Requirements

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

• Environmental & Safety Data

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

• Confidentiality & Public Disclosure

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

• Stakeholder Engagement

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

• Administrative Details

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

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

Overview

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

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

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

Key Elements

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

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

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

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

Key Elements

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

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

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

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

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

Key Elements

• Final Dumping Margins

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

• Assessment Rates

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

• Cash Deposit Requirements

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

• Timeline

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

• Administrative Protective Order (APO) Reminder

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

• Implications for the Aluminum Supply Chain

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

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

Overview

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

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

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

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

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

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

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

Key Elements

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

Building Safer Communities: The New Wildfire Resilience Grant Act

Overview

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

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

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

Key Elements

• Grant Program Structure

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

• Eligibility & Prioritization

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

• Cost‑Sharing & Local Preference

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

• Plan Requirements

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

• Reporting & Oversight

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

• Structure Hardening Amendment

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

• Definitions

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

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

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

Overview

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

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

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

Key Elements

• Temporary Flaring Limits

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

• NHV Monitoring Requirements

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

• Record‑Keeping & Reporting

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

• Other Technical Clarifications

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

• Economic & Regulatory Context

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

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

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

Overview

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

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

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

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

Overview

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

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

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

Overview

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

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

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

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

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

Streamlining Oil & Gas Royalty Reporting on the Outer Continental Shelf

Overview

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

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

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

Key Elements

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

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

Overview

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

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

Key Elements

• Survey Scope

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

• Estimated Takes

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

• Mitigation Measures

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

• Environmental and Regulatory Assessment

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

• Public Comment Period

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

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

Wyoming Proposes New Reclamation Bond Rules for Coal Mining

Overview

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

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

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

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

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

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

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

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

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

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

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

Key Elements

• Project Scope

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

• Environmental Findings

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

• Regulatory Context

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

• Public Participation

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

• Next Steps

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

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

Overview

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

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

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

NOAA Extends Public Comment Deadline for Deep-Seabed Mining Licenses

Overview

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

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

• Dates & Format

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

• Public Participation

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

• Agenda Highlights

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

• Accessibility & Support

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

• Follow‑Up Procedures

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

• Contact Points

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

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

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

Overview

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

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

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

Key Elements

• Project Scope

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

• Relicensing Objectives

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

• Procedural Timeline

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

• Public Access & Participation

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

• Environmental Review Status

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

• Stakeholder Engagement

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

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

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

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

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

Draft Environmental Review Opens for the New Kosciusko Junction Pipeline

Overview

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

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

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

Key Elements

• Project Scope

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

• Environmental Assessment

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

• Public Participation

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

• Regulatory Context

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

• Mitigation Measures

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

• Stakeholder Impact

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

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

Overview

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

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

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

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

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

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

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

Key Elements

• Project Scope

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

• Operation Mode

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

• Location & Land Use

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

• Regulatory Framework

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

• Timeline

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

• Filing Instructions

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

• Public Participation Resources

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

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

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

Overview

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

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

Key Elements

• Scope of NDZs:

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

• Information Required from States:

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

• Administrative Burden:

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

• Public Participation:

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

• Legal Basis:

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

• Implications for Geoscience and Natural Resource Fields:

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

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

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

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

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

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

Overview

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

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

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

Key Elements

• ICE Pact Components

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

• Shipyard Capacity Assessment

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

• Economic and Community Impact

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

• Supply Chain and Small‑Business Participation

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

• Technology and Innovation Priorities

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

• Testing and Facilities Needs

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

• Intellectual Property and Export Controls

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

• Procurement and Financing Structures

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

• Lessons Learned and Cooperation Models

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

• Future Planning and Research

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

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

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

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

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

Key Elements

• Compensation Scope

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

• Eligibility Criteria

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

• Administrative Process

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

• Payment and Acceptance

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

• Judicial Review

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

• Reporting and Funding

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

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

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

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

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

Key Elements

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

USDA Unifies NEPA Rules to Streamline Environmental Reviews Across Agriculture and Rural Development

Overview

In April 2026 the U.S. Department of Agriculture (USDA) finalized a sweeping update to its National Environmental Policy Act (NEPA) regulations, replacing seven agency‑specific rules with a single, department‑wide framework (7 CFR 1b). The new rules eliminate references to the now‑rescinded Council on Environmental Quality (CEQ) guidance, incorporate recent statutory changes—including the Fiscal Responsibility Act of 2023—and reflect the Supreme Court’s 2025 decision that courts should give agencies greater deference to NEPA analyses.

The update clarifies the roles of USDA’s senior officials, designates the Deputy Secretary as the senior agency official for NEPA oversight, and requires an annual congressional report on any missed environmental assessment (EA) or environmental impact statement (EIS) deadlines. By consolidating procedures, the USDA aims to reduce duplication, speed up project approvals, and provide clearer guidance for stakeholders in agriculture, rural development, and natural resource management.

For geoscientists, energy and mineral resource professionals, and other natural‑resource practitioners, the new rules mean a more predictable and consistent environmental review process. Projects that previously had to navigate multiple sets of NEPA requirements will now follow a single, streamlined set of procedures, while still maintaining rigorous protection of the environment and compliance with other federal laws.

Key Elements

• Single Department‑wide NEPA Framework – 7 CFR 1b replaces seven agency‑specific rules, simplifying compliance across USDA.
  
• Removal of CEQ References – The rules no longer cite the rescinded CEQ regulations, reflecting the statutory authority of NEPA itself.
  
• Senior Agency Oversight – The Deputy Secretary is the designated senior agency official for NEPA, ensuring unified leadership and accountability.
  
• Congressional Reporting – USDA must annually report to Congress on any missed EA or EIS deadlines, enhancing transparency.
  
• Categorical Exclusions (CEs) Across Agencies – A single set of CEs applies to all USDA subcomponents, allowing routine, low‑impact actions to bypass full reviews while still permitting extraordinary‑circumstance checks.
  
• Emergency‑Action Guidance – Updated provisions allow USDA to act swiftly in emergencies, with clear criteria for when a full NEPA analysis is required.
  
• Reliance on Prior Analyses – USDA can rely on existing environmental studies (e.g., from other agencies or prior USDA work) if they are substantially the same, with proper documentation.
  
• Comment‑Handling and Transparency – Subcomponents must publish substantive comments, document responses, and provide unique identification numbers for all EAs and EISs.
  
• Clear Definitions of “Extraordinary Circumstances” – The rules specify that a CE is only overridden when uncertainty exists about a significant impact on sensitive resources.
  
• Streamlined Documentation Formats – EAs and EISs must follow concise page limits and standardized formatting, reducing paperwork while preserving scientific integrity.
  

These provisions collectively aim to make USDA’s environmental review process more efficient, consistent, and responsive to the needs of stakeholders in agriculture, energy, mineral resources, and related geoscience fields.

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

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

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

Key Elements

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

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

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

Overview

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

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

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

Key Elements

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

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

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

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

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

Key Elements

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

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

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

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

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

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

Overview

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

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

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

Key Elements

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

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

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

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

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

Key Elements

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

Ohio Grants Final Authority to Update Its Hazardous‑Waste Program

Overview

The U.S. Environmental Protection Agency (EPA) has finalized its approval of Ohio’s revised hazardous‑waste management program under the Resource Conservation and Recovery Act (RCRA). The decision, effective April 2 2026, confirms that Ohio’s new rules are equivalent to, consistent with, and no less stringent than the federal RCRA requirements. The revisions cover a broad range of technical provisions— from emission limits for treatment facilities to record‑keeping and closure requirements— and were developed after a public comment period that addressed concerns about transparency, enforcement, and potential impacts on water quality and interstate commerce.

For geoscientists, energy and mineral resource developers, and environmental professionals, the authorization means that Ohio’s state‑level permitting and compliance framework will now be fully recognized by the EPA. Facilities operating in Ohio can rely on the state’s rules for hazardous‑waste treatment, storage, and disposal (TSD) permits, while the EPA retains oversight authority to enforce the program and to coordinate with the state on corrective actions and environmental monitoring.

Key Elements

• Final Authorization – EPA grants Ohio the authority to administer its hazardous‑waste program in lieu of the federal program, effective April 2 2026.
  
• Equivalence & Consistency – Ohio’s revisions meet RCRA’s criteria for equivalence, consistency with federal and other state programs, and adequate enforcement.
  
• Broad Rule Updates – Changes include new organic‑air emission standards, updated permit and record‑keeping requirements, and clarified definitions for terms such as “permit” and “contained.”
  
• Enforcement & Oversight – EPA maintains the right to inspect, enforce, and require corrective action at Ohio TSD facilities, ensuring compliance with both state and federal standards.
  
• No New Burdens – The authorization does not impose additional regulatory or financial burdens on small entities, local governments, or tribal communities.
  
• PFAS & Water Quality – The rule does not address PFAS regulation; it reaffirms that hazardous‑waste facilities remain subject to strict controls to prevent releases into water bodies.
  
• Public Participation – The process included a 65‑day comment period, with EPA responding to ten substantive comments and updating the Memorandum of Agreement with Ohio EPA.
  
• Codification – While the rules are not yet codified in the Code of Federal Regulations, EPA reserves the right to do so in the future.
  
• Executive Order Exemptions – The action is exempt from several federal executive orders and does not trigger significant economic or environmental impacts.
  

This final authorization strengthens Ohio’s capacity to manage hazardous waste responsibly while aligning state practices with national environmental protection standards.

FERC Sets New Timeline for Lowell Hydroelectric Project’s Relicense Process

Overview

Boott Hydropower, LLC has sought a new major license to keep its 15‑megawatt Lowell Hydroelectric Project operating on the Merrimack River in Massachusetts. The company first filed the application in April 2021, amended it in June 2025, and received a procedural schedule from the Federal Energy Regulatory Commission (FERC) in July 2025. That schedule originally anticipated a “Ready for Environmental Analysis” notice by March 2026.

On March 30 2026, FERC issued a revised procedural schedule, moving the environmental‑analysis readiness date to May 2026. The notice confirms that the commission will continue to adjust the timetable as needed and invites public comments on the updated plan. The change reflects the commission’s ongoing assessment of the project’s environmental, technical, and regulatory requirements.

For stakeholders—including local communities, environmental groups, and the energy sector—this update signals a clear next step in the licensing process. It also underscores the importance of hydropower as a renewable resource while ensuring that environmental safeguards remain a priority before the project can proceed.

Key Elements

• Project Details: 15.012‑MW Lowell Hydroelectric Project, located on the Merrimack River, Massachusetts.
  
• Licensing Timeline:
  
  • Initial application filed: April 30 2021.
    
  • Amendment submitted: June 20 2025.
    
  • Original procedural schedule: Ready for Environmental Analysis by March 2026.
    
  • Revised schedule: Ready for Environmental Analysis by May 2026.
    
• FERC Role: Issued a notice of revised procedural schedule (Document 2026‑06430) and may further adjust dates as appropriate.
  
• Public Participation: Notice invites comments on the updated schedule; inquiries can be directed to Bill Connelly (202‑502‑8587).
  
• Implications: The May 2026 date marks the point at which the project will undergo a comprehensive environmental review, a critical step before any final licensing decision.
  
• Regulatory Context: The notice is issued under 18 CFR 2.1, reflecting FERC’s authority to manage the licensing process for interstate electric transmission and generation facilities.

Morrisville Hydroelectric Settlement Meeting: Balancing Power, Water, and Conservation

Overview

The Village of Morrisville, Vermont, has convened a virtual meeting on April 15, 2026, to discuss a settlement agreement concerning the Morrisville Hydroelectric Project. The agreement, filed on February 13, 2026, involves the Village, the Vermont Agency of Natural Resources (ANR), the Vermont Natural Resources Council, the Vermont Council of Trout Unlimited, and American Whitewater. Its purpose is to outline the steps required to relicens the hydroelectric facility while ensuring compliance with environmental standards and water‑quality protections.

Key objectives of the meeting include reviewing the settlement’s proposed measures, presenting a schedule for meeting the ANR’s August 9, 2016 water‑quality certification, and detailing an Interim Flow Management Plan that specifies how river flows will be managed during the relicensing process. The discussion will also cover timelines for implementing these measures and allow stakeholders to provide feedback.

The meeting reflects a collaborative effort among local, state, and federal agencies, as well as environmental and recreational groups, to balance the village’s renewable energy interests with the ecological health of the local watershed. Participation is open to all interested parties, and the virtual format aims to facilitate broad engagement.

Key Elements

• Meeting Details: April 15, 2026, 10:30 a.m.–12:00 p.m. EDT, held virtually via Microsoft Teams.
  
• Participants: Village of Morrisville, Vermont ANR, Vermont Natural Resources Council, Vermont Council of Trout Unlimited, American Whitewater, and other interested parties.
  
• Agenda:
  
  1. Presentation of the settlement agreement and its purpose.
     
  2. Discussion of the Village’s proposed schedule to satisfy the ANR’s water‑quality certification.
     
  3. Overview of the Interim Flow Management Plan, including specific measures and implementation timeline.
     
  4. Open forum for comments on proposed measures and schedules.
     
• RSVP: Contact Nicholas Ettema (Great Lakes Branch, Division of Hydropower Licensing) by 5:00 p.m. EDT on April 10, 2026, to receive participation instructions.
  
• Authority: Meeting authorized under 18 CFR 2.1.
  
• Contact: Nicholas Ettema – phone (312) 596‑4447; email (not provided).

EPA Seeks Public Input on Settlement to Clean Up Baghurst Drive Superfund Site

Overview
The U.S. Environmental Protection Agency (EPA) Region 3 has announced a proposed settlement agreement under the Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA) with Anita J. Miller concerning the Baghurst Drive Superfund Site in Upper Salford Township, Montgomery County, Pennsylvania. The agreement aims to secure long‑term EPA access to the property for ongoing monitoring and remediation activities while establishing an environmental covenant that binds the settling party to comply with cleanup obligations. In return, the EPA pledges not to pursue civil or administrative actions against Miller under CERCLA sections 106 or 107.

The settlement is currently open for public comment until May 4, 2026. EPA will review all submissions and may modify or withdraw the agreement if new information suggests it is inappropriate or inadequate. The process reflects the agency’s commitment to transparent, community‑informed decision‑making while ensuring that contaminated sites are addressed in a timely and legally sound manner.

Key Elements
- Parties Involved: EPA Region 3 and Anita J. Miller (Settling Party).
- Legal Basis: Section 122(g) of CERCLA, allowing administrative settlement agreements.
- Covenant: EPA will not sue or take administrative action against Miller for the site under CERCLA sections 106/107.
- Long‑Term Access: Miller must grant EPA continuous access to conduct responsive actions and file an environmental covenant on the property.
- Public Comment Period: 30‑day window (until May 4, 2026) for written comments; EPA may adjust the settlement based on feedback.
- Contact Information: Comments and copies of the proposed settlement can be sent electronically to the EPA’s Regional Counsel, Stephanie Tuason, or via phone at 215‑814‑2614.

Fast‑Track Permitting: Renewing the Federal Project Initiation Notice

Overview

The Federal Permitting Improvement Steering Council (Permitting Council) is seeking to restore the Office of Management and Budget (OMB) clearance for the Permitting Notice of Initiation (FIN), a key data‑collection tool under the Fixing America’s Surface Transportation Act (FAST‑41). The FIN is required for any infrastructure project that wishes to qualify for FAST‑41’s streamlined permitting program, which promises faster, more transparent environmental reviews and a shared Federal Permitting Dashboard.

The request follows the expiration of the original OMB approval in January 2021. By reinstating the clearance, the Permitting Council aims to reduce administrative delays for projects ranging from transportation corridors to energy facilities, while maintaining compliance with the Paperwork Reduction Act. The Council has opened a 30‑day public comment period ending April 30, 2026, inviting stakeholders to assess the necessity, utility, and burden of the FIN.

For geoscientists, energy developers, and natural‑resource professionals, the renewal means clearer guidance on project eligibility, a standardized set of information to submit, and a more predictable timeline for federal approvals—potentially accelerating the delivery of critical infrastructure while preserving environmental safeguards.

Key Elements

• Permitting Council: A federal body established by FAST‑41 to coordinate environmental reviews for covered projects.
• FAST‑41 Program: Voluntary framework offering expedited permitting and a Federal Permitting Dashboard for transparency.
• Permitting Notice of Initiation (FIN): Mandatory submission that outlines project purpose, feasibility, federal financing, and compliance with FAST‑41 definitions.
• OMB Control Number 3121‑0001: The clearance sought for the FIN; originally approved in 2018, transferred to the Permitting Council in 2020, and expired in 2021.
• Paperwork Reduction Act Compliance: The Council estimates a total burden of 225 hours (75 hours for initial submission, 150 hours for follow‑up) and seeks public input on reducing this load.
• Public Comment Period: 30 days (until April 30, 2026) for stakeholders to provide feedback on the collection’s necessity, utility, and burden.
• Benefits to Stakeholders: Faster permitting timelines, clearer data requirements, and enhanced collaboration among federal agencies and project sponsors.

Reclamation’s Quarterly Water Contract Update: New Deals, Repayments, and Public Participation

Overview

The U.S. Bureau of Reclamation (Reclamation) has released its quarterly status report on water‑service, repayment, and other water‑related contract actions. The notice lists all contractual activities that have been proposed, discontinued, or completed since the last publication, covering a wide range of projects across the western United States. The primary goal is to keep the public informed about how Reclamation is managing capital recovery, operating costs, and resource allocation for its extensive network of dams, reservoirs, and irrigation systems.

Reclamation’s contracts span several categories: temporary and long‑term water‑service agreements for irrigation and municipal/industrial use; repayment contracts that reimburse users for construction and operating costs; title‑transfer agreements that shift ownership of project facilities; and special arrangements such as extraordinary maintenance (XM) and emergency extraordinary maintenance (EXM). The report highlights key projects—including the Central Arizona Project, Colorado‑Big Thompson, and the Klamath and Central Valley projects—along with new agreements for water delivery, storage, and power rights.

Public participation is a cornerstone of the process. The notice explains that proposed contracts are published in accordance with Section 9(f) of the Reclamation Project Act and 43 CFR 426.22, and that the public may submit comments, attend hearings, and request contract documents. The process is coordinated with the National Environmental Policy Act and the Final Revised Public Participation Procedures, ensuring transparency and stakeholder engagement in decisions that affect water resources, land use, and regional economies.

Key Elements

• Scope of Contracts

  • Water‑service agreements (short‑term up to 5 years, long‑term up to 40 years).
    
  • Repayment contracts for construction and operating costs.
    
  • Title‑transfer agreements under the John D. Dingell Act.
    
  • Extraordinary maintenance (XM/EXM) contracts funded by Title IX of the Infrastructure Investment and Jobs Act.
    

• Geographic Coverage

  • Projects across 12 states (Arizona, Colorado, Idaho, Nevada, New Mexico, Oregon, Utah, Washington, Wyoming, California, Montana, Kansas).
    
  • Five Reclamation regions with regional offices listed for contract inquiries.
    

• Funding Sources

  • Title IX (Infrastructure Investment and Jobs Act) and Title IX, Subtitle G (Omnibus Public Land Management Act).
    
  • Public Law 111‑11 (XM funding).
    
  • State and tribal agreements (e.g., Navajo Nation, Southern Ute Tribe).
    

• Public Participation Procedures

  • Advance notice of meetings for parties with written requests.
    
  • Written comments due within specified time limits.
    
  • Availability of contract documents via Freedom of Information Act.
    
  • Coordination with NEPA and the Final Revised Public Participation Procedures.
    

• Notable Projects and Actions

  • New water‑delivery contracts for Colorado River water to Arizona and California.
    
  • Repayment agreements for the Central Arizona Project and Klamath Project.
    
  • Title transfers for the Gila Project and Hungry Horse Reservoir.
    
  • Temporary water‑service contracts for the Middle Rio Grande and San Juan‑Chama projects to support irrigation and habitat.
    

• Contact Information

  • Morgan Raymond, Reclamation Law Administration Division, Denver, CO (303‑445‑3382).
    
  • Regional offices provide detailed contract information and public comment procedures.
    

This quarterly report serves as a transparent record of how Reclamation is allocating water resources, managing financial obligations, and engaging stakeholders across the western United States.

Erie Boulevard Hydropower Eyes Safer, Smarter Spillway Upgrade

Overview

The Federal Energy Regulatory Commission (FERC) has accepted a non‑capacity amendment application from Erie Boulevard Hydropower L.P. for its Beebee Island hydroelectric project on the Black River in Jefferson County, New York. The amendment seeks to replace the existing wooden flashboards that sit atop the dam’s spillway with a new pneumatic flashboard system. This change is intended to improve operational control, enhance dam safety, and reduce the frequency of high‑flow failures that have historically plagued the wooden system.

The proposed pneumatic system will use steel plates supported by inflatable air bladders that can be raised or lowered as needed. Installation will involve a temporary drawdown of about one foot below the dam crest for roughly six weeks, after which the reservoir will return to its normal level. The project will not create new ground disturbance, will not alter the minimum flow releases, and will employ best‑management practices to minimize turbidity during construction.

FERC is inviting comments, protests, and motions to intervene from federal, state, local, and tribal agencies, as well as the general public. A water‑quality certificate under Section 401 of the Clean Water Act is required from the New York Department of Environmental Quality, and all filings must be submitted by April 29, 2026. The notice outlines electronic and paper filing procedures and emphasizes that cooperating agencies cannot intervene in the proceeding.

Key Elements

• Project Location & Status: Beebee Island Project on the Black River, Watertown, NY; non‑capacity amendment filed June 2, 2025.
  
• Amendment Purpose: Replace 3‑ft wooden flashboards with a pneumatic system to improve spillway control and dam safety.
  
• Technical Details: Steel plates on inflatable bladders; temporary 1‑ft drawdown for ~6 weeks; no new ground disturbance.
  
• Environmental Impact: Minimal turbidity during installation; no change to minimum flow releases; expected to stabilize reservoir elevation and reduce environmental fluctuations.
  
• Regulatory Requirements: Water‑quality certificate (Section 401, Clean Water Act) from NY DEQ; compliance with FERC Rules of Practice and Procedure.
  
• Public Participation: Deadline for comments, protests, and motions to intervene is April 29, 2026; electronic filing encouraged via FERC eFiling system.
  
• Intervention Policy: Agencies that cooperate in environmental documentation cannot intervene; intervenors must serve copies to all parties on the service list.
  
• Contact & Filing Info: Debbie‑Anne A. Reese, Secretary, FERC; electronic and paper filing addresses provided; eLibrary access via docket number.

EPA Secures $346 k Settlement to Cover Superfund Cleanup at Connecticut Site

Overview

The Environmental Protection Agency (EPA) has proposed a settlement with Barth‑Colburn Realty Company to recover administrative costs incurred during the cleanup of the Price‑Driscoll Site in Waterford, Connecticut. Under the agreement, the company will pay $346,567—covering a portion of the $534,717 in response costs already borne by the EPA—while the agency will issue a covenant not to sue or pursue further administrative action related to the site’s remedial work. The settlement is authorized under CERCLA Section 122(h)(1) and has been approved by the Department of Justice’s Environmental and Natural Resources Division.

The proposal invites public comment until May 4, 2026, allowing stakeholders—including local residents, environmental groups, and industry representatives—to weigh in on the adequacy and fairness of the arrangement. EPA will consider all comments and may modify or withdraw the settlement if new facts emerge. The final agreement will be effective once the comment period closes and EPA notifies the settling party.

For geoscientists and natural‑resource professionals, this settlement underscores the ongoing financial and legal mechanisms that support Superfund remediation. It illustrates how administrative cost recovery can help sustain long‑term cleanup efforts while providing a clear legal resolution for parties involved in contaminated site management.

Key Elements

• Parties Involved: EPA (federal agency) and Barth‑Colburn Realty Company (settling party).
  
• Financial Terms: Settling party pays $346,567; EPA has incurred $534,717 in past response costs.
  
• Legal Covenant: EPA will not sue or take administrative action against the settling party for removal work or cost recovery related to the site.
  
• Authority: Settlement authorized under CERCLA §122(h)(1) and DOJ’s power to compromise claims.
  
• Public Comment Period: 30 days (until May 4, 2026) for written comments; EPA may adjust settlement based on feedback.
  
• Effective Date: Upon EPA’s notice that the comment period has closed and no modifications are required.
  
• Relevance to Geosciences: The site involves contamination remediation; the settlement supports continued monitoring, sampling, and potential future geoscientific assessments.
  
• Contact Information: Comments addressed to Megan Roberts‑Edwards, Enforcement Counsel, EPA Region I; technical questions to Stacy Greendlinger, Superfund Division.

Renewing the Data‑Gathering Playbook for Offshore Renewable Energy and Facility Reuse

Overview

The Bureau of Safety and Environmental Enforcement (BSEE) has issued a notice to renew its information‑collection program under the Paperwork Reduction Act (PRA). The program focuses on renewable energy projects and the alternate use of existing facilities on the Outer Continental Shelf (OCS). By collecting data on facility design, construction, operation, and decommissioning, BSEE can enforce safety, environmental, and regulatory requirements for offshore energy activities that are not limited to oil and gas.

The renewal seeks to streamline reporting for operators, pipeline rights‑of‑way holders, and other stakeholders while maintaining rigorous oversight. It also invites public comment on the necessity, burden, and quality of the data collected, encouraging the use of electronic submission and other technologies to reduce respondent workload.

Ultimately, the information gathered will support BSEE’s mission to protect the marine environment, ensure safe operations, and facilitate the transition to renewable energy sources on the OCS.

Key Elements

• Purpose: Renew an existing PRA‑approved information‑collection program (OMB Control No. 1014‑0034) for renewable energy and alternate uses of OCS facilities.
  
• Scope: Covers design, fabrication, installation, operation, and decommissioning of renewable energy facilities and alternate uses of existing OCS infrastructure.
  
• Respondents: Approximately 555 federal OCS oil, gas, and sulfur lessees/operators, pipeline rights‑of‑way holders, and other entities with OCS activities.
  
• Reporting Requirements: Mandatory submissions include Facility Design Reports (FDR), Fabrication and Installation Reports (FIR), and performance‑measure data (Form BSEE‑0187).
  
• Burden Estimate: Ranges from 0.5 to 6,000 hours per submission, with an annual total of roughly 1.9 million hours across all respondents.
  
• Comment Period: Public comments are solicited through June 1, 2026, via electronic submission or mail/fax.
  
• Regulatory Basis: Authority derives from the Outer Continental Shelf Lands Act, Energy Policy Act of 2005, and 30 CFR part 285.
  
• Technology Use: Encourages electronic, automated, or other technology‑based collection methods to minimize paperwork.
  
• Public Record: All comments become public record; personal identifying information may be disclosed unless specifically requested to be withheld.

Columbia, SC to Expand Sewer Capacity: DOJ Proposes New Clean Water Act Modifications

The U.S. Department of Justice has filed a proposed material modification to a 2014 Clean Water Act consent decree that addresses sanitary sewer violations in Columbia, South Carolina. The original decree required the city to complete remedial projects and implement a capacity‑assurance program to eliminate sewer overflows. The new proposal adds four additional projects aimed at increasing sewer capacity and shifts the implementation of the assurance program until those projects are finished.

If adopted, the modification would extend the deadline for the capacity‑assurance program in the affected subbasins until after the new projects are completed, with a target completion date of January 1, 2029. The DOJ is inviting public comments on the proposal for 30 days, with submissions due to the Assistant Attorney General, Environment and Natural Resources Division. Comments can be sent by email or mail, and the full documents are available on the DOJ website.

Key Elements

• Four new sewer‑capacity projects to be completed by 2029, expanding the system’s ability to handle wastewater.
  
• Postponement of the capacity‑assurance program in the subbasins where the new projects will be built, delaying the requirement to eliminate sanitary sewer overflows until after those projects finish.
  
• Public comment period of 30 days, with submissions directed to the DOJ’s Environment and Natural Resources Division (email: pubcomment‑ees.enrd@usdoj.gov).
  
• Access to documents: the proposed modification and the original consent decree can be downloaded from the DOJ website.
  
• Legal context: the modification is part of a civil action (No. 3:13‑cv‑2429‑TLW) that addresses alleged Clean Water Act violations by Columbia’s sanitary sewer system and wastewater treatment plant.

NRC Grants 20‑Year License Renewal for Hatch Nuclear Plant, Finds No Significant Environmental Impact

Overview
The U.S. Nuclear Regulatory Commission (NRC) has issued an Environmental Assessment (EA) and a Finding of No Significant Impact (FONSI) for the subsequent license renewal (SLR) of the Edwin I. Hatch Nuclear Plant (HNP) Units 1 and 2. The renewal would extend the operating licenses for an additional 20 years, allowing the plant to remain in service until 2054 and 2058, respectively. HNP is located about 11 miles north of Baxley, Georgia, on the Altamaha River in Toombs and Appling counties.

The EA evaluated 80 environmental issues—generic to all nuclear plants and site‑specific—to determine whether the renewal would significantly affect the human environment. The NRC staff concluded that none of the identified impacts would be significant, and that the plant’s existing safeguards and the site’s prior industrial use mitigate new environmental concerns. Consequently, the NRC issued a FONSI, meaning an Environmental Impact Statement (EIS) is not required for this action.

The decision also involved an exemption from certain NRC regulations that normally mandate an EIS for license renewals. By granting this exemption, the NRC can complete the environmental review more efficiently—saving up to three months—while still meeting the National Environmental Policy Act (NEPA) requirements. The renewal supports continued nuclear power generation, which may be needed to meet future energy demands, and reflects the NRC’s commitment to regulatory efficiency and public safety.

Key Elements

• License Extension: 20‑year renewal of operating licenses for HNP Units 1 and 2 (until ²⁰⁵⁴⁄₂₀₅₈).
  
• Environmental Assessment: Review of 80 environmental issues; all assessed as having no significant impact.
  
• Finding of No Significant Impact (FONSI): No EIS required; the renewal poses no major environmental risk.
  
• Regulatory Exemption: NRC granted exemption from 10 CFR 51.20(b)(2), 51.25, and 51.95© to use an EA instead of an EIS.
  
• Efficiency and Public Interest: Exemption reduces review time by up to 3 months, aligning with Executive Order 14300’s one‑year decision deadline.
  
• Alternatives Considered: No‑action alternative (shutdown) and potential replacement power options were evaluated; the renewal was deemed environmentally preferable.
  
• Implications for Energy Supply: Continued operation supports regional electricity needs and contributes to the U.S. nuclear energy portfolio.
  
• Public Safety and Environmental Protection: NRC’s assessment confirms that existing safety measures and site conditions mitigate new environmental concerns.

Powering the Saranac River: Lake Flower Dam’s New Hydroelectric License

Overview

The Village of Saranac Lake has submitted a hydroelectric license application to the Federal Energy Regulatory Commission (FERC) for the Lake Flower Dam on the Saranac River. The project, a 134‑foot dam with a 200‑kW Kaplan turbine, aims to continue generating clean electricity while maintaining run‑of‑river flow and preserving local recreation sites. The application is currently in the early filing stage and is not yet ready for environmental analysis.

The notice invites public participation: anyone can file protests or motions to intervene by May 26, 2026. FERC will consider these submissions before moving the project into the environmental review phase. The schedule includes scoping in March, comments in April, and environmental analysis readiness by May, with further comment periods through August.

For geoscientists and natural‑resource professionals, the project’s design details—dam dimensions, spillway, intake gates, and impoundment characteristics—offer a concrete example of how small‑scale hydropower integrates with riverine ecosystems and local land use.

Key Elements

• Project Scope: 134‑ft dam, 33‑ft high, 49‑ft spillway, 200‑kW Kaplan turbine, 1,455‑acre impoundment at 1,528.67 ft NGVD 29.
• Run‑of‑River Operation: Maintains inflow‑equal outflow, with a minimum downstream flow of 55 cfs or less, ensuring ecological continuity.
• Recreation and Community Use: Riverside, Hydropoint, Beaver, and River Walk parks; proposed Boothe River Park whitewater area.
• Environmental Safeguards: Invasive species plan, bat and bald eagle protection, impoundment drawdown, and monitoring plans filed with the license.
• Public Participation Window: Motions to intervene and protests due by May 26, 2026; comments and recommendations due July 2026.
• Regulatory Framework: Governed by the Federal Power Act and FERC Rules of Practice (18 CFR 385 series).
• Access to Documents: Application available on FERC’s eLibrary and at the Saranac Free Library; electronic filing encouraged via eFiling and eComment systems.

Lake Flower Dam: Public Scoping on a New Hydropower License

Overview

The Village of Saranac Lake has submitted a request to the Federal Energy Regulatory Commission (FERC) to relicence the Lake Flower Dam Hydroelectric Project on the Saranac River in New York. The 134‑foot dam, built in 1929, currently operates in a run‑of‑river mode and generates 200 kW of electricity. The proposed license would maintain existing water levels, flow releases, and recreation facilities while adding a whitewater park and enhanced environmental monitoring plans.

FERC is opening a scoping period under the National Environmental Policy Act (NEPA) to gather public input on the environmental issues that should be addressed in the forthcoming environmental document. Comments are due by 5:00 p.m. EDT on April 27, 2026, and can be submitted electronically or by mail. The scoping process will help focus the analysis on key resource areas such as geology, aquatic and terrestrial ecosystems, threatened species, recreation, cultural resources, and development impacts.

Depending on the scope of identified concerns, FERC will decide whether to prepare an Environmental Assessment (EA) or a full Environmental Impact Statement (EIS). The outcome will influence whether a new license is issued and how the project’s operations may be modified to protect environmental and community interests.

Key Elements

• Project Scope: 134‑ft dam, 33‑ft height, 49‑ft spillway, 1,455‑acre impoundment, 200‑kW Kaplan turbine, underground transmission line.
  
• Operational Goals: Maintain current water levels, minimum downstream flow of 55 cfs, existing recreation sites, and develop a downstream whitewater park.
  
• Environmental Focus Areas:
  
  • Geology and soils
    
  • Aquatic resources (fish, water quality)
    
  • Terrestrial habitats and wildlife, including bats and bald eagles
    
  • Threatened and endangered species
    
  • Recreation, land use, and aesthetic values
    
  • Cultural and historical resources
    
  • Development and land‑use impacts
    
• Public Participation:
  
  • Scoping deadline: April 27, 2026 (5:00 p.m. EDT)
    
  • Submission methods: eFiling, eComment, or paper mail to FERC.
    
  • Comments should address potential environmental effects and reasonable alternatives.
    
• Next Steps:
  
  • FERC will use scoping input to draft an EA or EIS.
    
  • Public comment periods will follow the issuance of the EA/EIS.
    
  • Final decision on licensing will consider all timely comments and the environmental analysis.

Alaska LNG Expansion: Public Gets First Look at Environmental Scoping

The Federal Energy Regulatory Commission (FERC) has opened a scoping period to gather public and agency input on the environmental impacts of Trans‑Foreland Pipeline Company’s proposed Kenai LNG Cool Down Expansion Project in Alaska. The project would expand LNG processing capacity at the existing Kenai terminal, adding high‑pressure cryogenic pumps, combustion vaporizers, and new compressor facilities to reduce boil‑off gas venting and increase annual LNG throughput to 400,000 metric tons and 20 billion cubic feet of natural gas. All construction would remain within the current 76‑acre terminal footprint, disturbing roughly 24 acres of land. Under the National Environmental Policy Act (NEPA), FERC will use the scoping comments to focus its environmental analysis on key resource areas—geology, water, wildlife, cultural resources, air quality, and more—and to evaluate reasonable alternatives. Depending on the scope, FERC will prepare either an Environmental Assessment (EA) or a full Environmental Impact Statement (EIS), each followed by public comment periods. The notice also invites cooperating agencies, such as the U.S. Coast Guard and the Pipeline and Hazardous Materials Safety Administration, to participate in the review.

Key Elements

- Project Scope: Expansion of LNG processing capacity at Kenai terminal; addition of cryogenic pumps, combustion vaporizers, and compressor building; no new land outside the existing site. - Environmental Focus Areas: Geology, soils, water resources, wetlands, wildlife, endangered species, cultural resources, socioeconomics, land use, air quality, noise, reliability, and safety. - Scoping Deadline: Comments must be received by 5:00 p.m. Eastern Time on April 27, 2026. - Public Participation: Comments can be submitted electronically via eComment or eFiling, or by paper mail to FERC’s Washington or Rockville addresses. - NEPA Process: FERC will decide between an Environmental Assessment or an Environmental Impact Statement after scoping; each will include public comment periods. - Cooperating Agencies: U.S. Coast Guard and Pipeline and Hazardous Materials Safety Administration are already designated; others may request status through the comment process. - Historic Preservation: Section 106 consultation with the State Historic Preservation Office and other stakeholders will be documented in the environmental review. - Mailing List: A broad environmental mailing list (state/local officials, tribes, NGOs, landowners) will receive updates; individuals can update or opt‑out via email or a provided form.

Wyoming Oil Lease Reinstated: New Terms Boost Rentals and Royalties

The Bureau of Land Management (BLM) has announced its intent to reinstate a previously terminated oil and gas lease (WYW183782) in Carbon County, Wyoming. The petition, filed on time by Kirkwood Oil and Gas, LLC and Kirkwood Resources, LLC, meets all statutory requirements under the Mineral Leasing Act of 1920. No other leases currently affect the land, allowing the BLM to move forward with the reinstatement.

Under the proposed reinstatement, the lease will be effective January 1, 2025 and will run for an additional two years. The lessees will pay a rental of $20 per acre (or fraction thereof) and a royalty of 20 percent on production, both higher than the original terms. Administrative fees and publication costs have already been paid, and the BLM has confirmed that the lease’s original conditions remain unchanged.

This action reflects the BLM’s ongoing effort to manage public lands responsibly while supporting energy development. The updated terms aim to balance revenue generation for the federal government with continued exploration and production opportunities for the lessees.

Key Elements

• Petition and Eligibility: Kirkwood Oil and Gas, LLC & Kirkwood Resources, LLC filed a timely petition meeting all Mineral Leasing Act requirements.
• Lease Status: No conflicting leases exist on the land; the lease can be reinstated without legal obstacles.
• Effective Date and Duration: Reinstatement effective January 1, 2025 with a 2‑year extension.
• Financial Terms:
  • Rental: $20 per acre (or fraction thereof).
  • Royalty: 20 percent of production revenue.
• Administrative Compliance: Lessees have paid the required administrative fee and reimbursed the BLM for notice publication.
• Authority: Action authorized under 30 U.S.C. 188(e)(4) and 43 CFR 3108.23(d).
• Contact: Sandra Blackburn, Branch Chief, Fluid Minerals Adjudication, BLM Wyoming State Office.

Bridger Pipeline Expansion: Montana’s New Oil Corridor Faces Environmental Review

Overview
The Bureau of Land Management (BLM) has announced its intent to prepare an Environmental Impact Statement (EIS) for the Bridger Pipeline Expansion Project, a 646‑mile, 36‑inch buried crude‑oil pipeline that would run from the U.S./Canada border in Montana to a terminal near Guernsey, Wyoming. The pipeline would cross roughly 63.8 miles of federal land—about 58.6 miles on BLM‑managed territory and 5.2 miles on U.S. Forest Service lands—alongside private and state lands. The project is positioned as a key component of the federal “National Energy Emergency” strategy to accelerate domestic energy infrastructure.

The notice initiates a 30‑day public‑scoping period, inviting comments on the scope of analysis, potential alternatives, and relevant studies. BLM will hold four in‑person meetings in Montana and Wyoming and one virtual session, with a deadline of May 1, 2026 for submissions. The EIS will be drafted by August 2026, finalized in spring 2027, and followed by a Record of Decision. The process will involve multiple federal, state, and tribal agencies, including the U.S. Fish and Wildlife Service, U.S. Army Corps of Engineers, and the Montana Department of Environmental Quality.

Key environmental concerns identified include impacts on geology, soils, water resources, wildlife habitat (notably whooping cranes, northern long‑eared bats, pallid sturgeon, and sage‑grouse), cultural and historic sites, and visual resources. The project will require a range of permits—right‑of‑way grants, temporary use permits, a presidential permit for cross‑border construction, and approvals under the Endangered Species Act, Clean Water Act, and state environmental statutes. Public input will shape the alternatives considered and the mitigation measures proposed.

Key Elements

• Project scope: 646.8 mi pipeline, 36‑inch diameter, 8 pump stations, 72 main‑line valve sets, temporary staging areas, and access roads.
  
• Federal land use: 63.8 mi on federal land (58.6 mi BLM, 5.2 mi USFS); 50‑ft permanent ROW on BLM, 100‑ft temporary corridor; 100‑ft permanent ROW on USFS, 50‑ft temporary corridor.
  
• Permitting framework: Right‑of‑way grant (BLM), special use permit (USFS), temporary use permits (BLM & USFS), presidential permit (State Department), Clean Water Act & Rivers and Harbors Act permits (Corps of Engineers), Endangered Species Act review, state environmental permits (Montana & Wyoming DEQ).
  
• Environmental focus: Geology, soils, water crossings (including impaired streams and aquifers), wildlife habitat (especially sensitive species), cultural and historic resources, visual impact, and potential for erosion or sedimentation.
  
• Stakeholder engagement: Public scoping meetings (Glasgow, Miles City, Newcastle, virtual), cooperation with U.S. Fish and Wildlife Service, U.S. Army Corps of Engineers, USFS, Montana DEQ, and tribal governments under E.O. 13175.
  
• Timeline: Scoping period ends May 1, 2026; Draft EIS expected August 2026; Final EIS spring 2027; Record of Decision to follow.
  
• Decision authority: Montana/Dakotas State Director of BLM, with delegated authority to district managers for day‑to‑day decisions, but final NEPA documents signed by the State Director.

BLM Eyes Reinstatement of New Mexico Oil & Gas Lease, Boosting Production Potential

Overview
The Bureau of Land Management (BLM) has received a petition from Enrique A. Cantu to reinstate the terminated competitive oil and gas lease NMNM141519, located in Chaves County, New Mexico. The lessee has paid the required rental from the termination date and has agreed to new lease terms, including a $20‑per‑acre annual rental and a 20 % royalty rate. No other leases have been issued that affect these lands, so the BLM is proposing to reinstate the lease effective January 1, 2022 for the remainder of its primary term.

This action follows the Mineral Leasing Act of 1920 and its amendments, which allow for lease reinstatement when the lessee meets all statutory requirements. By reinstating the lease, the BLM would enable continued exploration and production activities on federal lands, potentially increasing oil and gas output and generating additional revenue for the state and federal governments.

The notice invites public comment and provides contact information for further inquiries. The BLM has also reimbursed the agency for the cost of publishing the notice, ensuring transparency and compliance with federal procedures.

Key Elements

• Petition for Reinstatement – Submitted by lessee Enrique A. Cantu, timely and in accordance with the Mineral Leasing Act.
  
• Financial Compliance – Lessee paid all accrued rentals and the required administration fee.
  
• No Conflicting Leases – No other leases have been issued that affect the land parcel.
  
• New Lease Terms – $20 per acre (or fraction thereof) annual rental; 20 % royalty on production.
  
• Effective Date – Lease reinstated retroactively to January 1, 2022, for the remainder of the primary term.
  
• Authority – Action authorized under 30 U.S.C. 188(e)(4) and 43 CFR 3108.23.
  
• Public Participation – Notice invites comments; contact: Ross Klein, Natural Resource Specialist, BLM New Mexico.

Wyoming Oil Lease Reinstated: Tripower Resources Aims to Revive Exploration in Converse County

Overview

The Bureau of Land Management (BLM) has announced a proposal to reinstate the terminated competitive oil and gas lease WYW164926 in Converse County, Wyoming. Tripower Resources, LLC submitted a timely petition that satisfies all filing requirements under the Mineral Leasing Act of 1920, and no other leases currently affect the land in question. The BLM’s notice indicates that the lease would be reinstated effective January 1, 2025, subject to the original terms and conditions.

The reinstatement would allow Tripower to resume drilling and production activities on federal lands, potentially boosting local employment and revenue. The proposal also includes updated financial terms—an increased rental of $20 per acre and a 20 % royalty rate—along with a two‑year lease extension. These changes reflect the BLM’s effort to balance resource development with fiscal responsibility.

For stakeholders in geoscience, energy, and natural resource management, the decision underscores the ongoing regulatory framework that governs mineral leasing on public lands. It highlights the importance of compliance with statutory deadlines, administrative fees, and environmental considerations that accompany any lease reinstatement.

Key Elements

• Petition Compliance: Tripower Resources met all filing deadlines and requirements under the Mineral Leasing Act of 1920.
  
• No Conflicting Leases: No other leases currently affect the lands, simplifying the reinstatement process.
  
• Reinstatement Terms:
  
  • Effective date: January 1, 2025.
    
  • Original lease conditions remain in force.
    
  • Rental increased to $20 per acre (or fraction thereof).
    
  • Royalty increased to 20 %.
    
  • Lease extended for an additional two years.
    
• Administrative Costs: Lessees paid the required administrative fee and reimbursed the BLM for notice publication.
  
• Regulatory Authority: Action based on 30 U.S.C. 188(e)(4) and 43 CFR 3108.23(d).
  
• Contact Information: Sandra Blackburn, Branch Chief, Fluid Minerals Adjudication, BLM Wyoming State Office.

Cleaning Up the Rules: Removing Outdated Backfilling Standards for Surface Mining

Overview
The Office of Surface Mining Reclamation and Enforcement (OSM) has confirmed that a direct‑final rule will take effect on March 30, 2026. The rule eliminates a long‑suspended regulation—30 CFR 816.101—that once set time and distance standards for rough backfilling and grading of surface mines. The provision was suspended in 1992 and never formally removed from the Code of Federal Regulations, creating confusion for operators and regulators.

During the 30‑day comment period, OSM received two timely comments opposing the removal. After review, the agency determined these were not significant adverse comments and that the rule’s technical housekeeping nature does not warrant a full notice‑and‑comment process. The rule therefore stands as a straightforward update that clarifies the regulatory text without altering current mining or reclamation requirements.

For stakeholders in geoscience, energy, and natural resource fields, this change means that surface mining operators can ignore the obsolete backfilling standards, and regulators can focus on the active provisions of the Surface Mining Control and Reclamation Act (SMCRA). The rule does not introduce new obligations or enforcement actions; it simply cleans up the regulatory record.

Key Elements

• Removal of 30 CFR 816.101 – The suspended time‑and‑distance backfilling standard is deleted, eliminating a non‑enforceable provision that had been inoperative for over 30 years.
  
• No Impact on Current SMCRA Requirements – Existing reclamation and grading rules remain unchanged; operators continue to follow the active SMCRA regulations.
  
• Direct‑Final Rule – OSM used a direct‑final approach because the change is purely technical and non‑controversial, avoiding a full notice‑and‑comment cycle.
  
• Comment Review – Two timely comments were received; OSM concluded they were not significant adverse and did not warrant withdrawal or modification of the rule.
  
• Effective Date – The rule becomes effective on March 30, 2026, after a 60‑day delay to allow for comment review.
  
• Clarification for Practitioners – The update removes confusing language that could mislead those unfamiliar with the regulation’s history, aiding compliance and enforcement clarity.

Reclamation Rules Simplified: New Guidance Removes Outdated Funding Requirements

The Office of Surface Mining Reclamation and Enforcement (OSM) has confirmed that a direct‑final rule, titled “General Reclamation Requirements,” will take effect on March 30, 2026. The rule updates federal regulations by eliminating obsolete language that previously required compliance with reclamation rules when projects were funded with *prior balance replacement funds*—Treasury money that replaced state or tribal share funds allocated before October 1, 2007 but never appropriated by Congress.

This update clarifies that the removal of the old requirement does not alter how states or tribes currently manage or spend any remaining balances of those funds. Existing reclamation programs, including those of tribes that have already expended their allocations, remain unchanged. The rule was deemed noncontroversial, with no significant adverse comments received during the public comment period, so OSM has chosen to proceed without modification.

Key Elements

• Obsolete language removed: No longer required to meet reclamation regulations when using prior balance replacement funds.
  
• Prior balance replacement funds defined: Treasury General Fund money that replaced state/tribal share funds allocated before 10/1/2007 but not appropriated.
  
• No impact on remaining balances: States or tribes with unspent balances (e.g., Wyoming) must still comply with the terms of their original grant agreements.
  
• Tribal programs unaffected: Tribes that have already spent their allocations are not impacted.
  
• Non‑controversial update: OSM received only generic comments; none were deemed significant adverse.
  
• Effective date: March 30, 2026, following a 60‑day delay from the original January 27, 2026 date.
  
• Administrative clarity: The rule maintains existing statutory and regulatory frameworks without adding new reporting tables or cross‑walks.

FERC Opens Inquiry into Vermont’s East Branch Hydroelectric Project: What It Means for Small‑Scale Power and Waterways

Overview
The Federal Energy Regulatory Commission (FERC) has issued a notice inviting public input on whether it has jurisdiction over the East Branch Hydroelectric Project in Orleans County, Vermont. The project, a small turbine system on the East Branch of the Missisquoi River, was built after 1935 and is connected to the interstate transmission grid. Vermont’s Department of Environmental Conservation (DEC) has requested that FERC determine whether the project must be licensed under the Federal Power Act (FPA) because it sits on a stream subject to the Commerce Clause and potentially affects interstate commerce.

Under the FPA, non‑federal hydroelectric projects must be licensed if they are on navigable waters, occupy federal lands, use surplus water from a federal dam, or are on a stream over which Congress has Commerce Clause jurisdiction and were constructed or modified after August 26, 1935. Small projects that feed the grid are considered to influence interstate commerce by displacing power from the national system, a principle upheld in several court decisions. The DEC’s request hinges on these criteria, prompting FERC to review the project’s status and decide whether a license is required.

Stakeholders—including local residents, environmental groups, and energy developers—have 45 days (until May 11, 2026) to submit comments, protests, or motions to intervene. FERC encourages electronic filings through its eFiling system but accepts paper submissions. The outcome will determine whether the East Branch Project must undergo a formal licensing process, potentially affecting its operation, maintenance, and future development.

Key Elements

• Project Details

  • East Branch Hydroelectric Project, Orleans County, Vermont
    
  • Small turbine system on the East Branch of the Missisquoi River
    
  • Constructed after August 26, 1935; connected to the interstate transmission grid
    

• Legal Basis for Review

  • Federal Power Act § 23(b)(1) requires licensing for projects on Commerce Clause streams built or modified post‑1935
    
  • Small hydro projects that feed the grid are deemed to affect interstate commerce by displacing power
    

• FERC’s Role

  • Determining whether the Commission has jurisdiction to license the project
    
  • Assessing compliance with FPA licensing requirements
    

• Public Participation

  • Comment, protest, or motion to intervene deadline: May 11, 2026, 5:00 p.m. ET
    
  • Electronic filing via FERC eFiling preferred; paper filings accepted at specified addresses
    
  • Only those filing a motion to intervene may become formal parties to the proceeding
    

• Potential Outcomes

  • Project may be required to obtain a federal license, subjecting it to regulatory oversight and permitting requirements
    
  • Alternatively, FERC may find it exempt, allowing continued operation without a new license
    

• Implications for Stakeholders

  • Licensing could impose additional costs, environmental reviews, and operational constraints
    
  • Exemption would preserve the project’s current status and potentially support local renewable energy goals
    

• Contact Information

  • FERC Secretary: Debbie‑Anne A. Reese, Washington, DC
    
  • FERC Online Support: 1‑866‑208‑3676 (toll‑free) or (202) 502‑8659 (TTY)
    
  • FERC eFiling portal for comments and motions to intervene.

Aspen’s Ruedi Dam Upgrade: A 1.2‑MW Powerhouse Expansion Under Review

Overview

The City of Aspen has submitted a non‑capacity amendment to the license for the Ruedi Hydroelectric Project (Project No. 3603) to the Federal Energy Regulatory Commission (FERC). The amendment proposes a modest expansion of the existing powerhouse, adding a second turbine and generator with a combined capacity of 1.2 MW, along with associated infrastructure upgrades such as a new penstock, tailrace, bypass line, and electrical system modernization. The project is situated on the Fryingpan River at the Ruedi Dam, a U.S. Bureau of Reclamation reservoir in Pitkin and Eagle counties, Colorado.

FERC’s Environmental Assessment (EA) concludes that, with appropriate protective measures, the proposed changes would not constitute a major federal action that significantly affects the quality of the human environment. The EA evaluates potential environmental impacts, considers alternatives, and affirms that the expansion falls below the threshold for a capacity amendment under current regulations.

Stakeholders and the public are invited to review the EA and submit comments by April 27, 2026. FERC encourages electronic submissions through its eFiling and eComment systems, but paper comments may also be mailed to the Commission’s offices. The review process is part of FERC’s ongoing oversight of hydroelectric projects to balance energy development with environmental stewardship.

Key Elements

• Project Scope: 22 ft × 28 ft powerhouse expansion; 110‑ft new 30‑inch penstock; second turbine/generator (1.2 MW); 48‑in × 48‑in, 60‑ft concrete tailrace; 24‑inch bypass line; electrical system modernization.
  
• Location: Ruedi Dam and reservoir on the Fryingpan River, Pitkin & Eagle counties, Colorado.
  
• Regulatory Context: Non‑capacity amendment under FERC 18 CFR 380; capacity increase below 18 CFR 4.201(b) threshold.
  
• Environmental Assessment: Concludes no major federal action; includes analysis of impacts, alternatives, and protective measures.
  
• Public Participation: Comments due April 27, 2026; electronic filing preferred; paper submissions accepted.
  
• Stakeholders: City of Aspen (licensee), FERC, U.S. Department of Energy, Bureau of Reclamation, local communities, environmental groups.
  
• Next Steps: FERC will consider public comments and determine whether to approve the amendment, potentially with conditions to mitigate environmental impacts.

BLM to Sell 640‑Acre Arizona Tract to Power Company in Direct Sale, Aiming to Spur Local Development

Overview

The Bureau of Land Management (BLM) has announced a non‑competitive, direct sale of a 640‑acre parcel of public land in La Paz County, Arizona. The sale is intended to permanently resolve management challenges associated with an isolated tract that lacks public access, eliminate its split‑estate status, and enable orderly economic development that benefits local communities. The parcel will be sold to 174 Power Global, LLC, a company already holding a long‑term commercial lease on adjacent state land.

The transaction is governed by the Federal Land Policy and Management Act (FLPMA) § 203 and BLM land‑sale regulations. The surface estate will be sold for no less than the appraised fair‑market value of $350,000, while the mineral estate remains reserved to the State of Arizona. A parcel‑specific Environmental Assessment (EA) is being prepared, and the sale will be subject to standard reservations for ditches, canals, indemnification, and existing rights. Public comments are accepted until May 15, 2026, after which the land will be offered for sale.

If approved, the sale will segregate the land from public‑land laws until a patent is issued, preventing new land‑use applications during the transition. The BLM will publish the notice in a local newspaper for three consecutive weeks and will review any adverse comments before finalizing the action.

Key Elements

• Parcel size & location: 640 acres in La Paz County, Arizona (Gila and Salt River Meridian).
  
• Buyer: 174 Power Global, LLC, holder of an exclusive long‑term lease on adjacent state land.
  
• Sale type: Direct, non‑competitive sale under FLPMA § 203(a).
  
• Price: Minimum fair‑market value of $350,000 for the surface estate.
  
• Mineral estate: Reserved to the State of Arizona; no minerals conveyed.
  
• Public access & values: No public access, scenic, or recreational value; isolated tract.
  
• Purpose: Resolve split‑estate status, eliminate management challenges, and facilitate local economic development.
  
• Regulatory framework: FLPMA, BLM land‑sale regulations, 43 CFR 2710.0‑3(a) and 2711.3‑3(a)(4).
  
• Environmental review: Parcel‑specific Environmental Assessment (EA) under NEPA; environmental site assessment under CERCLA.
  
• Reservations & conditions:
  
  1. Reservation for U.S. ditches and canals (43 U.S.C. 945).
     
  2. Indemnification clause protecting the U.S. from claims arising from use or occupancy.
     
  3. Preservation of pre‑existing rights.
     
  4. Additional terms as deemed appropriate by the authorized officer.
     
• Public comment period: Written comments accepted until May 15, 2026 (mail or email).
  
• Publication: Notice will appear in a local newspaper weekly for three weeks.
  
• Segregation: Land will be segregated from public‑land laws until patent issuance or termination of segregation.
  
• Impact on local communities: Expected to enable timely, efficient development and bring economic benefits to La Paz County.

FirstLight CT Housatonic Updates Shoreline Plan: Public Comment Window Opens

Overview
FirstLight CT Housatonic LLC has filed an update to the Shoreline Management Plan for its Housatonic River Pumped Storage Project, a hydroelectric facility located in Fairfield, Litchfield, and New Haven counties, Connecticut. The project, which does not occupy federal lands, is governed by the Federal Power Act and is subject to a six‑year review that prompted this update. The revised plan expands protected designations to include non‑shoreline lands within the project boundary, tightens allowable uses on adjacent properties, simplifies permitting procedures, and revises the fee structure to address imbalances.

The update was developed in consultation with stakeholders and aims to balance future development pressures with long‑term environmental stewardship. By redefining land use restrictions and streamlining authorization processes, the plan seeks to limit potential impacts on the river ecosystem while maintaining operational flexibility for the pumped‑storage facility.

The Federal Energy Regulatory Commission (FERC) has opened a public comment period, inviting federal, state, local, and Tribal agencies, as well as the general public, to submit comments, protests, or motions to intervene. The deadline for submissions is April 27, 2026, 5:00 p.m. Eastern Time, with electronic filing encouraged through FERC’s eFiling system. All filings must include the docket number P‑2576‑215 and comply with FERC’s Rules of Practice and Procedure.

Key Elements

• Project: Housatonic River Pumped Storage Project (Project No. 2576‑215) – hydroelectric facility in Connecticut, not on federal land.
  
• Updated Plan: Expands protected designations to non‑shoreline lands within project boundaries; tightens allowable uses; simplifies permitting; revises fee structure.
  
• Stakeholder Input: Update developed after consultation with local stakeholders and agencies.
  
• Public Participation:
  
  • Comment, protest, or motion to intervene deadline: April 27, 2026, 5:00 p.m. ET.
    
  • Electronic filing via FERC eFiling; paper filings accepted.
    
  • All submissions must reference docket number P‑2576‑215 and follow FERC’s formatting rules.
    
• Intervention Rules: Agencies that cooperate in preparing environmental documents cannot intervene; intervenors must serve copies to all parties on the service list.
  
• Access to Documents: Updated plan available on FERC’s eLibrary; register online for email notifications.
  
• Contact Information: FERC Online Support (866‑208‑3676) and Office of Public Participation (202‑502‑6595).

MCC Advisory Council Opens Doors: A Hybrid Meeting on Critical Minerals, Private‑Sector Innovation, and Sustainable Development

Overview

The Millennium Challenge Corporation (MCC) will convene its Advisory Council on Wednesday, April 15, 2026 from 9:30 a.m. to 12:00 p.m. EDT. The council, a discretionary advisory body established under the Federal Advisory Committee Act, provides independent guidance on infrastructure, technology, sustainability, financing, and risk assessment for MCC’s foreign‑aid programs.

During this Spring 2026 session, council members will receive updates on MCC’s private‑sector strategy and the new “American Returns” framework, which seeks to align U.S. economic interests with development outcomes. A key highlight will be the council’s critical minerals approach, including a country profile of one MCC compact nation that illustrates how critical‑mineral considerations are integrated into aid projects.

The meeting is open to the public; attendees may submit written statements before or after the session. Interested participants must register by Monday, April 13, 2026 to receive hybrid‑attendance instructions. For more details, contact Sheena Cooper at (202) 733‑7148 or via email.

Key Elements

• Hybrid format: in‑person and conference‑call participation.
  
• Critical minerals strategy: discussion of new policy and a country case study.
  
• Private‑sector engagement: updates on MCC’s strategy to involve businesses in development projects.
  
• “American Returns” framework: aligning U.S. economic benefits with foreign‑aid outcomes.
  
• Public participation: open meeting with opportunity to file written statements.
  
• Council’s advisory role: insights on infrastructure, technology, sustainability, financing mechanisms, and risk assessment in partner countries.
  
• Contact information: Sheena Cooper (email/phone) for registration and questions.

U.S. Eyes China’s New Futures Markets: A Hearing on Global Commodity Pricing Power

Overview

The U.S.-China Economic and Security Review Commission (USCSEC) has announced an open public hearing scheduled for April 16, 2026, to examine China’s expanding role in global commodity derivatives. The hearing, titled “Pricing the Future: China’s Ambitions for Commodities Derivative Markets,” will explore how China’s domestic futures exchanges for agricultural goods, energy and oil products, base metals, and critical minerals may reshape price discovery and trade flows worldwide.

This event is part of the Commission’s annual mandate to assess the national‑security implications of U.S.–China economic relations. By focusing on commodity derivatives—a key lever for influencing global supply and pricing—the hearing seeks to understand whether China’s market‑making activities could alter the competitive landscape for U.S. producers and exporters, and whether new regulatory challenges arise for U.S. firms operating in or with China.

Stakeholders—including geoscientists, energy and mineral resource professionals, and trade analysts—are invited to attend in person near the U.S. Capitol or to view a live webcast. The Commission encourages participants to submit written statements by the hearing date and to request accommodations in advance.

Key Elements

• Date & Time: Thursday, April 16, 2026, at 9:30 a.m.
  
• Location: In person at or near the U.S. Capitol (specific room to be announced) or via live webcast on the Commission’s website.
  
• Contact: Jameson Cunningham, 444 North Capitol Street NW, Suite 602, Washington, DC 20001; phone 202‑624‑1496; email for general inquiries or accommodations.
  
• Focus Areas:
  
  • China’s establishment of domestic futures exchanges for agricultural commodities, energy/oil, base metals, and critical minerals.
    
  • Impact on global price discovery, commodity flows, and U.S. market competitiveness.
    
  • Regulatory and market implications for U.S. firms and policymakers.
    
• Participation: Public can file written statements by April 16, 2026; question‑and‑answer session with Commissioners and witnesses.
  
• Commission Leadership: Co‑chaired by Commissioner Livia Shmavonian and Commissioner Taylor Budowich.
  
• Context: Fourth public hearing in the 2026 reporting cycle; part of USCSEC’s broader mandate to report annually on U.S.–China economic security.

Risk‑Based, Technology‑Inclusive Rules for the Next Generation of Nuclear Plants

Overview

The U.S. Nuclear Regulatory Commission (NRC) finalized a new regulatory framework—10 CFR Part 53—effective April 29, 2026, that replaces the older, light‑water‑centric rules in Parts 50 and 52. The rule, mandated by the Nuclear Energy Innovation and Modernization Act (NEIMA) and the 2024 ADVANCE Act, introduces an optional licensing path that applies to all future commercial reactors, including advanced designs that may not use light‑water technology. By foregrounding probabilistic risk assessment (PRA) and other systematic risk evaluations (SREs), the framework allows developers to demonstrate enhanced safety margins while reducing regulatory burden, with an estimated net cost savings of $152–$203 million over 66 years.

The new Part 53 framework covers the entire lifecycle of a commercial nuclear plant—design, siting, construction, operation, decommissioning, licensing, reporting, and enforcement—while maintaining rigorous safety and security standards. It broadens the definition of a “plant” to include the reactor, its support facilities, and any radionuclide sources, and permits a wide range of commercial purposes such as process heat for desalination, oil refining, or hydrogen production. Public participation, environmental assessment, and compliance with executive orders are integral to the rule, ensuring transparency and stakeholder engagement.

Overall, Part 53 streamlines the licensing pathway for emerging nuclear technologies, provides flexibility in design and siting, and preserves the NRC’s defense‑in‑depth safety philosophy. The framework is designed to support innovation in the nuclear sector while safeguarding public health, the environment, and national security.

Key Elements

• Risk‑informed, performance‑based licensing – Part 53 replaces Parts 50 and 52 with a framework that uses PRA and SREs to set safety objectives.
• Optional licensing path for all future reactors – Applies to advanced, non‑light‑water designs and commercial uses beyond electricity generation.
• Broad plant definition – Includes reactor, support facilities, and radionuclide sources; allows process‑heat applications (desalination, refining, hydrogen).
• Design, siting, and operation flexibility – Supports alternative containment, remote operations, reduced staffing, and siting near population centers with rigorous safety analysis.
• Estimated cost savings – $152–$203 million over 66 years by reducing prescriptive rules and streamlining approvals.
• Public participation and environmental assessment – Mandatory engagement and compliance with executive orders and the Congressional Review Act.
• Safety‑related and safety‑significant component requirements – Special treatment for safety‑related SSCs and non‑safety‑significant but safety‑significant SSCs.
• Financial protection and enforcement provisions – Includes insurance, financial‑protection requirements, and enforcement mechanisms for non‑compliance.
• Alignment with NEIMA, 2024 ADVANCE Act, and 2025 NRC reform – Ensures consistency with broader energy and innovation policy goals.

Categorical Exclusions From Environmental Review: A Streamlined NRC Approach

Overview

The U.S. Nuclear Regulatory Commission (NRC) has finalized a rule that expands and clarifies the list of actions that are exempt from the National Environmental Policy Act (NEPA) environmental assessment (EA) or environmental impact statement (EIS). The rule, effective April 29 2026, removes the requirement to prepare an EA for a broad range of licensing, regulatory, and administrative actions that the NRC determines do not significantly affect the human environment. Importantly, the rule does not impose new obligations on licensees or applicants; it simply streamlines the NRC’s internal review process.

Key points of the rule include:
- Reorganization of categorical exclusions to eliminate redundancy and improve consistency.
- Addition of new exclusions for actions such as certificate‑of‑compliance updates for spent‑fuel cask designs, operator‑license changes, and certain decommissioning‑funding decisions.
- Removal of obsolete exclusions that no longer apply under current statutes.
- Definition of “previously disturbed areas” to clarify when ground disturbance is permissible without triggering an EA.
- No change to applicant or licensee requirements—the rule only affects the NRC’s internal NEPA workflow.

The rule is part of the NRC’s broader NEPA reform effort under Executive Order 14300 and the Fiscal Responsibility Act, aiming to reduce regulatory burden while maintaining environmental safeguards.

Key Elements

• Expanded categorical exclusions covering:
  
  • Administrative, procedural, or purely financial actions (e.g., filing‑procedure changes, record‑keeping updates).
    
  • Education and training requirements for NRC staff and licensees.
    
  • Procurement of general equipment and technical assistance.
    
  • Import of nuclear facilities and materials (excluding spent‑fuel).
    
  • Operator‑license approvals and changes.
    
  • Package‑design approvals for licensed material transport.
    
  • Certain decommissioning‑funding approvals.
    
  • Certificate‑of‑compliance updates for spent‑fuel cask designs.
    
• New exclusions for actions that involve ground disturbance limited to previously disturbed areas, ensuring that only activities in already altered sites bypass the EA requirement.
  
• Clarified criteria for “special circumstances” that would still trigger an EA or EIS, such as unresolved conflicts over resource use or significant environmental impacts.
  
• Removal of two outdated exclusions related to water‑pollution‑control and emergency‑planning provisions that are no longer applicable.
  
• No impact on licensee or applicant responsibilities—the rule does not change licensing procedures, safety requirements, or reporting obligations.
  
• Enhanced transparency and public participation through documented comment periods, public meetings, and availability of all related documents on the NRC docket.
  

This rule streamlines the NRC’s environmental review process, reduces administrative overhead, and clarifies the boundaries of when a full NEPA analysis is required, while preserving the agency’s commitment to protecting the human environment.

Calling Ocean Experts: New Advisory Panel Seeks Diverse Voices to Shape U.S. Ocean Policy

Overview
The U.S. Department of Commerce, through NOAA’s Office of Oceanic and Atmospheric Research, has opened nominations for the Ocean Research Advisory Panel (ORAP). Established by Congress in 2021, ORAP serves as an independent advisory body to the Ocean Policy Committee, providing evidence‑based recommendations on national ocean policy, research priorities, and resource management. By drawing on a broad spectrum of expertise—from academia and industry to state, tribal, and local governments—ORAP aims to ensure that policy decisions reflect the full range of stakeholder perspectives and scientific knowledge.

The panel’s recommendations will influence federal funding allocations, regulatory frameworks, and strategic initiatives that affect marine science, technology development, and sustainable use of ocean resources. Participation in ORAP offers professionals an opportunity to shape the direction of U.S. ocean research and policy, fostering collaboration across disciplines and sectors.

Key Elements

• Composition: 10–18 members, including:
  • 3 representatives from the National Academies of Sciences, Engineering, and Medicine.
  • Members representing ocean industries, state/tribal/territorial/local governments, academia, and other relevant viewpoints.
  • Eminent individuals in marine science, technology, policy, or related fields.
• Terms: Up to 3 years per term, renewable once for a second term (maximum of 6 years total), terms may be consecutive or non‑consecutive.
• Nomination Process:
  • Self‑nominations or third‑party nominations accepted.
  • Application must include name, title, affiliation, industry perspective, brief qualifications, and a resume (≤4 pages).
  • Deadline: 45 days after notice publication.
• Submission: Email applications to the ORAP Designated Federal Officer (DFO) with subject line “Application for ORAP Membership 2026.”
• Contact: Viviane Silva, ORAP DFO – 240‑624‑0656, email: email protected.

Ocean Research Advisory Panel (ORAP) Meets to Shape the Future of Emerging Ocean Technologies

Overview

The U.S. Department of Commerce’s National Oceanic and Atmospheric Administration (NOAA) has announced a public meeting of the Ocean Research Advisory Panel (ORAP) on May 21, 2026. ORAP, an independent body established by Congress, advises the Ocean Policy Committee (OPC) on national ocean policy. The meeting will review the draft of ORAP’s second report, “Recommendations for Supporting Public‑Private Partnerships to Advance Emerging Ocean Technologies,” and decide whether it is ready for submission to the OPC.

The agenda also includes an update from the OPC co‑chairs on current priorities and a discussion of the panel’s earlier work on a National Ocean Data Strategy. The meeting will be held at the AGU Conference Center in Washington, D.C., with a webinar option and a 15‑minute public comment period. Written comments are due by May 8, 2026, and the panel will consider only non‑repetitive statements.

This event underscores NOAA’s commitment to fostering collaboration between industry, academia, and government to accelerate ocean‑science innovations—such as AI/ML, eDNA, and other emerging technologies—while ensuring data accessibility and interoperability for researchers and stakeholders.

Key Elements

• Meeting Details

  • Date & time: May 21, 2026, 9:00 a.m.–1:00 p.m. ET
    
  • Location: AGU Conference Center, Washington, D.C. (webinar link to be posted)
    
  • Public comment period: 15 minutes; verbal presentations limited to 3 minutes each
    

• Agenda Focus

  • Review of draft second report on public‑private partnerships for emerging ocean technologies
    
  • Discussion of the National Ocean Data Strategy and its role in supporting interdisciplinary research
    
  • OPC co‑chairs’ update on policy priorities
    

• Participation & Accessibility

  • Written comments due by May 8, 2026 (late submissions may not be reviewed)
    
  • Meetings are physically accessible; special accommodations requested by May 1, 2026
    

• Policy Context

  • ORAP was created by the 2021 National Defense Authorization Act (Section 1055©)
    
  • The panel’s first report, Toward a National Ocean Data Strategy, was delivered in September 2024
    
  • The upcoming report aims to guide federal support for industry‑led ocean‑technology initiatives over the next 5–10 years
    

• Stakeholder Impact

  • Provides a platform for scientists, industry leaders, and policymakers to shape the direction of ocean research and technology deployment
    
  • Emphasizes the importance of data interoperability, trust, and accessibility for advancing global ocean science and resource management.

New Mexico & Oklahoma Lands Get Official Survey Filing—What It Means for Land Management

Overview

The U.S. Bureau of Land Management (BLM) has announced the official filing of several cadastral plats—detailed maps that define land boundaries—in New Mexico and Oklahoma. These plats, which include both standard survey plats and supplemental plats, are essential tools for managing public lands, resolving ownership disputes, and facilitating resource development. The filing process formalizes the survey data, making it part of the federal land record system.

The notice specifies that the official filing will occur on April 29, 2026. Stakeholders—including landowners, developers, tribal governments, and geoscientists—have until that date to submit written protests if they believe the plat contains errors or conflicts with existing claims. After the filing, the plats will be available for public inspection at the BLM New Mexico State Office in Santa Fe, and copies can be requested for a fee.

For those involved in mineral exploration, energy projects, or environmental studies, these plats provide critical baseline information about land parcels, topography, and jurisdictional boundaries. Accurate cadastral data supports everything from permitting to environmental impact assessments, ensuring that resource development proceeds on a clear legal and geographic foundation.

Key Elements

• Scheduled Filing Date: April 29, 2026 (official filing of the plats).
  
• Protest Deadline: Written protests must be received by the BLM New Mexico State Office no later than the filing date.
  
• Plats Covered:
  
  • New Mexico: Township 19 South, Range 27 East (Group 1221).
    
  • Oklahoma:
    
  • Township 19 North, Range 15 West (Group 242).
    
  • Township 10 North, Range 26 East (Group 247).
    
• Preparation Sources:
  
  • New Mexico plat prepared at BLM’s request.
    
  • Oklahoma plats prepared at the request of the Bureau of Indian Affairs (Southern Plains and Eastern Oklahoma Regions).
    
• Public Access: Plat records can be viewed free of charge at the BLM Public Room, 301 Dinosaur Trail, Santa Fe, NM 87508. Copies are available for a fee.
  
• Contact Information: Jacob B. Barowsky, BLM Chief Cadastral Surveyor for New Mexico and Oklahoma – 505‑761‑8903 or barowsky@blm.gov.
  
• Legal Basis: Filing authority under 43 U.S.C. Chap. 3; protests may be filed with the BLM State Director for New Mexico.
  
• Implications for Stakeholders:
  
  • Provides definitive boundary data for land management and resource development.
    
  • Supports accurate mapping for environmental assessments and land-use planning.
    
  • Enables tribal and private parties to verify or contest land claims before official recording.

Cape Cod Canal Pipeline Relocation: FERC Delays Environmental Review, Sets New Timeline

Overview
The Federal Energy Regulatory Commission (FERC) has announced a revised schedule for the environmental assessment (EA) of Algonquin Gas Transmission’s Cape Cod Canal Pipeline Relocation Project. The original plan called for the EA to be issued on April 17, 2026, but delays in Algonquin’s submission of a critical horizontal directional drill assessment report and additional siting information have pushed the issuance to May 29, 2026.

The EA will be released with a 30‑day public comment period, after which FERC will proceed to a 90‑day federal authorization decision deadline of August 27, 2026. This deadline applies to all federal and state agencies that must grant permits or approvals under the Natural Gas Act. If further schedule changes arise, FERC will issue additional notices to keep stakeholders informed.

Stakeholders—including local communities, environmental groups, and industry participants—can track the project’s progress through FERC’s eSubscription service and access all filings via the eLibrary. The notice also provides contact information for public participation and assistance with filing comments or interventions.

Key Elements

• Revised EA issuance date: May 29, 2026
  
• Public comment period: 30 days following EA release
  
• Federal authorization decision deadline: August 27, 2026 (90 days after EA)
  
• Reason for delay: Missing horizontal directional drill assessment report and additional siting data from Algonquin
  
• Agency coordination: Deadline applies to all federal and state agencies responsible for permits under the Natural Gas Act
  
• Tracking tools: eSubscription service for automatic notifications; eLibrary for document access
  
• Contact points: Office of Public Participation (202) 502‑6595; eLibrary helpline (866) 208‑3676 or TTY (202) 502‑8659
  
• Unique identification number for NEPA tracking: EAXX‑019‑20‑000‑1763050824
  
• Regulatory reference: 18 CFR 157.22(a) governing agency decision deadlines
  
• Next steps: FERC will issue the EA, open the comment period, and then move toward the final authorization decision by the August deadline.

US Bank Eyes $100M+ Loan to Revitalize Idaho’s Critical Mineral Mines

Overview
The Export‑Import Bank of the United States (EXIM) has announced that it has received an application for a final commitment of a long‑term loan or financial guarantee exceeding $100 million. The proposed financing is part of EXIM’s “Make More in America” initiative and is aimed at redeveloping gold‑antimony‑silver‑tungsten deposits in Idaho’s Stibnite‑Yellow Pine district. By supporting domestic extraction and processing of these critical minerals, the project seeks to strengthen U.S. supply‑chain resilience for defense, energy, and advanced manufacturing sectors.

The loan would fund the extraction of gold dore bars and antimony concentrate, which will be exported to overseas processing facilities for refinement into gold bullion and antimony metal. Antimony is a key component in semiconductors and lead‑acid batteries, and the project intends to eventually bring domestic antimony processing capabilities online. The financing is expected to create high‑quality U.S. jobs and reduce reliance on foreign sources for strategic minerals.

Comments from the public are invited until April 24, 2026. The EXIM Board of Directors will review all submissions before making a final decision on the transaction.

Key Elements

• Loan Size: Long‑term commitment of $100 million+ (exact amount not disclosed).
  
• Purpose: Redevelopment of critical mineral deposits (gold, antimony, silver, tungsten) in Idaho.
  
• Strategic Minerals: Focus on antimony—essential for semiconductors and batteries—and gold for industrial and defense uses.
  
• Supply‑Chain Impact: Aims to reduce U.S. dependence on foreign antimony and strengthen domestic supply chains for advanced manufacturing.
  
• Export Details: Export of gold dore bars and antimony concentrate to overseas processing facilities; eventual domestic processing of antimony concentrate.
  
• Job Creation: Expected to generate high‑quality U.S. jobs in mining, processing, and related industries.
  
• Comment Period: Public comments due by April 24, 2026; submissions via the EXIM comment portal (EIB‑2026‑004).
  
• Regulatory Basis: Authorized under Section 3©(10) of the Export‑Import Bank Act of 1945.
  
• Stakeholders: Involvement of Perpetua Resources Idaho Inc. and Perpetua Resources Corp.
  
• Decision Timeline: Final decision to be announced in the EXIM Board of Directors’ meeting minutes.

Plaquemines LNG Seeks to Boost Non‑FTA LNG Exports to 1.9 Tcf/yr

Overview

Venture Global Plaquemines LNG, LLC (Plaquemines LNG) has filed a request with the U.S. Department of Energy (DOE) to raise its authorized export volume of liquefied natural gas (LNG) to countries that do not have a free‑trade agreement (FTA) with the United States. The company’s existing authorization, granted under DOE/FE Order No. 4446 and its amendments, allows exports of 1,240 billion cubic feet per year (Bcf/yr) of natural gas, which was later increased to 1,405 Bcf/yr. The new application seeks an additional 467.67 Bcf/yr, bringing the total to 1,873 Bcf/yr (approximately 1.9 trillion cubic feet per year).

Plaquemines LNG argues that the requested increase reflects a refined analysis of the terminal’s peak liquefaction capacity under optimal conditions. The company has already obtained Federal Energy Regulatory Commission (FERC) approval to raise its liquefaction capacity from 27.2 metric tons per annum (MTPA) to 35.0 MTPA, which aligns with the volume increase sought from DOE. Importantly, the company states that this uptick does not require new construction or major modifications to existing facilities.

The DOE will evaluate the application under the Natural Gas Act (NGA) and relevant regulations, taking into account environmental impacts as required by the National Environmental Policy Act (NEPA). Interested parties have 60 days from the notice’s publication to file protests, comments, or motions to intervene, with a deadline of 4:30 p.m. Eastern Time on May 26, 2026. The final decision will be issued after the DOE completes its NEPA review and considers all stakeholder input.

Key Elements

• Current Authorization: 1,240 Bcf/yr (initial), extended to 1,405 Bcf/yr (2026 Order 4446‑B).
  
• Requested Increase: 467.67 Bcf/yr, raising total to 1,873 Bcf/yr (≈1.9 Tcf/yr).
  
• Capacity Alignment: FERC approval to raise liquefaction capacity to 35 MTPA, matching the volume increase.
  
• No New Construction: Expansion relies on existing terminal infrastructure operating at peak capacity.
  
• Regulatory Framework: Evaluation under NGA §3(a), DOE regulations, and NEPA requirements.
  
• Public Comment Window: 60‑day period ending May 26, 2026; electronic filing encouraged.
  
• Future Actions: DOE will issue a final order after completing its review and incorporating stakeholder input.

Laser‑Powered Enrichment: Kentucky’s New Uranium Facility Under Review

Overview

The U.S. Nuclear Regulatory Commission (NRC) has released a draft Environmental Impact Statement (EIS) for Global Laser Enrichment, LLC’s (GLE) proposal to build and operate the Paducah Laser Enrichment Facility (PLEF) on a 322‑acre greenfield site in McCracken County, Kentucky. The facility would use laser‑based isotope separation to enrich uranium up to 8 % U‑235 and re‑enrich depleted uranium tails to natural levels. The NRC’s preliminary recommendation, pending safety review, is to issue a license that would allow GLE to construct, operate for up to 40 years, and later decommission the plant.

The draft EIS evaluates both the proposed action and the no‑action alternative (denying the license). It incorporates GLE’s environmental report, scoping comments, and input from federal, state, local, and tribal agencies. Public comments are invited until May 11, 2026, with electronic submissions encouraged through the Federal Rulemaking website.

Key Elements

• Facility Scope: 322‑acre site, laser‑based uranium enrichment up to 8 % U‑235, re‑enrichment of depleted tails.
  
• Operational Timeline: Up to 40 years of construction, operation, and eventual decommissioning.
  
• Environmental Focus: Assessment of impacts on air quality, water resources, wildlife, and local communities; comparison with no‑action alternative.
  
• Regulatory Process: Draft EIS published under Docket ID NRC‑2025‑1007; NRC staff’s preliminary recommendation to issue license unless safety concerns arise.
  
• Public Participation: Comment period closed May 11, 2026; submissions accepted electronically or by mail; NRC will post all comments publicly.
  
• Stakeholder Engagement: Coordination with federal, state, local, and tribal authorities; inclusion of scoping comments in the draft analysis.
  
• Safety and Security: NRC’s review includes safety, security, and safeguards considerations for handling special nuclear material.

EPA Publishes Comments on Federal Environmental Impact Statements

Overview

The Environmental Protection Agency (EPA) has issued a Notice of Availability announcing that its comment letters on several federal Environmental Impact Statements (EISs) are now publicly accessible. This action fulfills the EPA’s obligation under the Clean Air Act and the Council on Environmental Quality (CEQ) guidance to disclose its evaluations of EISs prepared by other federal agencies.

The notice lists two specific EISs: the draft report for the Global Laser Enrichment, LLC license application for the Paducah Laser Enrichment Facility, and the final site‑wide EIS for the continued operation of Los Alamos National Laboratory. By making these comments available, the EPA enhances transparency, allowing stakeholders, researchers, and the public to review the agency’s assessments of potential environmental impacts and regulatory considerations.

The release also provides contact information for the EPA officials responsible for the comments and specifies the timeframe during which the comments were filed, underscoring the agency’s commitment to timely and open communication in the environmental decision‑making process.

Key Elements

• Purpose: Public disclosure of EPA comment letters on federal EISs, as required by the Clean Air Act and CEQ guidance.
  
• EISs Covered:
  
  • Global Laser Enrichment, LLC – Paducah Laser Enrichment Facility (draft report, due 05/11/2026).
    
  • Los Alamos National Laboratory – Continued Operation (final site‑wide EIS).
    
• Availability: Comments filed March 16–23, 2026, and now accessible to the public.
  
• Contact Information:
  
  • Amy Minor, 817‑200‑1454 (Paducah EIS).
    
  • Lawrence Kwei, 505‑665‑8774 (Los Alamos EIS).
    
• Agency Oversight: Nancy Abrams, Deputy Director, Federal Activities Division, EPA.
  
• Regulatory Context: Aligns with 42 U.S.C. 4332 § 309(a) and CEQ guidance on federal environmental review.
  
• Implications for Stakeholders: Enables informed participation in environmental assessments, potential influence on project approvals, and supports scientific and policy discussions in geoscience and energy sectors.

DHS Streamlines Environmental Review by Adopting Five Existing Categorical Exclusions

Overview

The Department of Homeland Security (DHS) has officially adopted five categorical exclusions (CEs) under the National Environmental Policy Act (NEPA) to simplify the environmental review process for a range of routine federal actions. By leveraging CEs established by other federal agencies—namely the Department of the Interior’s Bureau of Reclamation, the U.S. Fish and Wildlife Service, the Department of Agriculture’s Farm Service Agency, and NASA—DHS can bypass the need for full Environmental Assessments (EAs) or Environmental Impact Statements (EISs) when those actions are unlikely to produce significant environmental effects.

The adopted exclusions cover activities such as rehabilitation of high‑hazard dams, habitat restoration projects, small‑scale ground disturbance, and routine maintenance or operation of unmanned aircraft systems. DHS will still evaluate each proposed action for “extraordinary circumstances” (e.g., impacts on endangered species, historic resources, or sensitive wetlands) and will prepare an EA or EIS if such circumstances arise. The agency’s NEPA procedures, including the list of extraordinary circumstances, are documented in the DHS NEPA Instruction Manual and will be recorded in the Environmental Planning and Historic Preservation Decision Support System.

This notice, effective March 27 2026, informs the public and other stakeholders of the adopted exclusions, the types of actions they apply to, and the consultation process that confirmed their appropriateness. The adopted CEs are now available to all DHS components and will be referenced in future environmental planning documents.

Key Elements

• Effective Date: March 27 2026
  
• Five Adopted Categorical Exclusions:
  
  • Bureau of Reclamation (DOI) – Rehabilitation of high‑hazard dams and related infrastructure.
    
  • U.S. Fish and Wildlife Service (USFWS) – Habitat restoration or enhancement projects, including limited fire‑prevention work.
    
  • Farm Service Agency (USDA) – Broad range of ground‑disturbance activities (bridges, dams, excavation, wetland restoration, etc.).
    
  • NASA (14 CFR 1216.304(d)(2)(ix)) – Routine maintenance, repair, and operation of unmanned aircraft systems (Category 1 or 2).
    
  • NASA (14 CFR 1216.304(d)(5)(i)) – Flight activities of unmanned aircraft systems.
    
• Extraordinary Circumstances: DHS will assess impacts on public health, endangered species, historic or cultural resources, Indian sacred sites, sensitive wetlands, and other protected areas before applying a CE.
  
• Consultation Process: DHS consulted with the establishing agencies in 2025–2026 to confirm that the intended uses align with the original scope of each CE.
  
• Documentation & Transparency: All applications of the adopted CEs will be recorded in the DHS Environmental Planning and Historic Preservation Decision Support System and are publicly accessible.
  
• Implications for Geoscience & Natural Resources: The adoption reduces administrative burden for routine infrastructure and environmental projects while maintaining safeguards for significant ecological and cultural resources.

NSF Tightens Reporting on Industry‑University Research Centers

Overview

The National Science Foundation (NSF) has announced the renewal of its information‑collection requirements for the Industry‑University Cooperative Research Centers (IUCRC) program. In line with the Paperwork Reduction Act, NSF is inviting public comment on the proposed reporting burden before submitting the request for Office of Management and Budget (OMB) clearance. Comments are due by May 26, 2026.

The IUCRC program connects universities with a broad spectrum of industry partners—large firms, startups, and non‑profits—to conduct pre‑competitive research that can later be commercialized. Centers are funded through membership fees, with at least 90 % of those fees directed to research projects. NSF supports the administrative and governance framework, while industry and government members contribute expertise, facilities, and intellectual property.

Under the renewed collection, each IUCRC site must submit annual data on structure, funding, membership, personnel, and research outcomes, as well as detailed project summaries and financial allocations. The program also encourages centers to share impact stories for public outreach. NSF estimates the total reporting burden at roughly 3,680 hours per year across 230 active sites, and seeks feedback on how to streamline the process and improve data quality.

Key Elements

• Renewal & OMB Clearance – NSF will seek OMB approval for a 3‑year collection period after public comment.
  
• Broad Industry Participation – Members include large corporations, startups, non‑profits, and government agencies.
  
• Funding Allocation – Minimum 90 % of membership fees go directly to research projects.
  
• Annual Reporting Requirements
  
  • Center‑wide survey on structure, funding, personnel, and outcomes.
    
  • Certification of membership and fee collection.
    
  • Site‑level research project summaries (goals, milestones, budgets, personnel).
    
  • Independent assessment reports uploaded by Principal Investigators.
    
• Data Use – Internal program evaluation, congressional reporting, and public dissemination via the IUCRC directory and optional impact stories.
  
• Estimated Burden – ~16 hours per award per year, totaling ~3,680 hours for all sites.
  
• Public Comment Focus – Necessity, accuracy of burden estimates, data quality, automation opportunities, and burden reduction strategies.

FEMA Review Council Gets a Fresh Term: What It Means for Disaster Science and Resource Management

Overview

In March 2026, the President extended the Federal Emergency Management Agency (FEMA) Review Council, a federal advisory body tasked with evaluating FEMA’s performance and recommending improvements. The new order keeps the council active until either the required report is submitted to the President or May 29, 2026—whichever comes first—ensuring continuous oversight during a period of heightened climate‑related emergencies.

The council’s mandate is especially relevant to geoscientists, oceanographers, and natural‑resource professionals because it scrutinizes how FEMA coordinates disaster response to events such as hurricanes, wildfires, floods, and coastal erosion. By assessing FEMA’s preparedness, resource allocation, and interagency collaboration, the council can influence policies that shape how scientific data and risk assessments are integrated into emergency planning and recovery efforts.

The extension also clarifies administrative responsibilities: the Secretary of Homeland Security will carry out the council’s functions under the Federal Advisory Committee Act, and the order supersedes earlier directives. While the order does not create new legal rights or benefits, it underscores the importance of transparent, evidence‑based oversight in safeguarding communities and critical infrastructure from natural hazards.

Key Elements

• Continuance Period: Council remains active until the required report is submitted or May 29, 2026, whichever occurs first.
  
• Administrative Authority: The Secretary of Homeland Security, following General Services Administration guidelines, will perform the council’s duties under the Federal Advisory Committee Act.
  
• Supersession: Sections 1 and 2 of the previous Executive Order (14378) are replaced by this new order.
  
• No New Rights: The order does not confer any enforceable rights or benefits on individuals or entities.
  
• Funding: Publication costs are borne by the Department of Homeland Security; implementation depends on available appropriations.
  
• Relevance to Natural‑Resource Fields: The council’s assessments will shape FEMA’s response strategies to climate‑driven disasters, influencing resource allocation, infrastructure resilience, and the integration of scientific expertise into emergency management.

NOAA Expands Access to Space‑Based Environmental Data, Seeking Public Input

Overview
The U.S. Department of Commerce, through the National Oceanic and Atmospheric Administration (NOAA), has submitted a revised information‑collection request to the Office of Management and Budget (OMB) for the NOAA Space‑Based Data Collection System (DCS). The request updates the existing collection by removing the Polar‑Orbiting Operational Environmental Satellite (POES) Argos system—no longer managed by NOAA—and refocusing on the Geostationary Operational Environmental Satellite (GOES) DCS. The GOES DCS supports a wide range of environmental applications, including meteorology, oceanography, hydrology, ecology, and remote sensing of Earth resources, and its data are already shared with the World Meteorological Organization through the Global Telecommunication System.

The revision allows NOAA to make its unused GOES DCS capacity available to qualified users, such as government agencies, research institutions, and non‑profit organizations, who cannot meet their data needs through commercial services. Applicants must submit a System Use Agreement (SUA) detailing the intended use, data formats, delivery schedules, and compliance with international and federal regulations. NOAA will only approve agreements that meet strict criteria, ensuring that the system’s resources are used efficiently and for public benefit.

NOAA is inviting the public and other federal agencies to comment on this revised information collection. A 30‑day comment period follows an earlier 60‑day period, giving stakeholders the opportunity to influence how NOAA manages and distributes space‑based environmental data. The final decision will be reviewed by OMB under the Paperwork Reduction Act of 1995, which aims to minimize reporting burdens while maintaining essential data collection for scientific and policy purposes.

Key Elements

• Revision & Extension – Updates the existing NOAA DCS information collection, extending its scope and duration.
  
• Removal of POES Argos – The POES Argos system is no longer administered by NOAA and is excluded from the new collection.
  
• Focus on GOES DCS – Emphasizes the geostationary satellite system that supports meteorology, oceanography, hydrology, ecology, and remote sensing.
  
• Capacity Sharing – NOAA offers excess GOES DCS capacity to qualified users who cannot obtain required data from commercial services.
  
• System Use Agreement (SUA) – Applicants must submit an SUA covering validity period, authorized uses, data formats, delivery schedules, equipment standards, and user‑borne costs.
  
• Eligibility Criteria – Includes not‑for‑profit institutions, federal, state, local, tribal governments, and for‑profit organizations that meet regulatory and technical requirements.
  
• Compliance Requirements – Must adhere to International Telecommunication Union (ITU) and Federal Communications Commission (FCC) regulations, as well as NOAA’s operational standards.
  
• Reporting & Data Delivery – Specifies reporting frequencies, data formats, and delivery systems to ensure timely and accurate information exchange.
  
• OMB Review & Public Comment – The request is subject to OMB clearance under the Paperwork Reduction Act, with a 30‑day public comment period to assess burden and impact.
  
• Potential Impact – Enhances data availability for environmental monitoring, climate research, and resource management, benefiting scientists, policymakers, and the public.

Ohio Power and Light’s Water Quality Certification Deadline Approaches

Overview

On March 16, 2026, Current Hydro LLC notified the Federal Energy Regulatory Commission (FERC) that the West Virginia Department of Environmental Protection (DEP) had received a Clean Water Act Section 401(a)(1) water‑quality certification request from Ohio Power and Light, LLC (OPL) for a project slated to begin on November 13, 2025. The request, governed by 40 CFR 121.5, seeks approval that the project will not adversely affect water quality in the state’s waters.

FERC’s notice informs the West Virginia DEP that it must act on the certification within one year—by November 13, 2026. If the DEP fails to approve or deny the request by that date, the certification is deemed waived under Section 401(a)(1) of the Clean Water Act, allowing the project to proceed without the required water‑quality clearance.

This procedural step underscores the regulatory balance between energy development and environmental protection. It also highlights the role of state agencies in ensuring that new power projects meet federal water‑quality standards before construction and operation begin.

Key Elements

• Request Origin: Ohio Power and Light, LLC submitted a water‑quality certification request to West Virginia DEP on November 13, 2025.
  
• Regulatory Framework: The request falls under Clean Water Act Section 401(a)(1) and 40 CFR 121.5, requiring a state’s certification that the project will not impair water quality.
  
• Deadline: West Virginia DEP must act on the certification by November 13, 2026—exactly one year after the request.
  
• Waiver Provision: If the DEP does not approve or deny the request by the deadline, the certification is automatically waived, permitting the project to proceed without that clearance.
  
• FERC Oversight: The notice serves to inform FERC and the public of the timeline and potential waiver, ensuring transparency in the regulatory process.
  
• Implications for Energy Development: The outcome will determine whether OPL can move forward with its project while maintaining compliance with federal water‑quality standards.

Maine’s Upper Barker Hydropower Project Opens for Public Review and Environmental Analysis

The Federal Energy Regulatory Commission (FERC) has announced that the application for a subsequent minor license for the Upper Barker Hydroelectric Project on the Little Androscoggin River in Auburn, Maine, is now ready for environmental analysis. The project, operated by KEI (Maine) Power Management (III) LLC, involves a 41‑acre reservoir, a 43‑foot concrete dam, a 950‑kW turbine, and a 12.47‑kV transmission line. The application, filed in 2021, seeks a 47‑year license term and includes detailed engineering drawings and fish‑passage plans.

A key feature of the application is a Settlement Agreement that addresses fish and aquatic resource concerns. The agreement, signed with the U.S. Department of Justice, U.S. Fish and Wildlife Service, National Marine Fisheries Service, and Maine wildlife agencies, sets out coordinated upstream and downstream passage for species such as American eel, river herring, shad, lamprey, and Atlantic salmon. It also establishes minimum flow releases, aligns license terms between the Upper and Lower Barker projects, and creates an Androscoggin Basin Stewardship Fund to support habitat restoration.

Public participation is central to the process. Comments, recommendations, terms and conditions, and prescriptions are due by July 6, 2026, with a filing deadline of May 22, 2026 for water‑quality certification documents. Intervenors must serve copies to all parties on the official service list and, if relevant, to the responsible resource agency. The FERC eLibrary provides full access to the application, and electronic filing is strongly encouraged.

Key Elements

• Project Scope: 41‑acre impoundment, 43‑ft concrete dam, 950‑kW turbine, 12.47‑kV transmission line on the Little Androscoggin River.
• License Terms: 47‑year subsequent minor license, aligning with a 50‑year term for the Lower Barker Project.
• Fish Passage Measures: Installation of full‑depth trash rack overlays and mussel spat ropes to protect eels and other migratory species.
• Settlement Agreement: Coordinated upstream/downstream passage, minimum flow releases, and a stewardship fund for basin habitat restoration.
• Water‑Quality Certification: Required submission by May 22, 2026; waiver possible if justified.
• Public Comment Period: Open until July 6, 2026; electronic filing preferred; paper filings accepted with strict service requirements.
• Environmental Analysis: FERC will evaluate impacts on aquatic resources, invasive species, and overall ecosystem health before issuing a license.

Ireland’s Nitrate Boost: EU Law Says “Check the Waters First”

Overview

Ireland’s Fifth Nitrates Action Programme, adopted in 2022, allows dairy and other livestock farms to apply up to 250 kg of nitrogen per hectare per year—well above the 170 kg limit set by the EU Nitrates Directive. The programme was approved by the European Commission under a derogation, but the Irish High Court has asked the Court of Justice to clarify whether this higher allowance is compatible with three key EU directives: the Nitrates Directive, the Habitats Directive (Natura 2000), and the Water Framework Directive (WFD).

The Advocate General’s opinion explains that the derogation cannot be granted without a comprehensive environmental assessment. Under the WFD, any increase in nitrogen must be shown not to jeopardise the “good status” of surface waters, while the Habitats Directive requires an assessment of the potential impact on Natura 2000 sites. Moreover, the Strategic Environmental Assessment (SEA) Directive demands that the programme’s environmental effects, monitoring plans, and alternatives be fully documented and publicly scrutinised.

If the assessment finds that the higher nitrogen application would breach water‑quality or habitat objectives, the derogation could be deemed invalid. The opinion also notes that, even if the programme is found partially unlawful, the Court may decide to maintain its effects to avoid creating a legal vacuum that could undermine Ireland’s obligations under the Nitrates Directive and the WFD.

Key Elements

• Higher nitrogen limit: 250 kg N ha⁻¹ per year, authorised by a Commission derogation (Implementing Decision 2022/696).
  
• Water‑quality assessment: Must demonstrate that the increased application does not prevent the attainment of “good status” for surface waters under the WFD.
  
• Habitat assessment: Requires an assessment of implications for Natura 2000 sites (Habitat Directive 92/43/EEC) to ensure no significant adverse effects.
  
• Strategic Environmental Assessment (SEA): The programme must include an environmental report covering impacts, monitoring measures, and alternatives, in line with Directive 2001/42/EC.
  
• Monitoring requirements: Detailed plans for monitoring nitrogen levels, water quality, and potential unforeseen adverse effects must be provided.
  
• Material assets: Only environmental effects on material assets are considered; economic impacts of agriculture are not treated as material assets in the SEA.
  
• Alternatives assessment: Alternatives to the derogation must be identified, described, and evaluated to ensure the chosen option is the least environmentally damaging.
  
• Potential invalidation: If the assessment shows incompatibility with the WFD, Habitats Directive, or SEA, the derogation may be invalidated.
  
• Maintenance of effects: The Court may decide to keep the programme’s effects in place if repealing it would create a legal vacuum and jeopardise Ireland’s EU obligations.

“No More Flood‑Control Plans: Nebraska’s Wood River Watershed Project Pulled the Plug”

Overview

The U.S. Department of Agriculture’s Natural Resources Conservation Service (NRCS) has officially rescinded its 2023 Notice of Intent (NOI) to prepare an Environmental Impact Statement (EIS) for the Lower Wood River Watershed Floodwater Reduction Project in five Nebraska counties. The decision follows a determination that the proposed diversion channel would serve a drainage area of roughly 323,000 acres—well above the 250,000‑acre statutory cap set by the Watershed Protection and Flood Prevention Act of 1954. Because the project no longer meets legal requirements and no other viable alternatives were identified, NRCS concluded that an EIS is unnecessary.

The rescission means that federal, state, and local agencies will not pursue the planned flood‑control infrastructure, and the associated environmental review process is halted. Communities and farmers who had anticipated improved flood protection will need to explore other mitigation options, while the NRCS will redirect resources to projects that comply with statutory limits.

Key Elements

• Project Termination: The Lower Wood River Watershed Floodwater Reduction Project has been officially canceled.
  
• Statutory Limit Exceeded: The proposed diversion channel would manage a watershed of ~323,400 acres, surpassing the 250,000‑acre cap for flood‑prevention projects.
  
• No Feasible Alternatives: NRCS’s planning process did not uncover any other options that fit within legal acreage constraints.
  
• Rescission Effective: The NOI to prepare an EIS was rescinded on March 25 2026.
  
• Agencies Involved: USDA‑NRCS, Central Platte Natural Resources District, and local Nebraska conservation districts.
  
• Public Notification: The Federal Register notice (88 FR 8400) and this rescission were published to inform federal, state, and local stakeholders.
  
• Contact Information: Melissa Baier, USDA‑NRCS‑NE Assistant State Conservationist for Water Resources and Easements, is the primary point of contact for questions.
  
• Implications for Communities: Residents and farmers in Buffalo, Custer, Dawson, Hall, and Merrick counties will no longer receive the planned flood‑control infrastructure and must seek alternative flood‑management strategies.

US Updates Hydric Soil Database to Include Subaqueous Soils

Overview

The U.S. Department of Agriculture’s Natural Resources Conservation Service (NRCS) has revised the criteria used to identify hydric soils—soils that develop under saturated, anaerobic conditions—within the National Soil Information System (NASIS). The update, announced in a 2026 notice, adds subaqueous (underwater) landforms to the official hydric soils list. Although the change will affect only a small fraction of total acreage, it brings the database into alignment with current scientific understanding and mapping of soils that have long been recognized as hydric by definition.

Hydric soils play a critical role in environmental planning, wetland delineation, and conservation efforts. By incorporating subaqueous soils, the NRCS enhances the accuracy of wetland identification, supports better land‑use and conservation planning, and improves the reliability of data used by researchers, policymakers, and land managers. The update also reflects refinements in soil taxonomy, notably the inclusion of the Wassents subgroup, which represents newly mapped underwater soils.

The notice invites public comment until April 24, 2026, and provides contact details for the NRCS Hydric Soil Committee. The revised criteria were approved by the National Technical Committee for Hydric Soils (NTCHS) during its 2024 meetings and are now publicly available through the NRCS and NTCHS web portals.

Key Elements

• Inclusion of subaqueous soils: Submerged landforms are now recognized as hydric, expanding the official list.
  
• Updated taxonomic criteria: The Wassents subgroup is added to reflect newly mapped underwater soils.
  
• Minimal acreage impact: The change represents a negligible increase in total hydric soil area.
  
• Enhanced wetland mapping: More accurate identification of wetlands and associated ecosystem services.
  
• Implications for land‑use planning: Better data for conservation, agriculture, and urban development decisions.
  
• Public comment period: Feedback accepted through April 24, 2026 (Docket ID NRCS‑2026‑0001).
  
• Contact information: Cory Owens, NRCS National Resource Soil Scientist, phone (503) 414‑3261, email provided in the notice.

Kinder Morgan’s New Texas‑Louisiana Pipeline Extension: A 112‑Million‑Dollar Expansion Opens Doors for Natural Gas Flow

Overview

Kinder Morgan Louisiana Pipeline LLC (KMLP) has filed a request with the Federal Energy Regulatory Commission (FERC) to construct a 3.05‑mile, 48‑inch mainline extension that will link its existing system in Texas to new facilities in Louisiana. The extension will connect to the Trident Intrastate Pipeline, the Texas Header, and KMLP’s Leg 1 and Leg 2 pipelines, and will include new regulator and metering stations at Sabine Pass and the Woodside Terminal. The project is projected to transport up to 1,300,000 Dth/d of natural gas and is estimated to cost $112 million.

The filing triggers a formal environmental review under FERC’s Part 157 procedures. Within 90 days of the notice, FERC staff will either complete the review and place the environmental documents in the public record or issue a schedule for the review. The outcome will determine the timing for federal authorizations and the completion of state‑level permits, including a Clean Water Act water‑quality certificate from the Texas Railroad Commission.

Public participation is a key component of the proceeding. Stakeholders can file comments, protests, or motions to intervene by April 9, 2026. Intervenors gain the right to challenge FERC orders and seek rehearing, while all participants will be kept informed through eLibrary notifications and the Commission’s environmental mailing list.

Key Elements

• Project Scope: 3.05‑mile, 48‑inch mainline extension; 540 ft of 42‑inch pipe to Trident; 70 ft to Texas Header; 250 ft to existing legs; new regulator/metering at Sabine Pass and Woodside Terminal.
  
• Capacity & Cost: Up to 1,300,000 Dth/d transport; estimated cost $112 million.
  
• Regulatory Path: FERC Notice of Application (Section 7© NGA, Part 157); environmental review schedule or final EA/EIS within 90 days.
  
• Water‑Quality Certification: Required Clean Water Act Section 401 certificate from the Texas Railroad Commission; KMLP must submit the certification decision or waiver.
  
• Public Participation:
  
  • Comments, protests, and motions to intervene accepted until 5:00 p.m. ET, April 9, 2026.
    
  • No filing fee; electronic filing via eComment or eFiling, or paper submissions.
    
  • Intervenors receive service on all documents and can request rehearing.
    
• Timeline:
  
  • Notice published March 24, 2026.
    
  • Intervention deadline April 9, 2026.
    
  • Environmental review milestones to follow per FERC schedule.
    
• Stakeholder Impact: Potential effects on land use, water resources, and local communities along the proposed route; opportunities for local input and environmental monitoring.

NSF’s Transparency Push: Live Videoconference on Oversight and Future Directions

Overview

The National Science Foundation (NSF) is holding a public videoconference under the Sunshine Act, a federal law that requires government meetings to be open to the public. The National Science Board’s Committee on Oversight will use this session to review recent audit findings, discuss how merit‑review processes are being implemented, and explore ways to measure NSF’s impact on science and technology.

The meeting, scheduled for Friday, March 27, 2026, will run from 11:00 a.m. to 12:00 p.m. Eastern Time and will be streamed live on YouTube and posted on the NSF’s Events page. Anyone can watch the proceedings in real time, ensuring transparency and allowing stakeholders—including scientists, industry partners, and the general public—to follow the board’s deliberations.

Key topics include the FY 2026 Office of Inspector General audit plan, progress on merit‑review implementation goals, and a discussion of a proposed “State of NSF” framework to track the agency’s effectiveness and impact. The session will conclude with closing remarks from the committee chair.

Key Elements

• Date & Time: Friday, March 27, 2026, 11:00 a.m.–12:00 p.m. ET
  
• Format: Videoconference streamed via YouTube and NSF Events page
  
• Location: National Science Foundation, 401 Dulaney Street, Alexandria, VA (virtual)
  
• Public Access: Meeting is open; livestream link available on NSF website
  
• Agenda Highlights:
  
  • Approval of prior minutes and opening remarks
    
  • Presentation of FY 2026 OIG Audit Plan
    
  • Discussion of Merit Review report implementation goals
    
  • Exploration of a “State of NSF” approach to track efficacy and impact
    
  • Closing remarks by Committee Chair
    
• Contact: Chris Blair, 703‑292‑7000 (NSF) – for additional information
  
• Status: Active and open to public observation.

DOE Extends Community Voice in Nuclear Cleanup: EM SSAB Renewed for Two Years

Overview

The Department of Energy (DOE) has announced the two‑year renewal of the Environmental Management Site‑Specific Advisory Board (EM SSAB), a community‑based advisory committee that advises DOE’s Environmental Management program on cleanup and restoration of former nuclear weapons sites. The renewal, effective April 7, 2026, follows the Federal Advisory Committee Act and GSA’s Committee Management Secretariat review, underscoring the board’s essential role in ensuring local perspectives shape federal cleanup decisions.

The EM SSAB is composed of roughly 160 members—most of whom live or work near eight major DOE cleanup sites across the United States. Members are selected without requiring technical expertise, allowing a broad range of community viewpoints to inform decisions on waste management, site closure, future land use, and long‑term stewardship. The board’s operations cost about $2.9 million annually, covering federal staff, travel, and administrative expenses, while members receive no compensation.

Since its inception in 1994, the EM SSAB has issued nearly 1,830 recommendations, with 84 % accepted or partially accepted by DOE. In the past two years alone, 42 recommendations were made, 90 % of which were implemented, accelerating cleanup timelines and fostering stakeholder support for site closures such as Rocky Flats (Colorado) and Fernald (Ohio). The board also fulfills public‑participation requirements under CERCLA, RCRA, and multiple federal‑state agreements, ensuring that affected communities have a direct voice in the remediation process.

Key Elements

• Renewal Period: Two‑year extension (April 7, 2026 – April 2028).
  
• Advisory Scope: Community‑based input on cleanup activities, waste disposition, excess facilities, future land use, stewardship, communications, and budget priorities.
  
• Membership: ~160 members, primarily residents or workers near eight DOE cleanup sites; no technical expertise required.
  
• Cost Structure:
  
  • Federal personnel: 4 FTEs (~$563,000/yr).
    
  • Other federal internal costs (travel, meetings, contractors): ~$2.27 M/yr.
    
  • Member reimbursements (travel): ~$89,000/yr.
    
  • Total annual budget: ~$2.9 M.
    
• Impact Record: 1,830 recommendations since 1994; 84 % accepted/partially accepted; 90 % implementation rate in recent years.
  
• Public Participation: Meets CERCLA, RCRA, and multiple federal‑state consent agreements’ requirements for community engagement.
  
• Strategic Value: Provides a cost‑effective, established mechanism for obtaining uncompensated community input, avoiding the higher costs and administrative burdens of alternative outreach methods.

Federal Land Withdrawal Near New Mexico Border Gets Precise Legal Update

Overview

The Bureau of Land Management (BLM) has issued a correction to Public Land Order (PLO) No. 7963, which originally withdrew 109,651 acres of federal land in Doña Ana, Luna, and Hidalgo counties for U.S. Army border‑security purposes. The update, published March 23 2026, refines the legal descriptions of the withdrawn parcels and adjusts the total acreage to 110,967 acres, incorporating the 60‑foot “Roosevelt Reservation” strip along the U.S.–Mexico border that was omitted in the initial order.

The correction does not alter the physical boundaries shown on the map issued with the original PLO; it simply ensures that the written descriptions match the GIS‑derived area and the official plat. The land remains under Army administrative jurisdiction, and the purpose of the withdrawal—enhancing national defense operations—continues unchanged.

For geoscientists, energy, and natural‑resource professionals, the update underscores the importance of precise land‑description data for planning, environmental assessment, and compliance with federal land‑management statutes.

Key Elements

• Accurate Legal Descriptions – The notice corrects typographical errors and expands the descriptions to fully capture each withdrawn parcel without relying on survey data.
• Updated Acreage – The total withdrawn area is revised from 109,651 to 110,967 acres, reflecting the inclusion of the Roosevelt Reservation.
• Roosevelt Reservation Inclusion – A 60‑foot strip along the international border, reserved by a 1907 presidential proclamation, is now explicitly listed in the legal description.
• No Change to Map or Land Status – The physical boundaries on the original map remain the same; the land is still transferred to the Department of the Army for border‑security use.
• Compliance with FLPMA – The correction is issued under Section 204(e) of the Federal Land Policy and Management Act, ensuring the withdrawal remains lawful and properly documented.
• Implications for Resource Management – Accurate descriptions aid in environmental impact assessments, land‑use planning, and coordination with state and local agencies in the affected counties.

All Aboard Act: A $50 B Push Toward Zero‑Emission Rail and Climate‑Resilient Infrastructure

Overview
The All Aboard Act of 2025 establishes a comprehensive federal framework to modernize the United States’ rail network, with a particular focus on electrification, climate resilience, and workforce development. At its core, the Act creates a state‑level rail formula grant program and a new Green Railroads Fund, allocating billions of dollars to support the planning, construction, and operation of high‑performance, zero‑emission rail corridors. It also expands passenger rail service, addresses air‑quality concerns at railyards, and institutes robust training centers for both passenger and freight rail workers.

The legislation authorizes $3.5 B for state rail grants, $50 B for the Green Railroads Fund, $80 B for the Federal‑State Intercity Partnership program, and additional appropriations for Amtrak, climate‑resilience projects, and crossing‑elimination initiatives. These funds are earmarked to electrify existing freight and passenger lines, upgrade locomotives, and build new electrified corridors, with a clear timeline: 50 % of trains zero‑emission by 2030, all new trains by 2035, and all locomotives by 2047. The Act also mandates climate‑resilient design, robust community engagement—especially in environmental‑justice communities—and a coordinated study on co‑locating electric transmission with rail corridors.

For geoscientists, energy specialists, and natural‑resource professionals, the Act signals a decisive shift toward low‑carbon transportation infrastructure. It integrates climate science into infrastructure planning, promotes renewable energy integration through transmission co‑location, and emphasizes land‑use efficiency and environmental stewardship across the rail network.

Key Elements

• State Rail Formula Grant Program – $3.5 B over five years to fund state rail plans, infrastructure upgrades, and electrification projects, with a minimum $5 M per state annually.
• Green Railroads Fund – $50 B for competitive grants to electrify freight and passenger lines, upgrade locomotives, and build climate‑resilient corridors.
• Federal‑State Intercity Partnership Program – $80 B to prioritize high‑performance passenger rail, including new routes and electrification, with a focus on environmental‑justice communities.
• Zero‑Emission Locomotive Targets – 50 % of trains zero‑emission by 2030; all new trains by 2035; all locomotives by 2047.
• Climate‑Resilient Infrastructure – Design standards for flood, sea‑level rise, and extreme weather; $5 B earmarked for Amtrak climate‑resilience projects.
• Transmission Co‑Location Study – $50 M to assess feasibility of aligning electric transmission lines with rail corridors, aiming to reduce land use and streamline permitting.
• Rail Workforce Training Centers – $500 M to establish passenger and freight rail training hubs, focusing on emerging technologies such as zero‑emission locomotives and electrification systems.
• Air Pollution Grant Program – $500 M for EPA grants to mitigate railyard emissions under the Clean Air Act.
• Labor Protections – Enforcement of wage, apprenticeship, and safety standards for contractors and rail workers, with special attention to displaced and underrepresented communities.
• Environmental Justice Focus – Prioritization of projects that reduce air pollution in communities of color, low‑income, and Indigenous populations, and robust public engagement requirements.

H.R. 7147: A $26 Billion Boost for Homeland Security, Climate Resilience, and Disaster Response

Overview

H.R. 7147 is a consolidated appropriations act that allocates roughly $26 billion to the Department of Homeland Security (DHS) for fiscal year 2026, with additional earmarks for related agencies such as FEMA, the Coast Guard, and the Transportation Security Administration. The bill is designed to strengthen national security, improve border and infrastructure protection, and enhance the United States’ ability to anticipate, respond to, and recover from natural disasters and climate‑related hazards. It also establishes new reporting and oversight mechanisms to ensure that funds are used efficiently and transparently.

The act places significant emphasis on environmental and geoscience‑related programs. FEMA receives $3.8 billion for disaster relief, including a $26 billion Disaster Relief Fund, and $226 million for the National Flood Insurance Fund, which supports flood mapping and mitigation. The Coast Guard is granted $11 billion for operations, construction, and research, including $98 million for unmanned aircraft and $30 million for coastal and marine research. The Cybersecurity and Infrastructure Security Agency (CISA) is funded $2.2 billion for risk management and simulation, while the Transportation Security Administration receives $10 billion for aviation security and infrastructure upgrades. These allocations underscore a federal commitment to integrating geoscience, climate science, and environmental stewardship into homeland security planning.

The bill also introduces stringent oversight provisions. DHS must submit monthly estimates of migrant arrivals and detentions, quarterly reports on the use of the National Flood Insurance Fund, and detailed plans for any new pilot programs. Funds may not be used for certain activities—such as the Arms Trade Treaty or the procurement of long‑range unmanned aircraft with kinetic capabilities—without congressional approval. Additionally, the act rescinds specific unspent balances and imposes limits on reprogramming, ensuring that appropriations remain aligned with congressional intent.

Key Elements

• Total Appropriations: ~$26 billion for DHS FY 2026, with $1.25 billion earmarked for other purposes (e.g., body‑worn cameras, training).
• FEMA: $3.8 billion for operations and support; $26 billion Disaster Relief Fund; $226 million for the National Flood Insurance Fund (flood mapping, mitigation, and insurance).
• Coast Guard: $11 billion for operations, construction, and research; $98 million for unmanned aircraft; $30 million for coastal and marine research.
• CISA: $2.2 billion for risk management, simulation, and infrastructure protection.
• Transportation Security Administration: $10 billion for aviation security and infrastructure upgrades.
• Reporting Requirements: Monthly estimates of migrant arrivals and detentions; quarterly reports on the National Flood Insurance Fund; annual reports on the use of funds for new pilots and demonstrations.
• Restrictions on Use: No funding for the Arms Trade Treaty until ratified; no procurement of long‑range unmanned aircraft with kinetic capabilities; no use of funds for certain personnel or activities (e.g., informant compensation limits, no use for certain types of training).
• Rescissions: Specific unspent balances from prior appropriations are rescinded to prevent duplication and ensure fiscal responsibility.
• Oversight and Accountability: Committees on Appropriations receive detailed reports on grant awards, procurement, and program performance; penalties for delayed reporting (e.g., $100,000 per day for FEMA’s Disaster Relief Fund reporting delays).
• Geoscience‑Focused Funding: Emphasis on flood mapping, coastal resilience, and climate‑adaptation research, reflecting the intersection of homeland security and environmental science.

Protecting the Hunt: A New Law Keeps Lead Ammunition on Federal Lands

Overview

The Protecting Access for Hunters and Anglers Act (H.R. 556) was introduced to prevent the U.S. Interior and Agriculture Departments from issuing blanket bans on lead ammunition or tackle on federal lands and waters used for hunting and fishing. The bill acknowledges growing concerns about lead contamination in wildlife and human food chains, yet seeks to preserve traditional hunting practices by limiting federal authority to prohibit lead use except under specific, evidence‑based circumstances.

The Act allows the Secretary of the Interior (via the Fish and Wildlife Service or Bureau of Land Management) and the Secretary of Agriculture (via the Forest Service) to prohibit lead use only on particular units of federal land or water where field data show a decline in wildlife populations directly attributable to lead. Such prohibitions must also align with the laws, policies, or approvals of the state in which the unit resides. When a prohibition or regulation is enacted, the applicable Secretary must publish a Federal Register notice explaining how the action meets the statutory requirements.

As of March 2026, the bill has been received in the Senate, read twice, and referred to the Committee on Environment and Public Works. It remains under consideration, with the potential to shape future wildlife management and land‑use decisions across the United States.

Key Elements

• No blanket bans: The Interior and Agriculture Secretaries cannot prohibit lead ammunition or tackle on federal lands or waters that are open for hunting or fishing.
  
• Targeted restrictions: Prohibitions are allowed only on specific units where (1) lead use is proven to cause wildlife decline and (2) the restriction aligns with state law, state fish‑and‑wildlife policy, or state approval.
  
• Evidence‑based requirement: The Secretary must rely on field data from the specific unit to justify a lead‑related ban.
  
• State consistency: Any federal prohibition must be consistent with the laws and policies of the state containing the federal unit.
  
• Transparency: A Federal Register notice must accompany any prohibition or regulation, detailing how the action satisfies the statutory criteria.
  
• Legislative status: The bill is currently in the Senate, referred to the Committee on Environment and Public Works, and awaiting further action.

U.S. Launches Trade Probe into Large Graphite Electrodes from China and India

Overview

The U.S. Department of Commerce has officially begun countervailing duty (CVD) investigations into large diameter graphite electrodes imported from the People’s Republic of China and India. The investigations aim to determine whether these imports are benefiting from countervailable subsidies—financial support that lowers production costs—and whether such subsidies are causing or threatening material injury to the U.S. domestic graphite electrode industry. The petitions, filed by the LDGE Fair Trade Coalition on behalf of U.S. producers, allege that imports have surged, depressed prices, and reduced U.S. production and sales.

The investigations cover all large graphite electrodes (diameter >425 mm) and associated pin‑joining systems used in industrial furnaces. They exclude small‑diameter electrodes already subject to an existing antidumping duty order. The U.S. will assess subsidy rates for up to 28 Chinese and 3 Indian companies, using customs data and company‑specific information. The process will involve consultations with the governments of China and India, public comment periods, and a preliminary determination by the U.S. International Trade Commission (ITC) within 45 days of petition filing.

If the ITC finds that imports are materially injuring the U.S. industry, the Department may impose countervailing duties—additional taxes on imported goods—to level the playing field. The outcome could affect steel and aluminum producers, supply chains, and trade relations with both countries, while also setting a precedent for how the U.S. handles subsidies in high‑tech industrial materials.

Key Elements

• Petitioners & Industry Support – The LDGE Fair Trade Coalition, representing U.S. producers Resonac Graphite America Inc. and Tokai Carbon GE LLC, filed the petitions, demonstrating 100 % support from the domestic graphite electrode industry.
  
• Scope of Investigation – All large diameter graphite electrodes (≥425 mm) and related pin‑joining systems, classified under HTSUS 8545.11.0020, with exclusions for small‑diameter electrodes under the existing antidumping order.
  
• Period of Investigation (POI) – January 1 – December 31 2025, covering imports during that year.
  
• Consultations – Formal consultations held with the governments of China (March 11, 2026) and India (March 12, 2026) to discuss subsidy allegations.
  
• Respondent Selection – Up to 28 Chinese and 3 Indian companies identified; the Department will calculate company‑specific subsidy rates, potentially selecting mandatory respondents based on customs import data.
  
• Timeline – Preliminary CVD determinations due within 65 days of initiation; ITC preliminary injury determination within 45 days of petition filing.
  
• Public Comment Period – Scope comments due by April 6 , 2026; rebuttal comments due by April 16 , 2026.
  
• Data Protection – Customs import data released under an Administrative Protective Order (APO); interested parties may request disclosure under APO procedures.
  
• Potential Outcomes – If injury is found, countervailing duties could be imposed, affecting import prices, supply chains, and U.S. industrial competitiveness.

NASA Opens a Digital Front Door: A New Hub to Connect Scientists, Students, and the Public

Overview

NASA has announced the launch of the NASA Front Door (NFD), an online, web‑based platform built on Salesforce that will serve as a centralized digital hub for individuals, organizations, and NASA employees. The tool is designed to streamline engagement by collecting basic contact information, interests, and, when appropriate, demographic data, and then routing users to the most relevant NASA programs, opportunities, and expertise. This initiative is part of NASA’s commitment under the Space Act Section 203(a)(3) and the NASA Strategic Plan to broaden public understanding and participation in the nation’s aeronautical and space endeavors.

The NFD represents a new information collection under the Paperwork Reduction Act (PRA). NASA estimates that the system will support about ten distinct activities each year, with roughly 60,000 respondents per activity, totaling 600,000 responses annually. Respondents are expected to spend about 15 minutes completing the intake, resulting in an estimated 150,000 burden hours per year. The agency is inviting public comments on the necessity, burden estimates, data quality, and ways to minimize respondent effort; comments are due by May 19, 2026.

For the geoscience, energy, and natural resource communities, the NFD offers a streamlined pathway to access NASA’s extensive datasets, research opportunities, and technical expertise. By reducing paperwork and providing personalized guidance, NASA aims to enhance collaboration between federal scientists, industry stakeholders, and the broader public.

Key Elements

• Purpose: Centralized digital hub to facilitate engagement and route users to NASA services, opportunities, and expertise.
  
• Legal Basis: New information collection under the Paperwork Reduction Act; OMB control number 2700‑xxxx.
  
• Data Collected: General contact info, interest/intake data, and optional demographic information for registration profiles.
  
• Platform: Built on Salesforce, enabling automated routing and data management.
  
• Estimated Impact:
  
  • 10 activities per year
    
  • 60,000 respondents per activity
    
  • 600,000 total responses annually
    
  • 15 minutes per response → 150,000 burden hours per year
    
• Target Audience: Individuals (students, educators, awardee PI’s, invited guests), organizations, and NASA workforce.
  
• Comment Period: 60 days from publication (comments due May 19, 2026).
  
• Contact for Comments: Stayce Hoult, NASA PRA Clearance Officer, Washington, DC (phone 256‑714‑8575, email hq‑ocio‑pra‑program@mail.nasa.gov).
  
• Strategic Alignment: Supports NASA’s communication function and the NASA Strategic Plan’s goal of broad public dissemination and participation.

St. Lucie Nuclear Plant Gets 20‑Year License Renewal: Final Environmental Review Released

Overview

The U.S. Nuclear Regulatory Commission (NRC) has published the final Environmental Impact Statement (EIS) for the subsequent license renewal (SLR) of Florida Power & Light’s St. Lucie Nuclear Plant, Units 1 and 2. The plant, located about seven miles southeast of Fort Pierce, Florida, is slated to operate for an additional 20 years beyond the expiration of its renewed facility operating licenses (DPR‑67 and NPF‑16). The EIS is a supplement to the generic NUREG‑1437 report and evaluates the environmental consequences of extending the plant’s operating life.

The NRC staff concluded that the adverse environmental impacts of the SLR are not significant enough to preclude the option of renewal. This determination follows a comprehensive review of the draft EIS, public comments received during the scoping and comment periods, and consultations with federal, state, and local agencies as well as Indian tribes. The final report incorporates responses to stakeholder concerns and reaffirms that the plant’s continued operation would not pose unreasonable risks to the environment or public health.

The document is publicly available through the NRC’s regulations.gov portal, the Agencywide Documents Access and Management System (ADAMS), and local libraries in St. Lucie County. Stakeholders and the general public can review the full EIS, submit additional comments, or contact NRC staff for clarification. The release of this final EIS marks a key step in the regulatory process that will inform energy‑planning decisions and the plant’s future operations.

Key Elements

• License Renewal Scope: 20‑year extension for Units 1 and 2 of the St. Lucie Nuclear Plant (DPR‑67 and NPF‑16).
  
• Final EIS Status: Published as a supplement to NUREG‑1437, addressing draft‑EIS comments and confirming no significant environmental impact.
  
• Public Participation: Draft EIS comment period closed February 23, 2026; final EIS incorporates stakeholder feedback.
  
• Availability: Accessible via regulations.gov (Docket ID NRC‑2021‑0197), ADAMS, and local St. Lucie County libraries.
  
• Contact Information: NRC staff (Lance Rakovan, Office of Nuclear Material Safety and Safeguards) for technical questions; public inquiries handled through regulations.gov.
  
• Implications for Energy Planning: The NRC’s recommendation supports continued operation, providing a stable energy source for the region while maintaining regulatory oversight of safety and environmental protection.

Nuclear Power Meets AI: Fermi America’s 4‑GW Project Matador Campus Under Environmental Review

Overview

The U.S. Nuclear Regulatory Commission (NRC) has announced its intent to prepare an Environmental Impact Statement (EIS) for Fermi America LLC’s Combined License (COL) application to build and operate four AP1000 advanced passive pressurized‑water reactors (PMN Units 1‑4) at the Project Matador campus in Carson County, Texas. The campus, adjacent to the Department of Energy’s Pantex Plant, is envisioned as a hyperscale data‑center hub that will rely on the reactors to supply 4 GW of reliable, carbon‑free baseload power for artificial‑intelligence and other high‑density computing operations.

To comply with the National Environmental Policy Act (NEPA), the NRC is conducting a 30‑day public scoping period, open until April 20, 2026. The agency invites comments from the public, state and local governments, tribes, and other federal agencies. The project is part of a pilot program in which the applicant prepares a draft EIS under NRC supervision, after which the NRC independently reviews the document and assumes responsibility for its content.

The forthcoming EIS will evaluate a range of alternatives—including a no‑action option—and analyze potential impacts on air quality, geology, surface and groundwater, terrestrial and aquatic ecosystems, land use, socio‑economic factors, radiological and non‑radiological health, waste management, the uranium fuel cycle, decommissioning, cultural resources, and transportation. The NRC will coordinate with agencies required by the Endangered Species Act, the National Historic Preservation Act, and other federal statutes to ensure comprehensive environmental protection while advancing grid decarbonization, AI infrastructure, and national energy security.

Key Elements

• Project Scope – Four AP1000 reactors (PMN Units 1‑4) at Project Matador campus, Texas; 4 GW of carbon‑free baseload power for hyperscale data centers.
  
• Regulatory Framework – Combined License (COL) application under 10 CFR 52; NEPA pilot program for applicant‑prepared draft EIS under NRC supervision.
  
• Public Participation – 30‑day scoping period (comments due April 20, 2026); engagement via regulations.gov and a dedicated NRC project website.
  
• Environmental Impact Areas – Air quality, geology, surface & groundwater, terrestrial & aquatic ecosystems, land use, socio‑economic effects, radiological & non‑radiological health, waste, uranium fuel cycle, decommissioning, cultural resources, transportation.
  
• Alternatives Analysis – Includes a no‑action alternative and other technically and economically feasible options that meet the project’s purpose and need.
  
• Agency Coordination – NRC will consult with federal, state, tribal, and local agencies under the Endangered Species Act, National Historic Preservation Act, and other applicable statutes.
  
• Benefits and Objectives – Supports grid decarbonization, AI and data‑center infrastructure, regional economic development, and workforce expansion while ensuring rigorous environmental review.
  
• Timeline – Scoping period ends April 20, 2026; draft EIS to follow, with public comment and NRC review before a final decision on the COL application.

Nuclear Power Gets a 20‑Year Green Light: Final Environmental Review for H.B. Robinson Plant

Overview

The U.S. Nuclear Regulatory Commission (NRC) has released the final Environmental Impact Statement (EIS) for the proposed subsequent license renewal of the H.B. Robinson Steam Electric Plant, Unit 2 (RNP) in Darlington County, South Carolina. The EIS, a supplement to the generic NUREG‑1437 report, evaluates the environmental consequences of extending the plant’s operating license for an additional 20 years beyond the current renewal period.

The NRC staff concluded that the adverse environmental impacts of this renewal are not significant enough to preclude the option of a subsequent license renewal. This determination follows a thorough review of draft EIS comments, consultations with federal, state, and local agencies, and an independent environmental assessment. The final report incorporates public feedback received during the draft‑EIS comment period that ended on February 23, 2026.

The decision supports continued nuclear generation at RNP, providing a stable, low‑carbon energy source for the region while ensuring that environmental, safety, and community concerns are addressed through the NRC’s regulatory framework.

Key Elements

• Location & Facility: H.B. Robinson Steam Electric Plant, Unit 2, ~5 mi NW of Hartsville, SC.
• License Renewal Scope: Proposed subsequent renewal of Renewed Facility Operating License No. DRP‑23 for an additional 20 years.
• EIS Basis: Supplement 13 to the generic NUREG‑1437 report, addressing environmental impacts of the renewal.
• Public Participation: Draft EIS released January 9, 2026; comment period closed February 23, 2026; final EIS incorporates public comments.
• NRC Findings: Adverse impacts deemed not significant enough to deny the renewal option; decision based on environmental data, stakeholder consultations, and independent review.
• Regulatory Context: Follows NRC’s Section 51.118 of Title 10 CFR; aligns with EPA’s notice of availability.
• Access to Information: EIS available in PDF, ADAMS, and public libraries; contact NRC docket ID NRC‑2025‑0076 for inquiries.
• Implications for Energy Planning: Maintains a reliable, low‑emission power source while upholding safety and environmental standards.

Sable Offshore Seeks Special Permit to Waive Pipeline Corrosion Repairs Amid Energy Production Restart

Overview

Sable Offshore Corp. has requested a special permit from the Pipeline and Hazardous Materials Safety Administration (PHMSA) to waive the 180‑day remediation requirement for corrosion on two segments of the Santa Ynez Pipeline System. The pipeline transports crude oil from the Outer Continental Shelf to onshore facilities in California, and the requested waiver would apply to Lines CA‑324 and CA‑325 (including CA‑325A and CA‑325B). PHMSA’s notice extends the public comment period to April 3, 2026, following a recent directive from the Secretary of Energy under the Defense Production Act (DPA) that requires Sable to resume oil transport on these segments.

The DPA order, issued on March 13, 2026, effectively overrides PHMSA’s usual 180‑day remediation rule, allowing the pipeline to operate while the corrosion issue remains unresolved. PHMSA is soliciting comments on whether the special permit remains necessary and how the DPA order might affect safety and environmental analyses. The agency will consider these comments when deciding whether to grant or deny the waiver.

For stakeholders in geoscience, energy, and environmental fields, this development highlights the tension between national energy production priorities and pipeline safety regulations. The extended comment period provides an opportunity for industry, regulators, and the public to weigh the risks of continued operation against the benefits of maintaining crude oil flow to California’s refineries.

Key Elements

• Special Permit Request – Sable Offshore Corp. seeks a waiver of the 180‑day corrosion remediation requirement under 49 CFR 195.452(h)(4)(iii)(H).
  
• Affected Pipeline Segments – Lines CA‑324 and CA‑325 (including CA‑325A and CA‑325B) of the Santa Ynez Pipeline System.
  
• Defense Production Act (DPA) Order – On March 13, 2026, the Secretary of Energy directed Sable to restart oil transport on the affected segments, overriding PHMSA’s remediation rule.
  
• Extended Comment Period – PHMSA has extended public comment until April 3, 2026, to incorporate feedback on the DPA order’s impact.
  
• Public Participation – Comments can be submitted via regulations.gov, fax, mail, or hand delivery; confidential business information may be designated under FOIA.
  
• Regulatory Review – PHMSA will evaluate comments and determine whether to grant or deny the special permit, balancing pipeline safety, environmental protection, and energy supply needs.
  
• Implications for Geoscience and Energy – The waiver could affect corrosion monitoring, pipeline integrity assessments, and the broader regulatory framework governing hazardous liquid transport.

U.S. Launches Trade Probe into Large Graphite Electrodes from China and India

Overview

The U.S. Department of Commerce’s International Trade Administration (ITA) has opened investigations into imports of large‑diameter graphite electrodes from the People’s Republic of China and India. The probes are aimed at determining whether these products are being sold in the United States at less‑than‑fair value (LTFV) and whether such sales are materially injuring the domestic graphite‑electrode industry.

The investigations cover large graphite electrodes (diameter >425 mm) and associated pin‑joining systems used in industrial furnaces. China is treated as a non‑market economy, while India is a market‑economy country, which shapes the methodology for valuing factors of production and calculating dumping margins. Preliminary dumping margins range from roughly 40 % to 150 % depending on the surrogate country used for China and the single margin for India.

If the ITC finds evidence of injury or threat of injury, the ITA will proceed with antidumping and countervailing duty actions. The process involves electronic questionnaires, separate‑rate applications, and a 140‑day timeline for preliminary determinations, giving U.S. producers, exporters, and interested parties a window to submit comments and factual information.

Key Elements

• Scope of the Investigation

  • Large diameter graphite electrodes (≥425 mm) and graphite pin‑joining systems (≥228.6 mm).
    
  • Excludes small‑diameter electrodes already covered by an existing antidumping order.
    

• Period of Investigation (POI)

  • India: Jan 1 – Dec 31 2025.
    
  • China (NME): Jul 1 – Dec 31 2025.
    

• Industry Support

  • Petitioners (Resonac Graphite America and Tokai Carbon GE) represent 100 % of U.S. production of the domestic‑like product, satisfying statutory support requirements.
    

• Dumping Margins

  • China (Brazil surrogate): 44.7 %–116.6 %.
    
  • China (Malaysia surrogate): 38.3 %–98.8 %.
    
  • China (Türkiye surrogate): 77.6 %–146.7 %.
    
  • India: 42.6 %–73.4 %.
    

• Respondent Selection

  • China: 28 identified exporters; Q&V questionnaires sent to the largest based on U.S. Customs data.
    
  • India: 3 identified exporters; mandatory respondents selected via CBP data.
    

• Separate‑Rate and Combination‑Rate Procedures

  • Exporters may apply for separate rates by submitting Q&V and separate‑rate applications within 21 days of notice.
    
  • Combination rates apply to exporters and their producers when separate rates are granted.
    

• Filing and Comment Deadlines

  • Scope comments: April 6 2026.
    
  • Product‑characteristic comments: April 6 2026.
    
  • Q&V responses: March 30 2026.
    
  • Separate‑rate applications: March 31 2026.
    

• ITC Preliminary Determination

  • Must be issued within 45 days of petition filing; a negative determination ends the investigation for that country.
    

• Administrative Protective Order (APO) and Electronic Filing

  • All submissions must be filed electronically via ACCESS and may be subject to APO for confidential information.
    

These provisions set the framework for how the U.S. will assess potential dumping, protect domestic producers, and manage trade relations with China and India in the graphite‑electrode sector.

NOAA Seeks Public Input on Voluntary Data Collection to Boost Natural Resource Restoration Planning

Overview

The National Oceanic and Atmospheric Administration (NOAA) has issued a notice under the Paperwork Reduction Act (PRA) inviting public comment on a renewal of an approved information‑collection form: the Natural Resource Damage Assessment (NRDA) Restoration Project Information Sheet. The sheet is designed to gather details on existing, planned, or proposed restoration projects that may be needed to repair natural‑resource injuries or service losses identified in NRDA investigations. By compiling this data, NOAA’s Office of Habitat Conservation helps state, local, and federal “Natural Resource Trustees” develop realistic restoration alternatives in compliance with the National Environmental Policy Act (NEPA) and related statutes.

The collection is voluntary, requires no monetary cost, and is expected to take about 20 minutes per submission. NOAA estimates that roughly 300 respondents—ranging from government agencies to private businesses and individuals—will provide the information each year, resulting in an estimated 100 total burden hours. The data will be used to inform restoration planning, not to award benefits to individual submitters, and can be updated at any time without a mandatory schedule.

NOAA is soliciting comments through May 19, 2026 to evaluate the necessity, accuracy of burden estimates, and ways to improve the quality and clarity of the information collected. Comments will be part of the public record and will be included in NOAA’s request to the Office of Management and Budget (OMB) for approval of the collection.

Key Elements

• Purpose: Assist Natural Resource Trustees in planning restoration alternatives for NRDA‑identified injuries or service losses.
  
• Legal Authority: National Environmental Policy Act (NEPA) and related federal regulations.
  
• OMB Control Number: 0648‑0497.
  
• Form: No separate form number; information is collected via an online or email submission.
  
• Respondents: Approximately 300 entities (state, local, tribal governments; businesses; individuals; nonprofits; farms; federal agencies).
  
• Time Burden: ~20 minutes per response; total annual burden ~100 hours.
  
• Cost to Public: $0 in record‑keeping or reporting.
  
• Voluntary: No obligation to submit; no individual benefits tied to submission.
  
• Method of Collection: Electronic internet portal or email.
  
• Comment Period: Open until May 19, 2026.
  
• Contact for Comments: Adrienne Thomas, NOAA PRA Officer – NOAA.PRA@noaa.gov (reference OMB Control Number in subject line).
  
• Additional Information: William Nichols, IT Specialist, NOAA – 301‑427‑8623, william.w.nichols@noaa.gov.
  
• Publication: 91 FR 13593 (March 20, 2026).
  
• Goal of Comments: Assess necessity, burden accuracy, data quality, and potential automation or technology improvements.

Hawks Nest Hydro Seeks to Upgrade Power Plant, Boost Capacity, and Align with Regional Grid

Overview
The Federal Energy Regulatory Commission (FERC) has accepted a notice of application from Hawks Nest Hydro, LLC to amend its license for the Hawks Nest Hydroelectric Project on the New River in Fayette County, West Virginia. Filed on March 5 2026, the amendment proposes converting the plant’s power output from the legacy 25 Hz frequency to the standard 60 Hz used by the regional electric grid, thereby enabling direct sale of electricity to the grid.

The technical changes include replacing the existing turbines and generators, building a new switchyard, upgrading one of the primary transmission lines, and constructing a new access road and support building. These upgrades will raise the plant’s authorized capacity from 102 MW to 108.5 MW and increase hydraulic capacity from 10,160 cfs to 10,380 cfs. The project will continue to operate in run‑of‑river mode during and after construction, with adjustments to recreational flow releases to accommodate the new infrastructure.

Regulatory requirements are significant: a water‑quality certification under the Clean Water Act must be obtained from the West Virginia Department of Environmental Protection, and the public, state, tribal, and federal agencies are invited to submit comments, protests, or motions to intervene by April 16 2026. FERC encourages electronic filing and provides detailed instructions for participation, underscoring the transparency and stakeholder engagement integral to the licensing process.

Key Elements

• Frequency Conversion – Shift from 25 Hz to 60 Hz to integrate with the regional grid.
  
• Capacity Increase – Authorized installed capacity rises from 102 MW to 108.5 MW; hydraulic capacity from 10,160 cfs to 10,380 cfs.
  
• Infrastructure Upgrades – New switchyard, transmission line upgrade, access road, and prefabricated building.
  
• Operational Continuity – Project remains run‑of‑river during and after construction; recreational flow releases will be adjusted.
  
• Environmental Compliance – Requires a Clean Water Act Section 401 water‑quality certificate from the West Virginia DEP.
  
• Public Participation Window – Comments, protests, and motions to intervene due by April 16 2026; electronic filing encouraged.
  
• Stakeholder Engagement – Federal, state, local, and tribal agencies invited to cooperate on environmental documentation; cooperating agencies cannot intervene.
  
• Regulatory Framework – Notice issued under the Federal Power Act; follows FERC Rules of Practice and Procedure (18 CFR 385).

FERC Opens Inquiry into Vermont’s Potter Brook Hydroelectric Project: Who’s Involved and What’s at Stake

Overview

The Federal Energy Regulatory Commission (FERC) has issued a notice to investigate whether it has jurisdiction over the Potter Brook Hydroelectric Project in Orleans County, Vermont. The Vermont Department of Environmental Conservation (DEC) requested this determination because the project sits on a stream that falls under Congress’s Commerce Clause, was built after August 26, 1935, and is connected to the interstate power grid. If FERC finds it has jurisdiction, the project would need to be licensed or exempted under the Federal Power Act (FPA).

The Potter Brook plant, owned by Arlon Warner, began generating power in the early 1980s and has sold electricity to the grid since 1984. Warner’s initial exemption applications in 1983 and 1986 were rejected as deficient, leaving the project without a formal FERC license. The DEC’s request seeks to clarify whether the plant’s location and operation trigger federal oversight, a question that hinges on the interpretation of the FPA’s jurisdictional criteria for non‑federal hydroelectric projects.

FERC is inviting public input. Comments, protests, and motions to intervene must be filed by May 1, 2026. Stakeholders—including local communities, environmental groups, and industry participants—can submit written or electronic filings through FERC’s eFiling system. The outcome will determine whether the Potter Brook plant must comply with federal licensing requirements, potentially affecting its future operations and regulatory obligations.

Key Elements

• Jurisdictional Basis: FERC will assess whether the project falls under the FPA’s Commerce Clause jurisdiction—i.e., a stream over which Congress has authority, built after 1935, and affecting interstate commerce.
  
• Project Profile:
  
  • Location: Potter Brook, Orleans County, Vermont.
    
  • Owner: Arlon Warner.
    
  • Operation: Began in the early 1980s, connected to the interstate grid, selling power since 1984.
    
• Licensing History:
  
  • 1983 and 1986 exemption applications denied as deficient.
    
  • No current FERC license or exemption in place.
    
• Public Participation:
  
  • Deadline for comments, protests, and motions to intervene: May 1, 2026.
    
  • Filing methods: electronic via FERC eFiling/eComment or paper mail.
    
• Implications for Energy and Environmental Policy:
  
  • A jurisdictional finding could require a new license or exemption, influencing regulatory compliance, environmental reviews, and grid integration.
    
  • The decision may set precedent for other small hydro projects on tributaries of navigable waters.
    
• Contact Information:
  
  • FERC Office of Public Participation: (202) 502‑6595 or OPP@ferc.gov.
    
  • eFiling portal: https://www.ferc.gov/docs-filing/efiling.asp.
    

These points outline the legal, operational, and participatory dimensions of the pending inquiry, offering a clear snapshot for professionals and interested citizens alike.

EPA Publishes Its Comments on Federal Environmental Impact Statements

Overview

On March 20 2026 the Environmental Protection Agency (EPA) issued a notice announcing that it has made public its comments on a series of Environmental Impact Statements (EISs) prepared by other federal agencies. The notice is part of the EPA’s commitment to transparency under the Clean Air Act and the National Environmental Policy Act (NEPA). By releasing these comment letters, the EPA allows stakeholders—including scientists, industry, and the public—to review how federal decisions on projects such as flood protection, nuclear plant renewals, and other infrastructure initiatives weigh environmental risks and benefits.

The notice lists three specific EISs that the EPA has reviewed: a flood‑protection project in Utah, and two supplemental EISs for license renewals of nuclear power plants in South Carolina and Florida. For each EIS, the notice provides the final status, the review period end date, and contact information for the EPA staff who prepared the comments. The EPA also reminds readers that its comment letters are available online through the EPA’s NEPA database.

Key Elements

• Transparency Requirement – EPA is fulfilling Section 309(a) of the Clean Air Act by publicly posting its comments on other agencies’ EISs.
  
• EISs Reviewed –
  
  • EIS 20260027: Final EIS for the Gould Wash Flood Protection Project, Utah.
    
  • EIS 20260028: Final Supplement for the license renewal of the H.B. Robinson Steam Electric Plant, Unit 2, South Carolina.
    
  • EIS 20260029: Final Supplement for the license renewal of the St. Lucie Plant, Units 1 and 2, Florida.
    
• Review Periods – All three EISs have a review period that ends on May 4 2026.
  
• Contact Information – EPA staff contacts: Ammon Boswell (Utah project), Karen Loomis (South Carolina plant), and Lance Rakovan (Florida plant).
  
• Access to Comments – EPA’s comment letters are available online at the EPA NEPA database (https://cdxapps.epa.gov/cdx-enepa-II/public/action/eis/search).
  
• Regulatory Context – The notice is issued under the EPA’s Office of Federal Activities and follows guidance from the Council on Environmental Quality (CEQ) on 42 U.S.C. 4332.

EU‑Japan Horizon Europe Partnership: A New Era of Joint Innovation

Overview

The European Union and Japan have agreed to associate Japan with Horizon Europe, the EU’s flagship research and innovation programme, starting 1 January 2026. The deal, formalised in a Council Decision, creates a long‑term framework for Japanese participation in the programme’s Pillar II – “Global Challenges and European Industrial Competitiveness.” This pillar covers climate, ocean and environmental research, clean energy, high‑performance computing, semiconductors, and circular economy, all areas where Japan’s world‑class research infrastructure and expertise can complement EU priorities.

The agreement sets out how Japan will contribute financially, how its researchers can access EU funding calls, and how both sides will safeguard the integrity of the programme through joint oversight, open‑science commitments, and mechanisms for correcting any over‑ or under‑payments. It also establishes a Joint Committee to monitor implementation, resolve disputes, and shape future cooperation.

Key Elements

• Association and Participation

  • Japan becomes an associated country for Horizon Europe Pillar II, gaining full access to calls, funding, and collaborative projects.
    
  • Japanese entities can join European partnerships and joint research centres, including the Joint Research Centre (JRC).

• Financial Contribution

  • Japan pays an operational contribution (≈ €13.7 million for 2026‑27) plus a participation fee (3 % in 2026, 4 % in 2027).
    
  • Contributions are calculated using a GDP‑based key and include a contingency reserve; an automatic correction mechanism adjusts payments if grant disbursements exceed contributions.

• Governance and Oversight

  • A Joint Committee (EU and Japan representatives) reviews performance, finances, and policy alignment; decisions are made by consensus.
    
  • The agreement includes provisions for audits, fraud prevention, and cooperation with the European Public Prosecutor’s Office.

• Open Science and Reciprocity

  • Both parties commit to open‑science practices, data sharing, and mutual access to research outputs.
    
  • Japanese programmes equivalent to Horizon Europe Pillar II (e.g., CREST, ERATO) are listed for reciprocal participation.

• Suspension and Flexibility

  • Japan may request suspension of the protocol if grant awards exceed 80 % of its contribution, allowing a pause in participation for a year.
    
  • The protocol can be amended or terminated by mutual written consent, with clear rules for financial adjustments.

• Geoscience and Energy Focus

  • The partnership targets climate‑action research, oceanography, renewable energy (especially offshore wind and hydrogen), and circular economy, aligning with EU Green Deal and Japan’s “Society 5.0” vision.
    
  • Joint projects will leverage Japan’s advanced research infrastructures (e.g., synchrotrons, supercomputers) and the EU’s large‑scale research facilities.

• Implementation Timeline

  • The agreement is provisionally applied from 1 January 2026 while internal procedures are finalised.
    
  • Full entry into force will follow once both parties complete their domestic approvals.

This collaboration marks a significant step toward deeper EU‑Japan research ties, promising accelerated innovation in critical areas such as climate resilience, clean energy, and advanced materials—key to both regions’ economic and environmental futures.

Japan Joins the EU’s Horizon Europe Programme: A New Era of Scientific Collaboration

Overview

The European Union and Japan have agreed to formalise Japan’s participation in the EU’s flagship research and innovation programme, Horizon Europe, through a comprehensive “umbrella” agreement and a specific protocol for Pillar II (Global Challenges and European Industrial Competitiveness). The deal, effective from 1 January 2026, allows Japanese research institutions, companies and universities to apply for EU funding, join European partnerships, and contribute to joint projects in areas such as climate science, oceanography, clean energy, high‑performance computing, and advanced materials.

The agreement is built on a long‑standing partnership between the two sides, extending earlier science‑and‑technology accords and the 2018 Strategic Partnership Agreement. It aligns with the EU’s 2030 Sustainable Development Goals, the Global Approach to Research and Innovation, and the EU’s economic‑security strategy, reinforcing a shared commitment to open science, data sharing, and responsible research practices.

Financially, Japan will make an operational contribution of about €13.7 million for 2026–27 (plus a 4 % participation fee) and will be subject to an automatic correction mechanism that adjusts payments based on the actual value of grants awarded to Japanese entities. A Joint Committee will oversee implementation, monitor performance, and negotiate future protocols, while a national contact point in Japan will facilitate application support and information exchange.

Key Elements

• Association to Horizon Europe Pillar II – Japanese entities can apply for EU grants, join European partnerships, and participate in joint research on climate, ocean, energy, ICT, and advanced materials.
  
• Financial Contribution & Correction Mechanism – €13.7 million (2026–27) plus a 4 % participation fee; automatic correction adjusts payments based on the value of competitive grants awarded to Japan.
  
• Joint Committee – Bi‑annual meetings of EU and Japanese representatives to review implementation, discuss future priorities, and amend protocols by consensus.
  
• Open Science & Data Sharing – Mutual commitment to promote open‑access publishing, open data, and transparent research practices.
  
• Reciprocity & Strategic Asset Safeguards – Japan may provide information on equivalent Japanese programmes and export controls; EU may request assurances on strategic assets and security.
  
• Suspension Mechanism – Japan can request a temporary suspension of the protocol if grant awards exceed 80 % of its contribution, allowing flexibility in early implementation.
  
• National Contact Points (NCPs) – Japanese NCPs will support researchers in preparing EU‑style applications and navigating funding procedures.
  
• Legal & Financial Safeguards – Detailed rules for audits, fraud prevention, and recovery of funds, ensuring protection of EU financial interests.
  
• Provisional Application – The agreement can be applied provisionally from 1 January 2026 while parties complete internal procedures, with full force from the date of mutual notification.
  

This partnership marks a significant step toward deeper EU‑Japan collaboration in science and technology, promising to accelerate joint solutions to global challenges such as climate change, sustainable energy, and resilient supply chains.

Building Smoke‑Ready Communities: A New Grant Program to Fight Wildfire Smoke and Extreme Heat

Overview

The Smoke and Heat Ready Communities Act of 2025 expands the Clean Air Act to create a federal grant program that helps local communities detect, prepare for, and mitigate the health and environmental impacts of wildfire smoke and extreme heat. By authorizing the Environmental Protection Agency (EPA) to fund air‑pollution control agencies, the bill aims to improve monitoring, public communication, and protective measures such as air‑filtration systems and personal protective equipment.

The Act also establishes a research agenda. Within 180 days of enactment, the EPA will set up four Centers of Excellence for Wildfire Smoke and Extreme Heat at universities with strong air‑quality expertise, and allocate $30 million annually for research on health effects, monitoring technologies, and community interventions. These centers will collaborate with local governments, tribes, and Native Hawaiian organizations to tailor solutions to the most vulnerable regions.

Finally, the legislation creates a competitive grant program for states, local governments, Indian tribes, and Native Hawaiian organizations to develop collaborative community plans. Grants will support partnerships with research institutions, technical assistance for grant applications, and the implementation of mitigation strategies, with an annual appropriation of $50 million.

Key Elements

• EPA Grant Program – Funds air‑pollution control agencies to:
  • Monitor and interpret air‑quality data related to wildfire smoke and extreme heat.
  • Conduct community outreach and deploy monitoring equipment.
  • Install air‑filtration systems in public buildings.
  • Distribute face masks, respirators, and portable air‑filters.
  • Provide subgrants to private or public entities for protective gear or weatherization.
• Funding Allocation Formula – Grants distributed based on community vulnerability and prevalence of poor air quality.
• Centers of Excellence – Four university‑based research centers focused on health impacts and community response strategies, prioritized at institutions with air‑quality expertise and local relevance.
• Research Funding – $10 million (FY 2026+) for centers and $20 million (FY 2026+) for broader research on health effects, monitoring tools, and communication strategies.
• Community Planning Grants – $50 million (FY 2026+) to support states, local governments, tribes, and Native Hawaiian organizations in creating collaborative smoke and heat mitigation plans.
• Technical Assistance – EPA will help eligible entities prepare grant applications and implement funded projects.
• Appropriations – The Act authorizes necessary appropriations for all grant and research activities, ensuring sustained funding across fiscal years.

Building Safer Homes: The Disaster Resiliency and Coverage Act of 2025

Overview

The Disaster Resiliency and Coverage Act of 2025 (H.R. 1105) amends the Robert T. Stafford Disaster Relief and Emergency Assistance Act to create a nationwide Individual Household Disaster Mitigation Program. The program directs the President to work with states and Indian tribal governments to identify high‑risk residential areas, develop mitigation plans, and award grants that help homeowners strengthen their homes against floods, wildfires, hurricanes, earthquakes, and other natural hazards.

The Act ties mitigation funding to insurance incentives, requiring states to provide technical assistance, establish mitigation standards, and offer guidance to insurers and consumers. Grants are capped at $10,000 per household (adjusted annually for inflation) and are only available to households with adjusted gross incomes below $250,000 (or $500,000 for joint returns). The legislation also revises tax rules to exclude mitigation payments from taxable income and introduces a 30 % tax credit for qualifying mitigation expenditures.

For geoscientists, energy, and natural resource professionals, the Act underscores the importance of integrating scientific hazard assessments, climate projections, and engineering standards into community resilience planning. It encourages collaboration among insurers, researchers, and local governments to promote evidence‑based mitigation practices that reduce disaster risk and enhance long‑term sustainability.

Key Elements

• Program Establishment: President must set up a grant program for states and tribal governments to fund household‑level mitigation in identified high‑risk areas.
• Eligibility & Income Limits: Grants available only to households with adjusted gross income ≤ $250,000 (or $500,000 for joint returns); high‑risk areas defined by scientific hazard assessments.
• Mitigation Standards: Multi‑tiered standards based on industry (e.g., Insurance Institute for Business & Home Safety) and federal guidelines for wind, flood, fire, and seismic resilience.
• Insurance Incentives: States must provide guidance to insurers, encouraging discounts, rebates, or premium credits for homes that meet mitigation standards.
• Grant Caps & Inflation Adjustment: Maximum $10,000 per household, adjusted yearly for the Consumer Price Index.
• Tax Treatment: Mitigation payments excluded from gross income; 30 % tax credit for qualifying mitigation expenditures, with specific rules for state‑funded reimbursements.
• Advisory Committee: 50‑member committee (insurance regulators, industry, academia, environmental groups) advises on emerging mitigation technologies and standards.
• Geoscience Integration: Program requires states to use current scientific tools and data (hazard likelihood, severity, climate projections) to define eligible disaster areas and update them every five years.
• Non‑Preemption Clause: The Act does not preempt state insurance regulation or require insurers to alter underwriting practices beyond the program’s incentives.
• Legislative Status: Referred to the Subcommittee on Economic Development, Public Buildings, and Emergency Management; pending further consideration.

EPA Declines to Regulate Nine New Drinking‑Water Contaminants, Keeping Current Standards Intact

Overview

The U.S. Environmental Protection Agency (EPA) has issued final regulatory determinations for nine chemicals that were listed on the fifth Drinking Water Contaminant Candidate List (CCL 5). Under the Safe Drinking Water Act (SDWA), the EPA must review unregulated contaminants every five years and decide whether to establish a national primary drinking water regulation (NPDWR). After a thorough assessment of health effects, occurrence data from the Unregulated Contaminant Monitoring Rule (UCMR 4), and public comments, the agency concluded that none of the nine substances—2‑aminotoluene, cylindrospermopsin, ethoprop, microcystins, molybdenum, permethrin, profenofos, tebuconazole, and tribufos—meet the statutory criteria for regulation.

The decision means that public water systems will not be required to monitor or treat for these chemicals, and no new maximum contaminant level goals will be established. The EPA emphasized that the findings are based on current scientific evidence and national monitoring data; however, the agency will revisit the list if new health or occurrence information emerges.

The announcement also highlights the EPA’s evolving approach to regulatory determinations, noting a recent court ruling that may influence future decisions and the agency’s intent to conduct preliminary benefits and treatment feasibility analyses before issuing positive determinations.

Key Elements

• Nine contaminants excluded from regulation:

  • 2‑aminotoluene (synthetic aromatic amine)
    
  • Cylindrospermopsin (cyanobacterial toxin)
    
  • Ethoprop (organophosphate pesticide)
    
  • Microcystins (cyanobacterial toxin)
    
  • Molybdenum (naturally occurring metal)
    
  • Permethrin (pyrethroid pesticide)
    
  • Profenofos (organophosphate pesticide)
    
  • Tebuconazole (fungicide)
    
  • Tribufos (thiophosphate pesticide)
    

• Regulatory criteria: EPA applied the SDWA’s three statutory criteria—adverse health effect potential, frequency/level of occurrence in public water systems, and meaningful opportunity for health‑risk reduction. All nine contaminants failed to meet at least the second and third criteria.

• Data sources:

  • UCMR 4 national monitoring data (2018‑2020) for public water systems serving >10,000 people and a representative sample of 800 small systems.
    
  • Health reference levels (HRLs) derived from peer‑reviewed toxicity studies and EPA’s Gold Standard Science framework.
    

• Occurrence findings: For each contaminant, less than 0.2 % of monitored systems exceeded the HRL, and the population served by those systems was below 0.1 %.

• No regulatory action: The EPA will not issue NPDWRs or enforce monitoring requirements for these chemicals at this time.

• Future considerations:

  • The agency will monitor new scientific or occurrence data that could alter the status of these contaminants.
    
  • A 2023 court decision (NRDC v. Regan) may shape how the EPA handles future positive determinations.
    
  • EPA plans to conduct preliminary benefits and treatment feasibility analyses for contaminants that meet the first two criteria before moving to regulation.
    

• Public and stakeholder engagement: The EPA received comments from eight organizations and individuals, most of which supported the negative determinations. The agency’s responses are documented in the final regulatory determination support materials.

• Implications for geoscience and natural resource fields:

  • The findings reinforce the importance of ongoing monitoring of naturally occurring metals (e.g., molybdenum) and pesticide residues in surface and groundwater.
    
  • The decision underscores the role of cyanobacterial toxins in water quality assessments and the effectiveness of conventional treatment processes in mitigating these risks.
    
  • The EPA’s transparent, data‑driven approach provides a framework for scientists and resource managers to evaluate emerging contaminants and advocate for evidence‑based regulation.

Forest Service Updates Filming Rules to Match New EXPLORE Act

Overview

The U.S. Forest Service has finalized a rule that revises its special‑use regulations for filming and still photography on National Forest System lands. The changes bring the agency’s rules into line with the recently enacted EXPLORE Act, which modernizes how public lands accommodate content creators while protecting natural and cultural resources.

The rule introduces a three‑tier system for permits and fees: no authorization is required for activities involving five or fewer people; a de‑minimis use authorization (no fee) applies to groups of six to eight; and a full special‑use permit with a reasonable fee is required for larger groups or activities that do not meet the lower‑tier criteria. Definitions of “filming or still photography” and “content creation” have been updated to reflect the Act’s broader, platform‑agnostic language.

These administrative updates do not create new environmental or economic burdens. The Forest Service will provide an online e‑permitting portal for quick approvals, and the rule explicitly protects resources by allowing the agency to deny activities that could damage natural or cultural values or disrupt public enjoyment.

Key Elements

• Alignment with the EXPLORE Act – Technical revisions incorporate the Act’s statutory language and permitting thresholds.
  
• Three‑tier permit structure –
  
  • No permit for ≤5 people or incidental activities.
    
  • De‑minimis use authorization (no fee) for 6–8 people.
    
  • Full special‑use permit with a reasonable fee for >8 people or non‑compliant activities.
    
• Updated definitions – “Filming or still photography” and “content creation” now cover all media, regardless of distribution platform.
  
• E‑permitting – The Forest Service will offer a public website and in‑person options for automated, immediate approvals of qualifying activities.
  
• Resource protection – The agency retains the authority to deny any activity that could damage natural or cultural resources, cause undue disruption, or pose health and safety risks.
  
• No new fees for small groups – De‑minimis use authorizations are free, reducing administrative costs for small‑scale creators.
  
• Minimal economic impact – The rule does not affect small entities, state or local governments, or tribal interests.
  
• No significant environmental or energy effects – Classified as a technical, clarifying revision with no need for environmental assessments.
  
• Preemption of conflicting state/local rules – The rule will preempt any state or local regulations that conflict with the new federal requirements.

Northern Natural Gas Company Seeks Approval for Pipeline Expansion and Abandonment, Opens Public Participation Window

Overview

Northern Natural Gas Company (Northern) has filed a formal application with the Federal Energy Regulatory Commission (FERC) under the Natural Gas Act to modify its pipeline network in Minnesota. The application covers two linked projects: the Ventura to Farmington A-Line Abandonment and Capacity Replacement (V2F) Project, which will retire aging 16‑ and 18‑inch lines and replace them with new 30‑ to 36‑inch extensions, and the Northern Lights 2027 Expansion (NL27) Project, which will add new pipeline segments and upgrade a compressor station to increase firm service capacity by 79.3 million therms per day.

The FERC notice announces that the company will conduct an environmental review within 90 days, and it invites the public to comment, protest, or intervene in the proceeding. The intervention deadline is set for 5:00 p.m. Eastern Time on April 6, 2026. The notice also provides details on how to file comments or motions to intervene, and it highlights that the projects are expected to cost roughly $146 million for the V2F and $133 million for the NL27.

For stakeholders—including geoscientists, energy professionals, and local communities—this filing signals a significant change in the region’s natural gas infrastructure. It offers an opportunity to assess potential environmental impacts, land‑use effects, and the broader implications for regional energy supply and market dynamics.

Key Elements

• Projects Covered

  • V2F Project: Abandonment of ~131 mi of 16‑/18‑inch lines; construction of 8.29 mi (36‑inch) and 2.09 mi (36‑inch) extensions, plus a 7.50 mi (30‑inch) extension. No net capacity increase; maintains service continuity.
    
  • NL27 Project: Ten new pipeline extensions totaling 28.43 mi; replacement of a 7,000 hp compressor with a 7,700 hp unit at Hugo Compressor Station. Adds 79.3 million therms/day of firm service.

• Financial Scope

  • Estimated cost: $146.5 million (V2F) and $132.8 million (NL27).

• Regulatory Process

  • FERC will complete an environmental review within 90 days of the notice.
    
  • Public participation avenues: comments, protests, and motions to intervene.
    
  • Intervention deadline: 5:00 p.m. ET, April 6, 2026.

• Public Engagement

  • Comments and protests must reference docket number CP26‑130‑000.
    
  • Electronic filing via eComment or eFiling; paper filings accepted.
    
  • Intervenors gain rights to request rehearings and challenge decisions.

• Contact Information

  • Northern’s Senior Regulatory Analyst: Donna Martens, 1111 S 103rd St., Omaha, NE.
    
  • FERC Office of Public Participation: 202‑502‑6595 or OPP@ferc.gov.
    

• Documentation Access

  • Full application and related documents available on FERC’s eLibrary (PDF and Word).
    
  • Environmental documents (EA/EIS) will be posted once issued.

Tribal Energy Agreements: A Call for Comments on Renewed Reporting Requirements

Overview

The Bureau of Indian Affairs (BIA) has issued a notice to renew an existing information‑collection requirement under the Paperwork Reduction Act. The collection pertains to Tribal Energy Resource Agreements (TERAs), the legal framework that allows federally recognized tribes to negotiate, implement, or terminate agreements for the development of energy resources on tribal lands. The renewal is a continuation of a previously approved process, with no substantive changes to the forms or data requested.

This notice invites public and agency comments on the necessity, accuracy, and burden of the collection. The BIA estimates that, on average, one tribe will submit 11 responses each year, totaling roughly 2,960 hours of effort and $18,100 in non‑hour costs. The goal is to ensure that the data collected remains useful for policy and regulatory purposes while minimizing the reporting burden on tribes and the public.

The notice also highlights that the collection requires tribes to publicly notify the Department of Interior about certain actions related to TERAs and allows the public to petition the Interior Department if they believe a tribe is non‑compliant. Comments are due by April 20, 2026, and can be submitted through the Office of Information and Regulatory Affairs (OIRA) or via the federal regulations portal.

Key Elements

• Renewal of an existing information‑collection under the Paperwork Reduction Act (PRA) with OMB Control Number 1076‑0167.
  
• Scope: Data required for tribes to apply for, implement, reassume, or rescind a Tribal Energy Resource Agreement under 25 U.S.C. 3501 and 25 CFR part 224.
  
• Estimated burden: ~2,960 annual hours, 11 responses, $18,100 in non‑hour costs; average of one tribe responding each year.
  
• Public notification requirement: Tribes must inform the Interior Department of certain TERA actions; the public may file petitions for alleged non‑compliance.
  
• Comment period: 60 days, closing April 20, 2026; submissions accepted via OIRA or Regulations.gov.
  
• Purpose: To assess whether the collection remains necessary, accurate, and efficient, and to explore ways to reduce respondent burden through electronic or automated means.
  
• Affected parties: Federally recognized Indian tribes and the general public.

Blue Earth County Revises Timeline for Environmental Review of Rapidan Hydroelectric Project

Overview
The Federal Energy Regulatory Commission (FERC) has issued a notice updating the schedule for the environmental assessment (EA) of the Rapidan Hydroelectric Project in Blue Earth County, Minnesota. The project, which is not on federal land, is undergoing a surrender of its exemption status, a process that requires a formal environmental review under FERC regulations.

The notice extends the anticipated issuance of the EA from the original April 1, 2026 deadline to August 10, 2026, to accommodate additional information submitted by the project owner in February 2026. Once published, the EA will be open for a 30‑day public comment period, during which stakeholders can submit feedback that will be considered in the final decision.

This revision underscores FERC’s commitment to thorough environmental analysis while allowing time for stakeholders—including local communities, environmental groups, and industry participants—to review and respond. The agency encourages public participation and provides contact details for inquiries, interventions, or comments.

Key Elements

• Project: Rapidan Hydroelectric Project, located on the Blue Earth River, Blue Earth County, Minnesota.
  
• Exemption Surrender: The exemptee filed a surrender application on March 18, 2025 (superseding an earlier 2023 filing).
  
• Revised EA Schedule: Environmental Assessment to be issued by August 10, 2026.
  
• Comment Period: 30 days following EA publication.
  
• Public Participation: Opportunities for interventions, comments, and rehearing requests; contact Office of Public Participation (202‑502‑6595, OPP@ferc.gov).
  
• Authority: Action taken under 18 CFR 2.1.
  
• Contact: Diana Shannon, FERC (202‑502‑6136, diana.shannon@ferc.gov).

Colorado Gains Authority to Regulate Carbon‑Sequestration Wells Under New EPA Rule

Overview

The U.S. Environmental Protection Agency (EPA) has proposed to approve the State of Colorado’s request for primary enforcement responsibility (primacy) over Class VI underground injection wells—those used for long‑term geological storage of carbon dioxide (CO₂). Under the Safe Drinking Water Act (SDWA), states that meet federal requirements can administer their own Underground Injection Control (UIC) programs. Colorado’s application, submitted in October 2025, demonstrates that its Energy and Carbon Management Commission (ECMC) has the legal, technical, and administrative capacity to regulate CO₂ injection while protecting underground sources of drinking water (USDWs).

If finalized, the rule will allow Colorado to issue, enforce, and monitor Class VI permits for CO₂ sequestration projects throughout the state, except on Indian lands where EPA retains primacy. The EPA’s approval would incorporate Colorado’s statutes and regulations by reference into the federal UIC framework, ensuring that state‑issued permits carry the same legal weight as federal permits. The rule also establishes EPA oversight, requiring quarterly compliance reports and annual performance summaries to ensure that state administration remains consistent with federal standards.

The proposed rule is currently active, with a public comment period ending May 4, 2026. Stakeholders—including industry, environmental groups, and tribal governments—can submit written comments or participate in a virtual hearing scheduled during the comment period.

Key Elements

• Primacy Approval – EPA proposes to grant Colorado primary enforcement authority for Class VI injection wells, except those on Indian lands.
  
• Incorporation by Reference – Colorado’s statutes and regulations (e.g., Oil and Gas Conservation Act, Administrative Procedure Act) will be incorporated into 40 CFR 147, making state‑issued permits enforceable under federal law.
  
• Technical Safeguards – Permits will require site characterization, hydraulic‑modeling, well‑construction standards, continuous monitoring (pressure, seismicity, CO₂ plume), and emergency response plans.
  
• Financial Assurance – Operators must provide financial guarantees covering all phases of the project, including post‑injection site care and closure.
  
• Public Participation – Colorado conducted extensive stakeholder outreach, public hearings, and a state rulemaking process before submitting its primacy application.
  
• EPA Oversight – EPA will receive quarterly non‑compliance reports and annual UIC performance reports, and will monitor the state program through a Memorandum of Agreement.
  
• No Significant Economic Impact on Small Entities – The rule is exempt from the Regulatory Flexibility Act because it transfers existing federal requirements to the state without adding new burdens.
  
• Limited Federal Mandates – The action does not impose unfunded mandates on state, local, or tribal governments.
  
• Comment Period – Public comments are accepted until May 4, 2026, with a virtual hearing scheduled during this period.

Rebuilding Forests After Disaster: A New Federal Reforestation Act

Overview

The Post‑Disaster Reforestation and Restoration Act mandates the U.S. Secretary of the Interior to launch a coordinated program that identifies and restores federal and tribal lands damaged by unplanned disturbances such as wildfires, pest outbreaks, or extreme weather. Within one year of enactment, the Secretary must work with the National Park Service, Fish and Wildlife Service, Bureau of Land Management, Bureau of Reclamation, and Bureau of Indian Affairs to map “covered lands” that cannot naturally regenerate and to set annual priority projects.

The Act provides a flexible funding framework—competitive grants, contracts, and cooperative agreements—to support these priority projects, including ensuring adequate seed and seedling supplies. Outreach to Indian tribes, states, local governments, and other stakeholders is required to foster collaboration and leverage local knowledge. Annual reports to Congress will track progress, funding, and gaps, and the program’s authority expires seven years after enactment.

For geoscientists, natural resource managers, and energy professionals, the legislation signals a renewed federal commitment to ecosystem resilience, a structured pathway for securing restoration funding, and a framework for integrating scientific expertise into post‑disaster recovery efforts.

Key Elements

• Program Mandate: Secretary of the Interior must identify and prioritize reforestation/restoration projects on federal and Indian lands within one year of enactment.
• Priority Projects: Annual list of projects to be developed in consultation with covered agencies; projects may be funded through grants, contracts, or cooperative agreements.
• Funding Mechanisms: Competitive grants, direct contracts, Indian Self‑Determination contracts, and cooperative agreements; provisions to secure seed and seedling supplies.
• Stakeholder Outreach: Mandatory engagement with Indian tribes, states, territories, local governments, Alaska Native and Native Hawaiian organizations, higher‑education institutions, and adjacent federal agencies.
• Reporting Requirements: Two‑year initial report and annual updates to Congress detailing land assessments, project progress, funding allocations, outreach activities, and recommendations for addressing gaps.
• Sunset Clause: Program authority expires seven years after enactment, encouraging timely implementation and evaluation.
• Definitions: Clarifies “covered lands,” “covered agencies,” “unplanned disturbance,” “reforestation,” and “restoration,” ensuring consistent application across federal and tribal contexts.

CFTC Pulls Back Climate‑Risk Inquiry After Executive Order Revocation

Overview

In June 2022 the Commodity Futures Trading Commission (CFTC) issued a request for information (RFI) to gather public input on how climate‑related financial risks affect derivatives and commodity markets. The RFI was issued under Executive Order 14030, which directed federal agencies to assess climate risk in financial systems.

On January 20 2025 President Trump signed Executive Order 14154, revoking EO 14030 and shifting the federal focus toward “unleashing American energy.” With the original mandate removed, the CFTC determined that its existing regulatory framework—particularly provisions in 17 CFR part 38 that address market integrity and risk—already covers climate‑related financial risk. Consequently, the agency withdrew the RFI on March 16 2026, noting that the action is not a significant regulatory change and does not constitute a major rule under the Congressional Review Act.

For stakeholders in geoscience, energy, and natural resources, the withdrawal means that no new data collection or reporting requirements will be imposed by the CFTC on climate risk. Existing regulations remain in force, and the agency will continue to monitor market stability and integrity without the additional RFI‑based input.

Key Elements

• Withdrawal date: March 16 2026 (published March 18 2026).
  
• Original RFI: Issued June 8 2022 (87 FR 34856) under EO 14030.
  
• Executive Order revocation: EO 14154 (January 20 2025) revoked EO 14030.
  
• Regulatory basis: CFTC’s own rules (17 CFR part 38, Subparts D, E, L) already address financial risk, including climate‑related factors.
  
• Regulatory impact: Classified as a non‑significant, non‑major rule; no new reporting or compliance obligations.
  
• Stakeholder implication: No additional data collection on climate risk; existing market‑integrity safeguards remain.

USGS Seeks Public Input on Earth Mapping Data Collection for Mineral‑Resource Mapping

Overview

The U.S. Geological Survey (USGS) has issued a notice to renew its information‑collection request under the Paperwork Reduction Act (PRA). The request concerns the Earth Mapping Resources Initiative (Earth MRI), a program funded by the Infrastructure Investment and Jobs Act (IIJA) that allocates $320 million annually (FY 2022‑FY 2026) to modernize surface and subsurface geological mapping across the United States. The initiative is specifically aimed at identifying areas that may contain critical mineral resources, a priority highlighted by Executive Order 14154, “Unleashing American Energy.”

Earth MRI operates through competitive cooperative agreements with state geological surveys. Each state can apply for up to two‑year projects, and the USGS collects data on applications, progress reports, and final reports to monitor compliance with federal assistance requirements and to ensure that the allocated funds are used effectively. The notice invites public comments on the necessity, burden, and quality of this data collection before the Office of Management and Budget (OMB) approves the continued collection.

The comment period closes on May 18, 2026. Respondents—primarily state geological surveys—are expected to submit 125 responses annually, with an estimated total burden of 2,600 hours per year. The USGS seeks feedback on whether the collection is essential, accurate, and efficient, and welcomes suggestions for reducing respondent burden.

Key Elements

• Program Purpose: Modernize U.S. geological mapping to locate critical mineral deposits.
  
• Funding: $320 million per year for five years (FY 2022‑FY 2026) under the IIJA.
  
• Cooperative Agreements: Competitive, up to two‑year projects with state geological surveys.
  
• Information Collection:
  
  • Applications (≈ 25 hrs each, 25 respondents)
    
  • Progress reports (≈ 8 hrs each, 3 reports per recipient)
    
  • Final reports (≈ 20 hrs each)
    
  • Total annual burden: 2,600 hours.
    
• OMB Control Number: 1028‑0133.
  
• Compliance: Meets IIJA Section 40201, Executive Order 14154, and 2 CFR 200 federal assistance requirements.
  
• Comment Period: Open until May 18, 2026; comments can be submitted via Regulations.gov or by mail.
  
• Contact: Tina Hamalak, Earth MRI Program Lead, earthmri@usgs.gov (phone: 303‑236‑5766).

Washington Winter Storms: SBA Corrects Disaster Declaration Dates, Keeps Loan Support Open

Overview
In late 2025, Washington State experienced a severe winter storm event that disrupted transportation, power, and water infrastructure across the region. The U.S. Small Business Administration (SBA) issued an administrative declaration of disaster on February 25 2026, designating the incident as a qualifying event for federal assistance. A subsequent correction notice, published on March 13 2026, clarified the exact period of the storm—December 5 through December 22, 2025—ensuring that all affected businesses and communities have accurate eligibility information.

The correction does not alter the scope of the disaster declaration; it simply amends the incident dates to match the official meteorological record. This precision is critical for businesses in the geoscience, energy, and natural resource sectors that rely on accurate timelines to assess damage, file claims, and secure funding. The SBA’s notice also reiterates the deadlines for two key loan programs: the Physical Disaster Loan (PDL) application deadline of April 27 2026 and the Economic Injury Disaster Loan (EIDL) deadline of November 24 2026.

Businesses and organizations can apply for assistance through the SBA’s MySBA Loan Portal, and the notice provides contact details for the Office of Disaster Recovery and Resilience. The correction underscores the SBA’s commitment to transparency and timely support for communities recovering from climate‑related disruptions.

Key Elements

• Corrected Incident Period – December 5–22, 2025, aligning with official storm data.
  
• Disaster Declaration – Administrative declaration #²¹⁴⁵⁰⁄₂₁₄₅₁ for Washington (Disaster Number WA‑20025).
  
• Loan Program Deadlines
  
  • Physical Disaster Loan (PDL): April 27 2026.
    
  • Economic Injury Disaster Loan (EIDL): November 24 2026.
    
• Application Portal – https://lending.sba.gov for all disaster assistance loans.
  
• Contact Information – Jennifer Talarico, Office of Disaster Recovery & Resilience, (202) 205‑6734.
  
• Authority – 13 CFR 123(b); Catalog of Federal Domestic Assistance No. 59008.
  
• Relevance to Geoscience & Natural Resources – Accurate incident dates aid in assessing storm‑induced damage to infrastructure, water resources, and energy supply chains, facilitating targeted recovery efforts.

Drone Amplified Inc. Seeks FAA Exemption for Small‑UAS Avalanche‑Mitigation Operations

Overview

The Federal Aviation Administration (FAA) has published a notice summarizing a petition filed by Drone Amplified Inc. (DAI) requesting an exemption from § 107.36 of the Federal Aviation Regulations. The petition seeks permission to operate the Freefly Alta X unmanned aircraft system (UAS)—a lightweight platform weighing less than 55 lb, including payload—for avalanche‑mitigation missions in the United States. DAI proposes to carry the MONTIS Payload, a device that drops charges to trigger controlled avalanches, thereby reducing the risk to human life and property in mountainous regions.

The FAA’s notice invites public comment on the petition until April 7, 2026. The request is part of the agency’s ongoing effort to balance safety and innovation in UAS operations, particularly for applications that can have significant environmental and public‑safety benefits. The petition is filed under docket number FAA‑2025‑2279 and is currently in the active review phase.

Key Elements

• Regulatory Target: § 107.36 of the Federal Aviation Regulations, which governs the operation of UAS for non‑commercial purposes.
• Requested Relief: Permission to use the Freefly Alta X UAS, equipped with the MONTIS Payload, for avalanche‑mitigation tasks.
• Operational Scope: Small‑UAS operations (≤ 55 lb total weight) in mountainous terrain to drop controlled charges that trigger avalanches.
• Safety Considerations: The petition must demonstrate that the proposed operations will not compromise airspace safety, comply with existing UAS safety standards, and include measures to mitigate potential hazards to people, property, and the environment.
• Public Participation: Comments are solicited from stakeholders and the general public; the comment period closes on April 7, 2026.
• Contact Information: Comments and inquiries can be submitted electronically via Regulations.gov or by mail to the FAA’s Docket Operations office in Washington, DC.
• Potential Impact: If granted, the exemption could enable more efficient avalanche control, potentially reducing the frequency and severity of natural disasters in high‑risk areas, while also advancing the use of UAS technology in geoscience and environmental management.

FERC Opens Public Review of Pipeline Relocation Near Naval Air Station Fallon

Overview

The Federal Energy Regulatory Commission (FERC) has released an Environmental Assessment (EA) for the Great Basin Gas Transmission Company’s proposed relocation of a segment of its Gabbs Lateral pipeline in Mineral and Nye Counties, Nevada. The relocation is driven by the expansion of the Naval Air Station Fallon (NASF) training range, requiring the company to move about 32.6 mi of new pipeline while abandoning roughly 21.2 mi of existing line. The project does not add any new natural‑gas capacity to the system.

The EA, prepared under the National Environmental Policy Act (NEPA), evaluates the potential impacts of construction, abandonment, and operation of the new pipeline, the removal of old segments, and related infrastructure changes such as a cathodic protection system upgrade. The Bureau of Land Management and the U.S. Navy, as cooperating agencies, contributed expertise on federal lands and naval operations, respectively, and will issue their own decisions on the project’s environmental aspects.

FERC invites public comments on the EA until 5:00 p.m. Eastern Time, April 13, 2026. The assessment concludes that the relocation would not constitute a major federal action affecting the quality of the human environment, but it remains open for public scrutiny and potential mitigation measures before a final decision on the project’s authorization is made.

Key Elements

• Project Scope:

  • Install ~32.6 mi of new 8‑inch and 6‑inch pipeline.
    
  • Abandon ~21.2 mi of existing 8‑inch and 6‑inch pipeline in place or by removal.
    
  • No incremental natural‑gas capacity added.

• Environmental Assessment Highlights:

  • NEPA-compliant analysis of construction, abandonment, and operation impacts.
    
  • Evaluation of potential effects on land, water, wildlife, cultural resources, and air quality.
    
  • Identification of reasonable alternatives and mitigation measures.

• Cooperating Agencies:

  • Bureau of Land Management (BLM) – responsible for right‑of‑way grants on federal lands.
    
  • U.S. Navy – provides expertise on NASF operations and potential impacts.

• Public Participation:

  • Comment period ends April 13, 2026; submissions can be filed electronically or by mail.
    
  • Comments should focus on environmental disclosures, alternatives, and mitigation strategies.

• Regulatory Context:

  • FERC is the lead federal agency for interstate natural‑gas transmission under the Natural Gas Act of 1938.
    
  • The project must meet public convenience and necessity criteria and not adversely affect future public needs.

• Potential Impacts:

  • Land disturbance from pipeline construction and abandonment.
    
  • Possible effects on groundwater, surface water, and local ecosystems.
    
  • Implications for cultural and historical sites in the project corridor.

• Next Steps:

  • FERC will consider public comments and the EA’s findings before issuing a final decision on the pipeline relocation authorization.

Revitalizing Brooklyn’s Fulton Park: A New Environmental Impact Study Begins

Overview

The U.S. Department of Housing and Urban Development (HUD) has announced its intent to prepare an Environmental Impact Statement (EIS) for the Fulton Park Redevelopment Project in Brooklyn, New York. The project seeks to transform two underused city‑owned sites—Fulton Park and the adjacent HPD site—into a mixed‑use neighborhood featuring new affordable and market‑rate housing, community facilities, and open space. The redevelopment will replace 209 existing Section 8 housing units with approximately 2,035 new dwellings, including 351 100‑percent affordable units and 337–505 permanently affordable units under the city’s Mandatory Inclusionary Housing program.

The notice invites public and agency input during a scoping period that begins with a virtual meeting on April 2, 2026, and ends with written comments due April 13, 2026. HUD, the New York City Department of Housing Preservation and Development (HPD), and the Department of City Planning (DCP) will use these comments to shape the scope of the forthcoming EIS, which will evaluate a range of alternatives—including a no‑action option—and assess environmental impacts such as air quality, water and sewer infrastructure, transportation, and community health. The EIS will be followed by a public comment period, a final statement, and ultimately a Record of Decision.

For residents, developers, and environmental stakeholders, this notice marks the first step in a comprehensive review that balances urban renewal with ecological stewardship, ensuring that the project meets federal, state, and local environmental standards while addressing Brooklyn’s pressing need for affordable housing.

Key Elements

• Project Scope: Redevelopment of Fulton Park (≈ 268,000 sq ft) and HPD site (≈ 38,500 sq ft) into mixed‑use, 2,035‑unit residential complex with community facilities.
  
• Housing Goals: 209 Section 8 units replaced, 351 100‑percent affordable units, 337–505 permanently affordable units under Mandatory Inclusionary Housing.
  
• Alternatives to be Evaluated:
  
  • No‑Action: Routine maintenance only.
    
  • Preferred: Full redevelopment with new housing, open space, and community amenities.
    
  • No Unmitigated Significant Adverse Impacts: Balanced approach minimizing negative environmental effects.
    
• Environmental Issues:
  
  • Land use, zoning, and public policy impacts.
    
  • Socioeconomic and community‑facility effects.
    
  • Natural resources, hazardous materials, and historic preservation.
    
  • Water and sewer infrastructure, transportation, air quality, greenhouse‑gas emissions, noise, and public health.
    
• Regulatory Framework: NEPA, HUD’s 24 CFR part 58, New York State Environmental Quality Review Act (SEQRA), and New York City Environmental Quality Review (CEQR).
  
• Public Participation: Virtual scoping meeting (April 2, 2026) and written comments until April 13, 2026. Comments will inform the Draft Scope of Work and the final EIS.
  
• Timeline: Draft EIS expected Spring 2026; public comment 45 days; Final EIS Fall 2026; Record of Decision thereafter.
  
• Key Contacts: Anthony Howard, Director of Environmental Planning, HPD (nepa_env@hpd.nyc.gov).