Some parts of the Bill will likely change as it moves through Congress. This alert identifies the Bill’s major policy proposals and what sponsors, investors, and lenders should focus on as legislative deliberations on the Bill continue in the coming weeks and months.

Key Takeaways

• Faster reviews, greater deference. Agencies would face enforceable deadlines under NEPA and other environmental statutes, and courts would owe substantial deference to agency determinations.
• Reduced litigation threats. Challenges would go directly to the courts of appeals, and only commenters alleging direct harm could sue. The time to sue would drop from six years to 150 days, with no exception for permits already issued. A NEPA violation would generally lead to remand, not vacatur.
• Grid and data center reforms. The Bill would ease interstate transmission siting and require data centers to bear their transmission costs.
• Durable approvals. Limits on rescinding issued permits would protect previously approved renewable projects and oil and gas approvals alike.

Litigation Reforms

In order to bring suit alleging a NEPA violation, a challenger would need to have submitted a detailed comment during the agency’s comment period that alleges direct harm. The lawsuit itself would go straight to a federal court of appeals, bypassing review by federal district courts. In reviewing the merits of the claims, courts would owe agencies substantial deference, codifying the Supreme Court’s 2025 decision in Seven County Infrastructure Coalition v. Eagle County.

To the extent there was a deficiency with the NEPA analysis, a court could only send a flawed permit back to the agency to fix. It could not vacate the permit or halt the project, and the permit would stay in effect while the agency corrects the problem. These proposed changes are intended to address the substantial regulatory and litigation uncertainties many project developers currently face when permits issued by federal agencies are successfully challenged in court, leading to substantial delays and cost overruns.

The Bill also proposes limits to legal challenges to NHPA actions, ESA biological opinions, and CWA Section 404 permits. Moreover, the 150-day period for bringing a legal challenge would also extend to challenges under any federal law to energy and mining authorizations.

In our view, the Bill would reduce litigation risks without eliminating them. Courts could still halt a project for violations of substantive statutes such as the Clean Air Act or the CWA, so opponents may try to shift the focus of their challenges toward those statutes if the Bill were to be signed into law.

Faster Reviews and Greater Deference

Fewer projects would trigger NEPA at all. Three categories would expressly fall outside its reach:

• federal loans and grants over which the agency does not exercise predominant control;
• work within existing rights-of-way, including reconductoring of transmission lines and the repair, upgrade, looping, compression, and capacity enhancement of existing interstate pipelines; and
• repair and replacement of critical infrastructure.

NEPA review deadlines already on the books would now be enforceable with greater force. The Bill would narrow the grounds for delay and require the agency to prove them by clear and convincing evidence.

Sponsors would gain several enforcement tools:

• Court petitions. A sponsor could petition a court over a missed deadline, and the court would have to act quickly.
• Binding dispute resolution. A sponsor could refer an interagency dispute to the Council on Environmental Quality (CEQ), whose decision would be final and unreviewable.
• Deadlines outside NEPA. Permits that need no NEPA review would have to be decided within one year of a complete application.

The Bill makes further procedural changes:

• NHPA consultation would have to conclude when the NEPA document does.
• Formal ESA consultation would move faster, and states could assume responsibility for it.
• Sponsors would file a stakeholder engagement report with their applications.

Agencies would also gain more control over the scientific record. They would not need to consider research published after review begins, and courts would defer substantially to their technical determinations.

Agencies would have 180 days to conform their procedures. Whether they can meet the new deadlines will turn on staffing, and sponsors should plan for a bumpy transition.

Clean Water Act

State review under Section 401 would be limited to water quality. For pipelines and transmission lines, review would be further limited to the direct effects of the point source discharge, and states would have less time to decide. A state could deny certification only on clear and convincing evidence that no modification would allow the project to meet water quality standards. The state would also bear the burden of showing that any conditions are the least burdensome available. A missed deadline would waive certification.

Under Section 404, Nationwide Permits and NPDES permits would last twice as long, and the Environmental Protection Agency could no longer veto a Section 404 permit after it issues.

Permit Certainty

Once a project is fully permitted, the government could disturb those valid permits only on narrow grounds, such as a court order, a material violation, fraud, or an urgent threat to safety or national security.

The government would bear the burden of proof by clear and convincing evidence. A permittee who prevails could recover fees and a substantial share of the costs it has incurred. A separate cause of action could target a pattern of disparate treatment against a category of projects, such as wind farms or gas pipelines.

These protections cut both ways. They would constrain the Trump administration’s holds on wind and solar approvals, and they would equally constrain a future administration seeking to unwind oil and gas approvals.

Transmission Siting and Data Center Ratepayer Protections

The Bill would expand the Federal Energy Regulatory Commission’s (FERC) backstop siting authority, which has seen little use since 2005, by removing the requirement that a line sit within a federally-designated corridor. Neighboring planning regions would have to plan interregional lines jointly, and costs would be allocated to the customers who benefit. ERCOT would be exempt from these siting and planning provisions.

Incumbent utilities should watch two provisions closely:

• Local transmission referrals. A state could refer a utility’s local transmission spending to FERC, which could respond with fines, loss of the presumption of prudence, or a reduced return on equity.
• Rights of first refusal. The Bill would bar federal rights of first refusal for regionally selected projects, while leaving state laws in place.

FERC would revise its transmission pricing policy so that data centers pay both the embedded and incremental cost of transmission service. States could set separate data center rates. The House-passed Ratepayer Protection Act takes a different approach. It would require state regulators to consider whether data centers of 100 megawatts or more should pay the full cost of generation, transmission, and distribution upgrades that serve them. Developers negotiating large load service agreements should test cost responsibility terms against both approaches. A separate provision would require RTOs and ISOs to let behind-the-meter resources participate in wholesale markets.

Outlook

The Bill needs 60 votes in the Senate, then passage in the House, in a short lame duck session. The last bipartisan permitting deal, in 2024, stalled after that year’s election. This one carries the support of both parties’ leaders on both committees of jurisdiction. House Natural Resources Committee Chairman Bruce Westerman (R-AR) called the agreement an encouraging step and credited the Trump administration’s involvement, a favorable early signal from the House. Other signals are less favorable. Representative Jared Huffman (D-CA), the House Natural Resources Committee’s ranking Democrat, has urged his colleagues to wait for a stronger negotiating position after the election. The election results will shape the odds, and the text will likely change significantly along the way. Whatever happens in the lame duck session, we expect the Bill’s core proposals to anchor future permitting negotiations.

What to Do Now

• Inventory your permits. Identify permits issued in recent years and pending applications, and assess how the shorter limitations period and narrower remedies would change each one’s risk.
• Build the record. Only commenters could sue, so expect opponents to file detailed comments. To help provide adequate evidence in the record to overcome any of these opposing efforts, project developers should be prepared to document stakeholder engagement and answer comments fully.
• Plan the review path. Consider whether to use the new deadline petitions and CEQ referrals, and weigh the effect on agency relationships.
• Revisit deal terms. Buyers and lenders should consider tying closing conditions, financing milestones, and permit representations to the limitations period, while pricing the injunction risk that remains under substantive statutes.
• Keep compliance programs current. Faster permits mean conditions take effect sooner, and the Bill leaves enforcement of permit terms untouched.
• Weigh in. The sponsors have invited comment before a manager’s amendment. Companies with a stake in particular provisions should decide soon whether to engage.

King & Spalding’s Environmental, Health and Safety, Energy, and administrative and appellate teams advise clients on federal permitting and enforcement, onshore and offshore leasing and drilling permits, permit litigation, transactions, and FERC transmission and large load matters. We would be glad to walk through how the Bill would affect a specific project, portfolio, or transaction.