US Energy Policy: The IRA, Permitting Reform, and LNG Export Expansion

Introduction

US energy policy is one of the most dynamic and consequential variables affecting energy investment banking deal flow in 2025-2026. Three interconnected policy areas, the Inflation Reduction Act and its subsequent modifications, federal permitting reform for energy infrastructure, and LNG export authorization, are collectively reshaping which energy investments get financed, which projects get built, and where banking advisory mandates are generated. Energy bankers advising on renewable energy, LNG infrastructure, power generation, and midstream transactions must understand the current policy landscape and its investment implications.

The Inflation Reduction Act of 2022 created approximately $369 billion in energy and climate incentives, representing the largest clean energy investment in US history. The core mechanisms are tax credits: the Investment Tax Credit (ITC) provides a 30% credit for qualifying energy property, while the Production Tax Credit (PTC) provides approximately $0.028 per kWh of electricity produced. Additional bonus credits for domestic content (increasing the ITC by one-third) and energy communities incentivize US-based manufacturing and investment in regions affected by fossil fuel transitions.

Starting January 1, 2025, the IRA transitioned from technology-specific credits (separate ITC and PTC for solar, wind, etc.) to technology-neutral clean electricity credits. The Clean Electricity Production Tax Credit (CEPTC) and Clean Electricity Investment Tax Credit (CEITC) apply to any generation technology with zero or negative greenhouse gas emissions, expanding eligibility to advanced nuclear, geothermal, and other emerging technologies alongside solar and wind.

The tax equity market, which is the primary mechanism for monetizing IRA credits, has adapted to the new policy framework. The IRA's transferability provision (allowing developers to sell tax credits directly rather than structuring complex partnership flips) expanded the universe of tax credit buyers and improved price discovery, with credits trading at approximately $0.92-0.95 per dollar of face value. This has been particularly beneficial for smaller developers who previously lacked access to the limited pool of traditional tax equity investors (primarily large banks and insurance companies).

For the oil and gas sector, the IRA's $85 per ton 45Q tax credit for geologic carbon sequestration created significant investment opportunities in carbon capture (CCUS) projects. The 45V hydrogen production tax credit of up to $3 per kilogram incentivized hydrogen development. Both credits remain intact under the OBBBA, making CCUS and hydrogen among the most policy-supported energy investment categories.

Federal permitting has historically been the primary bottleneck for energy infrastructure development in the US. Pipeline projects, LNG terminals, transmission lines, and power plants routinely face 3-5 year permitting timelines under the National Environmental Policy Act (NEPA) review process, with some projects delayed by litigation for a decade or more. The current policy environment is focused on dramatically accelerating these timelines.

On June 30, 2025, both the Department of Energy (DOE) and FERC announced revisions to their NEPA procedures, removing references to recently rescinded White House Council on Environmental Quality (CEQ) regulations. FERC took additional action on June 18, 2025, temporarily waiving rules that limited initial construction activities for natural gas infrastructure projects and proposing permanent changes to expedite pipeline and LNG facility construction.

FERC (Federal Energy Regulatory Commission)

The independent federal agency that regulates the interstate transmission of natural gas, oil, and electricity, and oversees the construction and operation of LNG import/export terminals, interstate natural gas pipelines, and hydroelectric projects. FERC's role in energy infrastructure permitting makes it one of the most consequential federal agencies for energy investment banking. FERC Chairman Laura Swett, who took office in October 2025, has prioritized streamlining the approval process for energy infrastructure, including considering blanket authorizations for certain LNG and pipeline activities.

FERC is also considering blanket authorizations for certain LNG facility modifications and operational changes, a departure from the traditional case-by-case review that required separate authorization orders for each modification. If adopted, this framework would significantly reduce the time and cost of expanding existing LNG facilities, benefiting operators like Cheniere Energy, Venture Global, and Sempra that have multiple trains under development.

For energy bankers, permitting reform has direct implications for deal flow. Faster permitting means shorter development timelines, which improves project economics and makes energy infrastructure more financeable. Midstream project finance mandates, LNG advisory work, and transmission infrastructure transactions all benefit from a more predictable and expedited permitting environment.

LNG export expansion has become a central pillar of the current administration's energy policy. In January 2025, the administration reversed the Biden-era pause on new LNG export authorizations to non-Free Trade Agreement (non-FTA) countries, and the DOE has since processed multiple pending applications. The most significant authorization was a final order in October 2025 granting Venture Global permission to export up to 1,446 billion cubic feet per year of domestically produced LNG from its Louisiana facilities to non-FTA countries.

Legislative proposals have sought to further liberalize LNG exports. The Unlocking Our Domestic LNG Potential Act (H.R. 1949) proposes to repeal all restrictions on natural gas imports and exports and grant FERC exclusive authority over LNG facility siting and construction, removing the DOE's role in determining whether exports serve the "public interest." While the bill's passage is uncertain, its introduction signals the direction of policy.

The investment implications are significant and far-reaching. The US currently has approximately 14-15 Bcf/d of LNG export capacity, with another 10-12 Bcf/d under construction or in advanced development. Policy certainty around export authorizations supports final investment decisions (FIDs) for new projects and underpins the long-term demand growth thesis for Henry Hub natural gas. Each new LNG train that reaches FID creates a cascade of financing activity: project-level debt (typically $5-15 billion per facility), equity capital raises, upstream gas supply agreements, midstream pipeline capacity commitments, and engineering and construction contracts.

The geopolitical dimension reinforces the policy push. European and Asian buyers, who accelerated their diversification away from Russian pipeline gas after 2022, view US LNG as a critical component of energy security. Long-term sale and purchase agreements (SPAs) between US exporters and European and Asian utilities provide the contracted revenue base that supports project finance, making US LNG investment a convergence of commercial returns and geopolitical alignment. For energy bankers, LNG export policy drives advisory mandates across the entire value chain: upstream gas supply contracts, midstream pipeline and processing expansions, liquefaction project finance, and LNG offtake agreement negotiations with international buyers.