Report Highlights

U.S. Oil and Gas Storage's Role in the Global Supply Chain

The United States occupies a pivotal position in the global oil and gas storage supply chain, functioning simultaneously as the world's largest crude oil producer, a major LNG exporter, and a critical buffer between upstream production and downstream refining and export markets. The U.S. Strategic Petroleum Reserve (SPR), with a capacity of approximately 714 million barrels, represents the world's largest government-owned emergency crude reserve and directly influences global oil price stability during supply disruptions. Commercial storage infrastructure — spanning over 500 million barrels of working crude storage capacity — connects Permian Basin, Eagle Ford, and Bakken production to refinery complexes in Houston, Port Arthur, and Los Angeles.

On the natural gas side, the U.S. holds over 4.2 trillion cubic feet of working gas storage capacity across more than 400 active underground storage facilities, predominantly depleted reservoirs and salt caverns. The U.S. exported over 11.9 billion cubic feet per day of LNG in 2023, making Sabine Pass, Freeport, and Corpus Christi export terminals critical nodes in European and Asian energy security chains. Key trade partners receiving U.S. LNG include South Korea, Japan, France, the Netherlands, and the United Kingdom. U.S. storage infrastructure thus acts as the physical backbone enabling the country to arbitrage global price differentials and fulfill long-term supply contracts across Atlantic and Pacific Basin markets.

Growth Drivers for U.S. Oil and Gas Storage Trade and Production

Three structural forces are driving expansion of U.S. oil and gas storage capacity. First, sustained growth in Permian Basin production — which surpassed 5.7 million barrels per day in 2023 — requires continuous investment in midstream storage to buffer pipeline throughput and manage export scheduling at Gulf Coast marine terminals. Operators including Magellan Midstream and Enterprise Products Partners are expanding tank farm capacity at terminals in Texas City and Beaumont to handle rising export volumes destined for Europe and Asia, where demand for U.S. crude remains robust following post-2022 energy security realignments.

Second, accelerating LNG export capacity additions are driving co-located storage infrastructure investment. The addition of Venture Global's Plaquemines LNG facility and the expansion of Cheniere Energy's Sabine Pass and Corpus Christi terminals require dedicated LNG storage tanks and associated regasification buffer capacity. Third, U.S. policy to rebuild and modernize the SPR following its 2022-2023 drawdown of over 180 million barrels is generating direct government procurement demand for storage services and engineering contracts, benefiting firms such as Worley, Jacobs Engineering, and CB&I Storage Solutions. These three drivers collectively ensure storage capacity investment remains a priority through the forecast period.

Supply Chain Risks and Trade Barriers

The most significant supply chain risk facing U.S. oil and gas storage operators is infrastructure concentration. The Cushing, Oklahoma crude hub — which serves as the physical delivery point for NYMEX WTI futures — holds approximately 76 million barrels of storage capacity but is served by a constrained pipeline network that limits throughput flexibility during demand surges or production disruptions. A repeat of the April 2020 near-capacity event, when WTI prices briefly turned negative, would expose operators to significant contract liabilities and force costly spot storage arrangements. Additionally, aging tank farm infrastructure along the Gulf Coast, much of it built in the 1960s and 1970s, requires accelerating capital expenditure for integrity maintenance, increasing operating costs for midstream players with large legacy asset bases.

Trade barriers and regulatory risks add further complexity. The Jones Act restricts marine transport of petroleum products between U.S. ports to U.S.-flagged vessels, increasing domestic waterborne logistics costs and reducing flexibility in moving stored products between coastal terminals. Environmental permitting for new above-ground storage tank installations has lengthened project timelines by an average of 18 to 24 months in states including California and Washington. Currency risk is limited but present for operators with export contracts denominated in alternative currencies, while tariff exposure on imported storage construction materials — particularly steel plate for tank fabrication — has increased project costs by an estimated 8 to 12 percent since 2018 Section 232 tariffs took effect.

Trade and Investment Opportunities in U.S. Oil and Gas Storage

The most compelling near-term investment opportunity lies in Gulf Coast marine terminal expansion to capture growing crude and LNG export volumes. With U.S. crude exports regularly exceeding 4 million barrels per day and European buyers actively seeking long-term supply agreements, operators that can offer integrated storage, blending, and loading capabilities at deepwater terminals — such as the proposed Sea Port Oil Terminal off Freeport, Texas — will command premium tolling rates. Private equity firms including Stonepeak Infrastructure Partners and Brookfield Asset Management have already identified this segment as a high-return infrastructure play with long-duration contracted cash flows backed by investment-grade counterparties.

A second major opportunity is import substitution through domestic underground storage development. Salt cavern storage, which can cycle gas or liquids far faster than depleted reservoir facilities, remains underdeveloped relative to the U.S. salt dome resource base along the Gulf Coast. Expansion of cavern storage in Texas and Louisiana can substitute for expensive above-ground tank infrastructure while providing superior operational flexibility. Inbound foreign direct investment from European energy majors — including TotalEnergies and Shell — seeking to secure U.S. storage access for their trading desks presents a viable monetization path for developers willing to build-and-lease cavern assets under long-term capacity reservation agreements structured to meet FERC regulatory requirements.

Market at a Glance

Leading Market Participants

• Enterprise Products Partners
• Magellan Midstream Partners
• Kinder Morgan
• Enbridge
• NuStar Energy
• Cheniere Energy
• Plains All American Pipeline
• Sunoco Logistics Partners
• Targa Resources
• Buckeye Partners

Regulatory and Trade Policy Environment

U.S. oil and gas storage operations are subject to a layered regulatory framework administered by federal and state authorities. The Federal Energy Regulatory Commission (FERC) oversees interstate natural gas storage facilities, setting rates and access terms under the Natural Gas Act. The Pipeline and Hazardous Materials Safety Administration (PHMSA) enforces integrity management standards for both underground storage and aboveground tank farms under 49 CFR Part 195. The Environmental Protection Agency's Spill Prevention, Control, and Countermeasure (SPCC) rule mandates secondary containment and inspection protocols for facilities storing over 1,320 gallons of petroleum products. The U.S. participates in the International Energy Agency's coordinated stockholding commitments, which obligate maintenance of emergency reserves equivalent to 90 days of net petroleum imports.

On the trade policy side, the Jones Act (Merchant Marine Act of 1920) remains a structural constraint on domestic waterborne petroleum logistics but also provides a competitive moat for U.S.-flagged vessel operators. Section 232 steel tariffs continue to inflate construction costs for new tank farm projects. The Inflation Reduction Act of 2022 introduced tax incentives relevant to hydrogen and carbon capture storage — adjacent markets that are beginning to share infrastructure with conventional oil and gas storage, particularly in Texas and Wyoming. The current administration's posture of expanding domestic energy production without reversing LNG export licensing is broadly positive for storage infrastructure investment through 2032.

U.S. Oil and Gas Storage Supply Chain Outlook to 2032

Through 2032, the U.S. oil and gas storage supply chain will shift structurally toward export-oriented coastal infrastructure at the expense of inland hub dominance. Cushing's relative importance as a pricing and storage node will decline as pipeline connectivity between the Permian Basin and Gulf Coast marine terminals continues to improve, enabling producers to move crude directly to export without inland storage intermediation. Salt cavern development along the Gulf Coast will accelerate, driven by demand for fast-cycle storage to support LNG export scheduling and power grid balancing as renewable penetration increases. Companies capable of offering multi-product storage — crude, refined products, LNG, and eventually hydrogen — at integrated coastal terminals will capture disproportionate market share.

Technology will materially alter competitive advantage in this market by 2032. Advanced tank monitoring systems incorporating IoT sensors, drone-based inspection platforms, and AI-driven inventory optimization are being piloted by Kinder Morgan and Enbridge to reduce operating costs and extend asset life. Digitization of custody transfer and scheduling — replacing legacy SCADA systems — will compress operational inefficiencies that currently cost midstream operators an estimated USD 200 million annually across the U.S. network. Operators that invest in digital infrastructure alongside physical capacity will secure long-term cost advantages and attract investment-grade shipper commitments, further consolidating market structure around a smaller set of technologically capable, large-scale midstream platforms.