The U.S. Energy Information Administration expects domestic dry gas production to reach record highs in both 2026 and 2027, with operators ramping output to fill the supply gap left by restrictions on energy trade through the Strait of Hormuz. The forecast lands alongside a separate, state-level event: a North Carolina judge has ruled that a Duke Energy gas-fired power plant proposed for the state should not proceed.

The EIA outlook frames 2026 and 2027 as twin record-setting years on both sides of the domestic natural gas balance. Supply and demand are each projected to reach all-time peaks this year and next, a configuration the agency ties directly to the export channel. Operators are ramping production in pursuit of LNG market share, while the same export buildout pulls incremental feedgas demand.

What is the Hormuz dimension?

The Strait of Hormuz reference in the EIA outlook signals a geopolitical tailwind for U.S. producers. Disruption to Qatari and UAE LNG flows would tighten global balances and elevate the marginal value of U.S. cargoes, particularly for European and Asian buyers seeking diversification away from Gulf supply. For U.S. dry gas producers, that translates into firmer netback pricing and a clearer case for incremental drilling through 2027.

The Hormuz risk premium is one factor behind the agency's confidence in sustained production growth even as rig counts in some basins moderate. Producers retain the optionality to flex output upward if export pull strengthens, and the EIA appears to be pricing that optionality into its record-high forecast.

What did the North Carolina court decide?

The ruling against the Duke Energy gas plant is a state-level event that does not directly affect the EIA's national supply or demand outlook. It does illustrate the friction between gas-fired generation buildout and state-level opposition at a time when utilities are turning to natural gas to replace coal retirements and meet rising electricity demand.

Duke Energy is the regulated electric utility serving much of North Carolina and South Carolina. The blocked plant is part of a broader capacity expansion strategy that the company has been pursuing to serve growing load in the Carolinas. Whether Duke will appeal, refile with modifications, or withdraw the application is the immediate operational question.

Where does the gas go?

EIA's twin records on supply and demand imply that incremental production has a market rather than landing in storage. The agency has not broken out how much of the demand lift comes from LNG feedgas versus domestic power and industrial use, but the supply-demand balance suggests the U.S. is unlikely to build a storage surplus through the forecast window. That has implications for Henry Hub pricing, which has remained compressed through much of the past two years despite elevated LNG export volumes.

Watch items

• EIA's next Short-Term Energy Outlook for revised production and consumption figures.
• Duke Energy's response to the North Carolina ruling — appeal, refile, or withdrawal.
• LNG feedgas nominations through the Gulf Coast terminal complex across the summer cooling season.
• OPEC+ decisions that could shift gas-to-coal switching dynamics in competing markets ahead of next winter's heating season.
• State-level permitting and court challenges to other proposed gas-fired units across the Southeast.