Bernstein reiterates its long-term bullish view on U.S. natural gas, arguing that the rebound in Haynesville activity is insufficient to change its tight supply-demand outlook

Overview

This report updates Bernstein's U.S. natural gas model and incorporates its newly introduced U.S. power model into the forecast for gas-fired power demand. The core conclusion is that by 2030 the U.S. natural gas market will face significant demand growth driven by LNG exports, power demand, and supply chain consumption, while supply expansion from major producing regions will be constrained by rig discipline, pipeline bottlenecks, and declining well quality in the Haynesville, making it difficult to comfortably meet demand.

Core views

The report's core views include: first, long-term U.S. natural gas demand growth remains strong, and even without assuming growth in industrial, commercial, and residential demand, LNG exports, gas-fired power demand, and supply chain consumption alone could drive roughly 24% demand growth by 2030; second, $5/mcf is a more reasonable mid-cycle Henry Hub price because a higher price is needed to incentivize upstream producers to supply the required gas; third, the rebound in Haynesville rigs does not change the bullish view because rig counts are still insufficient to restore historical high-productivity levels, and more of the incremental rigs are coming from lower-quality operators; fourth, Henry Hub-related equities EQT, EXE, and DVN still have meaningful upside.

Analysis framework

The report uses a top-down U.S. natural gas supply-demand balance framework, forecasting demand components including LNG exports, gas for power generation, residential and commercial demand, industrial demand, pipeline exports to Mexico, and loss items, while breaking down supply into Permian associated gas, Appalachia, Haynesville, Bakken, Eagle Ford, Rockies, Midcon, and other basins. It then combines pipeline takeaway capacity, rig counts, per-well quality, and inventory-implied pricing to assess market balance.

Methodology notes

• Supply-demand balanceU.S. natural gas supply-demand model

  Forecast demand components and basin-level supply components through 2030

  The model places total demand, marketed production, net imports from Canada, inventory, and Henry Hub implied pricing within one framework to assess future supply-demand gaps and price pressure.

• Power modelBernstein U.S. power model

  Map electricity demand growth and fuel mix into gas-fired power demand

  The report expects U.S. total power demand to grow at a 2025-2030 CAGR of 2.6%, and uses this to derive continued growth in gas-fired power demand through 2030.

• Basin quality analysisComparison of per-well quality among Haynesville operators

  Rig count growth does not equal high-quality production growth

  The report compares the sources of new Haynesville rigs with historical cumulative per-well gas production performance and concludes that more of the new activity is coming from operators with lower historical productivity.

• Infrastructure constraintsPipeline takeaway capacity and basin constraints

  Whether basin supply can materialize depends on pipeline capacity and upstream investment willingness

  Production forecasts for the Permian, Appalachia, and Haynesville all incorporate takeaway capacity, expansion projects, and historical constraints.

Asset mapping & comparison

Structured mapping from thesis to named assets (strengths, weaknesses, peers, risks).

• Henry Hub natural gas

  Core price benchmark

  Strengths

  Supported by LNG export growth, rising gas-fired power demand, and supply constraints.

  Weaknesses

  In the short term it may still be affected by inventories, weather, coal-to-gas switching, and basin production volatility.

  Comparison

  The report argues that Haynesville's previous marginal pricing power of about $3.50/mcf is no longer sufficient, and that $5/mcf is more appropriate as a mid-cycle price.

  Risks

  If supply grows faster than expected, LNG projects are delayed, or power demand falls short of expectations, price upside may be limited.

• EQT

  Henry Hub-related equity

  Strengths

  Offers high leverage when natural gas prices rise, and the report continues to see meaningful upside.

  Weaknesses

  Affected by Appalachia pipeline constraints and regional basis differentials.

  Comparison

  Compared with more integrated oil and gas or oil-weighted equities, it is more sensitive to natural gas prices.

  Risks

  Constrained regional takeaway, falling gas prices, or operating performance below expectations.

• EXE

  Henry Hub-related equity with Haynesville exposure

  Strengths

  If natural gas prices remain elevated, its assets offer upside to improving gas prices.

  Weaknesses

  The report notes divergence in the quality of new Haynesville activity, meaning basin production growth is not risk-free.

  Comparison

  Compared with oil-weighted companies, EXE is more directly affected by the U.S. natural gas supply-demand balance.

  Risks

  Haynesville production delivery, well quality, and capital efficiency may affect share performance.

• DVN

  Henry Hub-related upstream equity

  Strengths

  The report lists it as one of the Henry Hub-related equities that continues to offer meaningful upside.

  Weaknesses

  Natural gas is not the sole driver, and its mixed oil-gas exposure may dilute pure natural gas upside.

  Comparison

  Compared with pure natural gas names, DVN may benefit from both oil and gas price drivers.

  Risks

  Oil prices, gas prices, capital discipline, and basin performance can all affect investment outcomes.

• LNG export chain

  Source of incremental natural gas demand

  Strengths

  Expansion of U.S. LNG capacity is expected to drive LNG offtake to about 32.4 bcfd by 2030.

  Weaknesses

  Depends on global demand absorbing the additional liquefaction capacity.

  Comparison

  Compared with residential and commercial demand, LNG exports are a clearer structural source of incremental demand.

  Risks

  Project delays, global LNG oversupply, insufficient demand in Europe and Asia, or weaker price linkage.

• Permian associated gas

  Important source of supply

  Strengths

  The report raises its future Permian production forecast and incorporates takeaway capacity additions such as Eiger, Saguaro, Apex, and the Transwestern Desert expansion.

  Weaknesses

  Associated gas depends on oil drilling activity; if Permian oil growth is limited, gas volume expansion will also be constrained.

  Comparison

  The Permian is the largest source of natural gas growth tied to shale oil drilling.

  Risks

  Oil prices, pipeline utilization, in-basin price blowouts, and producer takeaway contract decisions may all affect supply.

Key data

• Total U.S. natural gas demand in 2030154.0 bcfdAbove 124.4 bcfd in 2025; the report says this represents about 24% growth.
• Total supply in 2030151.3 bcfdThe report's supply-demand table shows total supply in 2030 below total demand.
• LNG exports15.1 bcfd in 2025, 32.4 bcfd in 2030LNG export expansion is a key pillar of the bullish natural gas view.
• Gas-fired power demand35.7 bcfd in 2025, 41.6 bcfd in 2030The report expects gas-fired power demand to continue growing through 2030.
• Growth in total U.S. power demand2025-2030 CAGR 2.6%From Bernstein's new U.S. power model.
• Mid-cycle Henry Hub price assumption$5/mcfThe report reiterates that this price level is the appropriate mid-cycle price needed to incentivize upstream supply.
• Change in Permian and Appalachia rig countsDown 25% and 21%, respectively, since the beginning of 2024Used to support the view that supply discipline remains in place.
• Haynesville rig countAbout 53 rigs in March 2026The report argues that around 60 rigs would be needed for the basin to return to its previous 16.7 bcfd level.
• Haynesville production lagAbout 8 monthsThe report believes the best correlation lag between changes in rig activity and production response is about 8 months.

Impact & implications

The investment implication is that medium- to long-term upward pressure on U.S. natural gas prices remains in place, particularly benefiting upstream gas equities with higher Henry Hub sensitivity. The report emphasizes that EQT, EXE, and DVN still have meaningful upside; at the same time, LNG export expansion and power demand growth will strengthen the linkage between U.S. gas prices and global LNG as well as European TTF prices.

Risks

• U.S. LNG export project start-ups or offtake may come in below expectations, weakening natural gas demand growth.
• U.S. power demand, especially data center-related demand growth, may fall short of expectations.
• Coal-to-gas switching, weather, and inventory changes may pressure gas prices in the short term.
• Supply growth in the Permian, Appalachia, or Haynesville may exceed the report's assumptions.
• The production quality of new Haynesville rigs may be better than expected, narrowing the supply gap.
• Global LNG market absorption may prove insufficient, weakening the linkage between U.S. LNG exports and TTF.
• Pipeline expansions, debottlenecking, or production efficiency improvements may exceed expectations and ease regional supply constraints.

What to watch

• Whether actual U.S. LNG project start-up progress and LNG offtake approach full utilization.
• The pace of U.S. power demand growth, especially the pull on gas-fired generation from data center construction.
• Whether Henry Hub prices approach or exceed the $5/mcf mid-cycle framework.
• Changes in rig counts in the Permian, Appalachia, and Haynesville.
• Per-well production performance of the operators behind new Haynesville rigs.
• The implementation pace of Permian takeaway pipeline projects such as Saguaro, Eiger, Apex, and the Transwestern Desert expansion.
• The degree of deviation of U.S. natural gas inventories relative to the five-year average.
• How Henry Hub-related equities such as EQT, EXE, and DVN perform relative to changes in gas prices.