Bernstein: New pipelines can't drive Permian gas prices down
AI summary card
Bernstein: New pipelines can't drive Permian gas prices down
The report argues that growth in associated gas production from the Permian Basin isn't sufficient to fill new pipeline capacity, invalidating bearish 'oversupply' narratives, and maintaining a positive outlook for pure-play gas stocks and Permian producers.
- Long-term bullish view on Henry Hub pricing driven by strong LNG export and power sector demand, alongside supply discipline in Haynesville
- Predicting Permian dry gas output growth won't be able to fill 2026's new pipeline capacity
- After Gulf Coast Express went online, Waha spread narrowed rapidly to -$0.5/mcf without a surge in supply
- Blackcomb and Hugh Brinson pipelines are set to come online between late 2026 and early 2027
- Historical data shows new pipeline openings haven’t triggered sudden releases of 'trapped' gas
- EXE and EQT are biggest beneficiaries of higher gas prices; DVN benefits most among large E&Ps
Report interpretation
Overview
This report addresses market concerns about new pipeline capacity in the Permian Basin leading to natural gas oversupply. Using pipeline commissioning schedules, regional price differentials, and historical yield responses, it argues the premise doesn't hold currently. Bernstein maintains its long-term bullish stance on North American natural gas, attributing dominance to demand-side support and disciplined supply, while identifying specific holdings benefiting from higher gas prices and Permian-specific price recovery within its coverage universe.
Core views
Bernstein holds a long-term bullish view on Henry Hub natural gas prices, supported by robust LNG exports and power sector demand, combined with supply discipline in the benchmark Haynesville region. To address fears of a 'glut' from new Permian pipelines (Gulf Coast Express, Blackcomb, Hugh Brinson), the report notes these projects increase capacity but Permian dry gas is expected to grow at just ~2 bcfd annually—a pace insufficient to fully utilize new transport by 2030. This means pipeline openings alone won't cause explosive supply increases. Real-world data shows Gulf Coast Express, operational since mid-June 2026, quickly reduced the Waha-Hub spread to -$0.5/mcf (down from an average -1.68/mcf pre-commissioning). Despite improved pricing, throughput has seen minimal change—medians around 22.7 bcfd vs previous 22.54 bcfd—no significant jump suggesting excess supply. Meanwhile, Blackcomb (~2.5 bcfd) is under testing and slated for full operation by year-end; Hugh Brinson I (1.5 bcfd) starts Sept 1, with Phase II (0.7 bcfd) scheduled Q1 2027. These alleviate bottlenecks but don't alter tight supply-demand balance overall. In terms of stock selection, Expand Energy (EXE) and EQT are positioned as top beneficiaries due to their status as pure-play gas companies. Among larger integrated E&Ps, Devon Energy (DVN) stands out given its higher gas exposure, followed by other Permian-focused producers gaining from narrowing Waha spreads and better realized prices. Names like APA, Chevron, ConocoPhillips, Diamondback, EOG, ExxonMobil, and Kosmos remain covered, with valuations closely tied to gas price movements.
Analysis framework
The report employs an 'infrastructure event-driven + high-frequency volume-price validation' framework. It first identifies planned 2026 Permian takeaway pipelines with genuine incremental capacity, then uses the Waha-Henry Hub spread as a real-time gauge of local supply-demand conditions post-activation. Finally, it calculates 'gas velocity' and reviews past pipeline expansions to test whether opening new lines automatically triggers releases of stranded gas. This three-part verification strengthens the conclusion’s reliability.
Methodology notes
Midstream pipeline capacity and upstream producer price differentials
In natural gas markets, when field takeaway infrastructure operates at full load, local wellhead prices (e.g., Waha) significantly discount or trade negative versus benchmarks (Henry Hub). Opening new capacity alleviates such constraints, causing the differential to converge. Monitoring this price movement helps determine if actual supply fills newly available pipe, beyond stated capacity figures.
Associate gas production filling rate relative to pipeline capacity
Gas in the Permian is largely a co-product of oil drilling, making output dependent on crude activity rather than gas prices themselves. The report therefore reasons that even with expanded pipeline access, gas volumes can't accelerate unless crude drilling picks up speed, rejecting the linear assumption that more pipe = suddenly more supply.
Asset mapping & comparison
Structured mapping from thesis to named assets (strengths, weaknesses, peers, risks).
- Expand Energy (EXE)Pure natural gas producer, direct beneficiary of high gas prices
- Strengths
- High gas exposure, profits highly sensitive to Henry Hub moves
- Comparison
- Top beneficiary alongside EQT
- Risks
- Lower-than-expected gas prices
- EQT Corporation (EQT)Pure natural gas producer, direct beneficiary of high gas prices
- Strengths
- One of North America's largest gas producers, notable cost advantages
- Comparison
- Co-top pick with EXE, EV/EBITDA valuation approach
- Risks
- Lower-than-expected gas prices
- Devon Energy (DVN)Large E&P with substantial gas exposure, benefits from both gas prices and Permian price recovery
- Strengths
- Quality assets in the Permian, room to improve gas realizations
- Comparison
- Most positively impacted large E&P by gas trends
- Risks
- Oil price volatility affecting overall earnings
- Diamondback Energy (FANG)Permian-focused producer, gains from narrowing Waha spread
- Strengths
- Efficient operations in the basin
- Comparison
- Other Permian players where price improvement offers marginal upside
- APA Corp (APA)Covered Permian producer
- Comparison
- Market Perform rating, neutral relative return expectations
Key data
- Waha-Henry Hub Spread (Current)-$0.5/mcfWidespread after Gulf Coast Express came online; averaged -$1.68/mcf previously (Sep 2025-Jun 2026)
- Permian Dry Gas Long-Term Growth Forecast+2 bcfd/yearProjected annual average through 2030, insufficient to fill new capacity
- Gulf Coast Express Capacity0.57 bcfdCommissioned June 2026, not yet operating at full tilt
- Blackcomb Pipeline Capacity2.5 bcfdPartially open, targeted for full operation by Dec 2026
- Hugh Brinson Phase I Capacity1.5 bcfdExpected live by Sept 1, 2026
- Hugh Brinson Phase II Capacity0.7 bcfdPlanned for Q1 2027
- Median Pipeline Flow Since Mid-June22.7 bcfdSlight rise from prior 22.54 bcfd, no indication of surge
Impact & implications
If the assessment of moderate Permian supply growth proves correct, bearish expectations for natural gas prices will be invalidated, allowing Henry Hub levels to stay elevated under LNG and power demand pressures. For investors, this implies continued profit elasticity for pure gas plays (like EXE, EQT), while mixed Permian operators benefit from higher commodity realization via narrowed Waha discounts. Conversely, if end-of-year observations show rapid pipeline flow increases or worsening Waha spreads, the bullish thesis would need reassessment.
Risks
- Unexpected faster-than-projected growth in Permian associate gas could quickly fill new pipelines
- Slowing LNG exports or weaker-than-expected power sector demand could undermine Henry Hub price support
- A loss of Haynesville supply discipline might add unexpected pressure to the benchmark market
What to watch
- Whether Blackcomb achieves full operation by Dec 2026
- Progress on Hugh Brinson I (Sept 2026) and II (Q1 2027)
- Stability of narrow Waha-Hub spreads
- Signs of accelerating pipeline flows indicating supply jumps
- New EIA data on associated gas production and flaring rates