Gas Holds While Oil Slips: EQT and Expand Energy's Structural Advantage at $75 WTI

EQT | NYSE | EXE | NASDAQ | Source data: Q1 2026 10-Q filings (EQT accession 0000033213-26-000030, April 22, 2026; EXE accession 0000895126-26-000028, April 28, 2026), Yahoo Finance commodity data, FRED DHHNGSP series

The Divergence That Changed the Game

At $75.26 WTI and $3.21 Henry Hub, the commodity market is running two different stories simultaneously. Oil is testing its floor. Gas is holding, and for EQT Corporation and Expand Energy, that distinction just delivered the best Q1 in either company's history. The morning brief flagged this divergence. Here's what it actually means for the operators writing those checks.

EQT posted net income of $1.49 billion in Q1 2026, up from $242 million a year earlier. Expand Energy swung from a $249 million loss in Q1 2025 to $1.16 billion in net income. Both companies had the same tailwind: the NYMEX gas curve averaged $4.95 and $5.04/MMBtu respectively during Q1, a sharp reversal from the $3.65 NYMEX average EQT faced in Q1 2025. But Q1 is history. The question operators should be asking is whether the structural setup that drove those results survives at current strip pricing.

EQT: 581 Bcf Sold at $5.07

EQT's Q1 2026 natural gas sales volume reached 581,327 MMcf, an 8.4% increase year-over-year from 536,338 MMcf in Q1 2025. The company averaged $5.07/Mcf including cash-settled derivatives, versus $3.66 it realized in Q1 2025 on a comparable basis. Basis was actually positive this quarter: EQT booked a $0.38/Mcf differential before basis swaps, compared to ($0.01)/Mcf a year earlier. That reflects tighter Appalachian differentials during a cold-weather draw period now behind us.

The derivative structure matters for the current-price outlook. Cash-settled hedges cost EQT negative $0.20/Mcf against the quarterly price, meaning the company was selling above its hedge book and surrendering upside. The trade-off is that same structure limits downside when strip falls toward current $3.21 HH levels. EQT's Q2 2026 disclosure indicated 10-15 Bcfe of strategic curtailments planned, subject to market conditions. That's a playbook it used in 2023 when Waha collapsed. Operating income hit $2.04 billion in Q1, with capital expenditures of $599 million. Annualized, that is a meaningful free cash flow position even with gas retreating from Q1 highs.

CIR Analysis: EQT's curtailment optionality is structurally underappreciated. A company that can idle 10-15 Bcfe of production per quarter in response to price signals, without losing contract capacity, is not exposed to a $3.21 HH the same way a company with fixed take-or-pay obligations and no curtailment flexibility is. At current strip, EQT is not in distress. It is in manage mode.

Expand Energy: 6.9 Bcf/d With a Basin Spread That Matters

Expand Energy's Q1 2026 production numbers read differently at the basin level. Haynesville averaged 3,148 MMcf/d at $4.40/Mcf realized. Northeast Appalachia (Marcellus) averaged 2,785 MMcf/d at $5.70/Mcf. Southwest Appalachia came in at 981 MMcf/d gas plus 15 MBbl/d oil at $4.74/Mcfe blended. Total output: 7,436 MMcfe/d, with an average realized price of $4.35/Mcfe including derivatives, versus $3.76/Mcfe in Q1 2025.

The spread between Haynesville ($4.40/Mcf) and Northeast Appalachia ($5.70/Mcf) reflects the pricing mechanisms embedded in EXE's asset base. Northeast Appalachia gas prices to Transco-connected markets, Algonquin City Gate, and increasingly to LNG-adjacent hubs, mechanisms that decouple it from pure Henry Hub correlation. Haynesville prices close to the Gulf Coast, which is its own structural strength: proximity to LNG export terminals. EXE holds a 35% equity stake in the NG3 gathering pipeline, which commenced CO2 capture and sequestration operations with ExxonMobil in February 2026, targeting Haynesville gas for Gulf Coast LNG delivery. At $75 WTI, that LNG optionality matters more than any Permian oil-levered play.

GP&T costs are rising and warrant attention: $0.84/Mcfe in Haynesville, $1.05/Mcfe in NE Appalachia, and $1.38/Mcfe in SW Appalachia. Total GP&T came in at $1.03/Mcfe versus $0.92/Mcfe in Q1 2025, a 12% year-over-year increase driven by new well production, annual fee escalations, and the NG3 pipeline going into service. Production expenses ran $0.28/Mcfe. Combined cash costs are running roughly $1.31/Mcfe, leaving substantial margin against $4.35 average realizations. If gas retreats to $2.50 NYMEX, the margin compresses fast in Southwest Appalachia where GP&T alone is $1.38.

The Oil-Levered Comparison: What $75 WTI Actually Does

A Permian-pure-play producer running $75 WTI against a $40-45/bbl cash cost breakeven (including GP&T, LOE, production taxes, and G&A) nets $30-35/boe before capex. At 2024-era $85 WTI, that margin was $40-45. The compression is real, and at $75, Permian operators on the margin of their drilling economics are slowing activity.

CIR Analysis: EQT and EXE are not exposed to the same margin pressure. At $3.21 Henry Hub against $1.31/Mcfe all-in cash costs, the gas-weighted margin is wider in percentage terms than most Permian operators enjoy at $75 WTI. The irony is that oil-levered peers look better on a boe headline, but the gas-weighted operators are in better shape on cash margin percentage.

Peer comparison at current prices (Q1 2026 actuals, CIR margin calculations from reported filings):

EQT avg realization: $5.07/Mcfe | Cash cost est. ~$1.20/Mcfe | Margin: ~$3.87/Mcfe (~76%)

EXE avg realization: $4.35/Mcfe | Cash cost ~$1.31/Mcfe | Margin: ~$3.04/Mcfe (~70%)

Source: EQT and EXE Q1 2026 10-Q filings. Margin calculations per CIR using reported costs and realized prices. Note: Q1 2026 prices were materially above current HH levels. Current-strip economics for both companies are lower.

What To Watch

• EQT Q2 curtailment execution. The company guided 10-15 Bcfe of strategic curtailments. If HH stays at or below $3.21 through June, watch for actual curtailment numbers in the Q2 release and whether volume exceeds the top of that range.
• EXE Haynesville GP&T trajectory. The NG3 pipeline is now in service, driving GP&T higher. Whether that incremental cost buys structural LNG-adjacent pricing or simply raises breakevens without commensurate price benefit becomes clear over the next two quarters.
• The $3.00 HH floor test. Both companies showed Q1 2026 strength at $4.95-5.04 NYMEX. Current front-month at $3.21 is already 35% below that level. A move below $3.00 would force more aggressive curtailments from both operators and test hedge books in earnest.
• Permian rig count at $75 WTI. If oil operators pull rigs, associated gas from the Permian declines, which supports HH basis. EQT and EXE benefit if Permian-associated gas supply drops. Watch Baker Hughes weekly data through July.

Disclosure: The author/publisher holds positions in EQT and EXE as of the publication date. This does not constitute investment advice.

Crude Intelligence Report is an independent upstream oil and gas intelligence publication. The content in this article is for informational purposes only and does not constitute investment advice, financial advice, or a recommendation to buy or sell any security. Always conduct your own due diligence before making investment decisions. CIR and its contributors may hold positions in companies mentioned; any such positions will be disclosed when known. © 2026 Crude Intelligence Report. All rights reserved.

This article contains forward-looking statements and analytical opinions. Actual results may differ materially.