Report Date: Tuesday, July 21, 2026 (after market close) | Call: Wednesday, July 22, 2026, 10:00 a.m. ET
EQT shares have pulled back sharply into this report, falling from a 52-week high near $68 in late March to roughly $49 as of July 20 — a decline of about 28% from the peak and roughly 20% since the Q1 release in late April. The pullback tracks a softer domestic natural gas tape: Henry Hub spot prices in April and May 2026 ran below year-ago levels even as EQT posted a record Q1. Sell-side price targets have been trimmed accordingly in recent weeks (Morgan Stanley to $68 from $74, Truist to $65 from $74, Goldman Sachs to $63 from $65), though the majority of the ~25-analyst coverage universe still carries Buy/Strong Buy ratings.
Consensus for Q2 2026 sits at roughly $0.41 adjusted EPS on ~$1.84 billion of revenue, which would be revenue growth of about 15% year-over-year but an EPS decline of roughly 9% versus Q2 2025's $0.45 — a reflection of how much softer gas prices have been sequentially after the winter price spike EQT captured in Q1. Estimates have moved down meaningfully into the print (Zacks cut its Q2 estimate to $0.40 from $0.67 in late June), and EQT's Zacks Earnings ESP was recently negative, suggesting the setup for a beat is less favorable than it has been in the company's recent four-quarter streak of positive surprises.
EQT's Q1 2026 was a record quarter and the reason expectations reset higher for 2026 overall:
Management framed the quarter as proof that the post-Equitrans, vertically integrated platform can convert commodity volatility into free cash flow, and reiterated a long-term $5 billion net debt target that was "within reach by year-end."
| Metric | Q2 2026 Guidance |
|---|---|
| Total sales volume | 570–620 Bcfe (includes 10–15 Bcfe of strategic curtailments) |
| Maintenance capex | $525–595 million |
| Growth capex | $210–235 million |
| TILs (net wells) | 30–45 |
| Average differential | ($0.75)–($0.65)/Mcf |
| Operating costs | $1.03–$1.17/Mcfe |
Two things stand out. First, management deliberately curtailed 10–15 Bcf of production this quarter — using its integrated storage-like flexibility to hold gas back during the seasonally weak shoulder period rather than sell into low spring prices, with the option to curtail more heavily ahead of winter if the forward curve justifies it. Second, Q2 is the peak capex quarter of the year, driven by growth-project timing; management guided to a step-down in spending in Q3/Q4 that should support a free-cash-flow recovery in the back half of 2026. Investors should watch whether volumes land near the top of the range (as they did in Q1) and whether management reiterates or nudges full-year 2026 volume guidance of 2,275–2,375 Bcfe.
Ahead of earnings, EQT filed an 8-K (July 14) disclosing preliminary Q2 derivative results: a total gain on derivatives of $45 million and net cash settlements received on derivatives of $73 million (comprised of $76 million received on NYMEX natural gas hedges, partly offset by $3 million paid on basis/liquids hedges). This is a modest net positive from hedging — consistent with commentary on the Q1 call that the balance-of-year hedge book was "in the money" as prices moderated into spring — but it is far smaller than the outsized unhedged upside EQT captured in Q1's winter price spike, underscoring why sequential EPS is expected to decline.
The geopolitical backdrop has intensified since the Q1 call. Management had already flagged that Middle East disruptions were driving a second global energy shock of the decade, noting that European natural gas prices nearly doubled following the disruption of Qatari LNG supply and the closure of the Strait of Hormuz, even as US natural gas prices stayed low and stable. That divergence has only sharpened heading into Q2 earnings: oil prices have pushed above $90/barrel amid escalating Middle East hostilities, with US pump prices back above $4/gallon, even as domestic Henry Hub gas has remained comparatively soft and, per EIA data cited by sell-side analysts, actually ran below year-ago levels in April and May 2026. This is the crux of the setup: EQT's near-term earnings power is tied to a still-lackluster domestic gas price, while its longer-term equity story is increasingly about capturing the global price gap through LNG exposure that doesn't begin until 2030.
Key things management will likely be pressed on: - LNG optionality: Management quantified that if its LNG portfolio (currently only ~15% of volumes) were fully online today at current TTF/JKM spreads, 2026 free cash flow would be roughly $6 billion — versus the $500 million/year uplift the contracts are modeled to generate starting in 2030 at the current strip (or up to $2.5 billion in a repeat-volatility scenario). Investors will want an update on offtake negotiation timing (management previously pointed to 2028–2029 for signing incremental agreements). - In-basin power/data-center demand: Progress on Homer City, Shippingport, MVP Boost, and the Borealis pipeline open season, plus commentary that midstream/gas-supply conversations tied to data centers could represent 8–10 Bcf/d of incremental egress opportunity, are all live catalysts investors will look for updates on. - Capital allocation: With leverage now below 1x net debt/EBITDA and the $5 billion net debt target within sight, expect continued discussion of the buyback-versus-dividend debate, and any signal on reintroducing low-single-digit upstream production growth once structural demand (data centers, power) is more contractually locked in.
EQT goes into this print with a strong operational and balance-sheet story (record Q1 free cash flow, an investment-grade upgrade, and a nearly-achieved deleveraging target) set against a much weaker sequential commodity backdrop that consensus already expects to show up as a roughly 9% year-over-year EPS decline despite double-digit revenue growth. The stock's ~20–28% drawdown since the Q1 report suggests the market has already priced in much of the Q2 pricing weakness; the swing factors for the print and stock reaction are likely to be (1) whether volumes and costs continue to run better than guided, as they have in recent quarters, (2) any change to full-year guidance, and (3) incremental progress on the data-center/LNG demand pipeline that underpins the multi-year bull case, especially against a geopolitical backdrop that has made the value of US energy reliability and LNG optionality more salient than at any point in this cycle.