Autoresearch: EIA STEO / Today-in-Energy Henry Hub 2026–2027 and EQT/EXE realized-price floor (Sep 2026)

Generated by /autoresearch on 2026-09-19. Synthesized across 3 rounds from EIA primary HTML/PDF plus EQT/EXE IR and the EXE Q2 10-Q. Anchored by Grokipedia Henry_Hub. See Provenance. Treat as raw material — review before promoting into a project or thread. No buy/sell/size. Do not re-rate EQT/EXE. Context: vault/projects/stock-market

Summary

The latest EIA Short-Term Energy Outlook (release September 9, 2026, forecast completed September 3) puts the Henry Hub spot price at $3.43/MMBtu in 2026 and $3.28/MMBtu in 2027 — a decline into 2027, not a lift (STEO landing; STEO text; Table 2). That is a material revision versus the January Today-in-Energy note that said “just under $3.50” in 2026 and “just under $4.60” in 2027, LNG-led (TiE, 2026-01-14). Do not collapse those two EIA products: the $4.60 figure is a January STEO recap, not a late-summer print. Realized spots after the late-July EQT/EXE Q2 prints are still in the high-$2s (August monthly average $2.78; last daily $2.97 on September 15) (EIA monthly; EIA daily). No August/September issuer update replaces the July 14 EQT hedge table or discloses a 2027 EXE ladder. The producer realized-price floor has not shown up in P&L.

Findings

1. Latest EIA STEO (Sep 9) — 2027 HH is $3.28, not $4.60

The September STEO overview table (rounded) is $3.53 (2025) → $3.43 (2026) → $3.28 (2027) for “Natural gas spot price (dollars per million BTU),” with U.S. LNG exports 15.1 → 17.4 → 18.6 Bcf/d (STEO landing; natgas page). Table 2 (modeling completed September 3; PDF dated September 4) gives the unrounded quarterly path in $/MMBtu (Table 2):

The August STEO (release August 11) had already cut the annuals to $3.44 / $3.31 from the July STEO’s $3.67 / $3.49 (−6.2% / −5.1%), and had 3Q26 at $2.87, “down 50 cents compared with last month’s forecast,” because of “reduced LNG feedgas demand and record natural gas production” and storage heading into winter at a record 3,985 Bcf (end-October), 5% above the five-year average (August STEO archive; August TiE, 2026-08-12). September trims another cent on 2026 and three cents on 2027, and lowers end-October storage to 3,969 Bcf, still 5% above the 2021–2025 average (STEO text).

Do not treat the January TiE $4.60 as current. That article is dated January 14, 2026 and explicitly cites “our January Short-Term Energy Outlook”: “decrease about 2% to just under $3.50 … before rising sharply in 2027 to just under $4.60/MMBtu,” with 2027 demand growth “driven mainly by more feed gas demand from U.S. liquefied natural gas (LNG) export facilities” (TiE 67004). The July 28 vault pass that used that URL as a contemporaneous 2027 lift was reading a January recap.

2. Realized Henry Hub prints after late-July Q2 — still high-$2s

EIA’s monthly Henry Hub series (release September 16, 2026; next September 23) is (monthly table):

• 2026 YTD: Jan 7.72 (weather spike), Feb 3.62, Mar 3.04, Apr 2.77, May 2.94, Jun 3.15, Jul 2.89, Aug 2.78. September not yet printed.

Daily prints after the EQT (July 22) / EXE (July 28) Q2 windows stay below $3.00 into mid-September. Selected EIA daily closes (daily table):

• Jul 27–31: 2.63, 2.65, 2.58, 2.65, 2.59
• Aug 3–7: 2.81, 2.74, 2.60, 2.60, 2.56 (series low in this window)
• Aug 31–Sep 4: 2.90, 2.90, 2.88, 2.95, 2.92
• Sep 8–11: 2.90, 2.81, 2.76, 2.71
• Sep 14–15: 2.85, 2.97 (last printed daily as of the September 16 release; Sep 16–18 blank)

A realized Appalachian producer floor that required Henry Hub to lift toward $4 would be visible here. It is not. Spots are below even the September STEO’s already-soft 3Q26 $2.85 print for most of August.

3. LNG vs data-center attribution — do not collapse

January TiE (stale on the level, still explicit on driver): the 2027 lift was “driven mainly by more feed gas demand from U.S. liquefied natural gas (LNG) export facilities,” with Plaquemines, Corpus Christi Stage 3, and Golden Pass named; 2026 demand +0.6 Bcf/d vs supply +1.1, then 2027 demand +2.5 vs supply +0.9 (TiE 67004). An April TiE still frames the 2026–27 export ramp as LNG + Mexico pipeline, not data centers (TiE 67484, 2026-04-16).

August/September STEO (current on the level): EIA does not restore a 2027 price lift and does not attribute the (now-absent) lift to AI campuses.

• Electricity sales are “driven by data center development and increased manufacturing activity,” with a Texas interconnect pause cutting West South Central 2027 sales vs August (790 vs 829 BkWh) (STEO text; STEO landing).
• Natural-gas share of generation is flat at 40% / 40% / 40% in 2025–2027 (STEO landing).
• Table 5a electric-power gas consumption: 35.8 → 36.8 → 37.5 Bcf/d (+1.0 / +0.7). LNG gross exports: 15.1 → 17.4 → 18.6 Bcf/d (+2.3 / +1.2). Dry production: 107.6 → 111.7 → 115.9 Bcf/d (+4.1 / +4.2) (Table 5a).
• Production growth is Permian + Haynesville >70% of the add (Permian 27.5 → 29.3 → 31.5; Haynesville 15.0 → 16.4 → 17.7). Appalachia is nearly flat: 36.7 → 37.2 → 37.5 (Table 5a; natgas page).
• August TiE: Haynesville stays economical at the $3.44 2026 HH because of Gulf LNG proximity, not because EIA is marking a data-center bid into the price (TiE 67944).

So: LNG is still the larger 2026–27 volume increment in EIA’s own table. Data-center load shows up as electricity sales, not as a 2027 Henry Hub floor. The January $4.60 path was LNG-led and has been withdrawn by later STEOs. Those are two separate facts.

4. No later EQT/EXE realized-price or 2027 hedge-ladder print

EQT. The last hedge table is still “as of July 14, 2026.” Q2 2026 average realized price $2.65/Mcfe (vs $2.81 in Q2 2025). 2027 short-call strikes remain $4.51 (Q2–Q4 2027) with $3.16 swaps on part of Q2–Q4 2027; Q3 2026 collars $3.50 / $4.94. Net debt $5.5B. No August or September IR release updates that ladder (EQT Q2 release).

EXE. Q2 2026 (released July 28) still shows gas NYMEX $2.90 and average realized $2.90 including derivatives; Northeast Appalachia $2.15/Mcf vs Haynesville $2.62 — the basin handicap is intact (EXE Q2 release; 8-K Ex. 99.1). The Q2 10-Q (period ended June 30, 2026) reports 2,771 Bcf of natural-gas derivative notionals (827 fixed-price, 644 two-way collars, 651 three-way collars, plus basis) with no year-by-year 2027 ladder (EXE 10-Q). MD&A is explicit that 1H26 prices were soft and that any tightening is forward:

“Domestically, a confluence of mild weather and robust production has negatively impacted natural gas prices during the first half of 2026. However, structural demand drivers, led by the commissioning of new LNG export capacity, accelerating industrial onshoring, and the rapid expansion of AI-powered data centers, are expected to tighten market conditions…” (EXE 10-Q)

EXE itself leads with LNG, then onshoring, then AI data centers, and says the hedge floor covers “over 65% of our projected gas volumes through the end of 2026” — not a 2027 disclosure (same). Indexers list EXE 8-Ks dated September 16–17, 2026 (new agreement / financial obligation). Those filings 403’d on sec.gov this pass (undeclared-automated-tool); search titles do not describe a Q3 earnings, realized-price, or hedge-ladder update. Treat as unfetched.

5. Appalachian basis in the latest EIA note — still a discount, not a wellhead floor

The only September Today-in-Energy that touches Appalachian pricing is the September 9 Algonquin note: April–July 2026 Appalachia regional average hub was 77¢/MMBtu below Henry Hub, “the second-widest discount ever reported,” feeding a 43¢ Algonquin discount to HH (TiE 68124). That is not a later confirmation of the July “record-high winter-strip basis” read; it is a spring/summer discount print. Combined with August HH at $2.78, a 77¢ Appalachia discount would put regional hubs near $2. That is the opposite of a realized wellhead floor in current P&L.

Grokipedia’s Henry_Hub primer is encyclopedic (NYMEX delivery point, Erath LA; Nov 2024 monthly average $2.12) and does not carry the 2026–27 STEO path (Grokipedia Henry Hub).

Add-evidence quotes (steps 4 / 5)

Use these as cited add-evidence on ai-gas-demand-to-appalachian-producer-price-floor steps 4–5. They do not re-rate the names.

1. Step 5 — the 2027 lift is gone in the current STEO (EIA disagrees with its own January TiE). Table 2: Henry Hub $3.43 (2026) / $3.28 (2027); 3Q26 $2.85; 2Q27 $2.76 (Table 2). Contrast, do not overwrite: January TiE still says 2027 “just under $4.60/MMBtu … driven mainly by more feed gas demand from U.S. liquefied natural gas (LNG) export facilities” (TiE 67004).

2. Step 4 — realized floor still not in issuer P&L; no later hedge ladder. EQT Q2: “Average realized price ($/Mcfe) | $2.65” and hedge table “as of July 14, 2026” with 2027 short calls at $4.51 (EQT Q2). EXE Q2: NYMEX $2.90, realized $2.90, NE Appalachia $2.15 vs Haynesville $2.62 (EXE Q2). August HH monthly $2.78; last daily $2.97 on September 15 (monthly; daily).

3. LNG vs DC — EXE’s own 10-Q still leads with LNG; EIA’s volume table agrees. EXE: structural drivers “led by the commissioning of new LNG export capacity, accelerating industrial onshoring, and the rapid expansion of AI-powered data centers, are expected to tighten” — forward tense, after 1H26 prices were “negatively impacted” by “mild weather and robust production” (EXE 10-Q). EIA Table 5a: LNG exports +2.3 / +1.2 Bcf/d vs electric-power gas +1.0 / +0.7 in 2026/2027 (Table 5a).

Contradictions and open questions

• EIA vs EIA on 2027 HH. January TiE ~$4.60 (LNG-led lift) vs July STEO $3.49 vs August $3.31 vs September $3.28. The attribution in the January piece (LNG, not DC) is consistent with later STEO volume tables; the level is not. Keep both on the page.
• August STEO vs September STEO on 3Q26. August text: 3Q26 $2.87. September Table 2: 3Q26 $2.85. Small; use Table 2 for the current quarterlies.
• Basis: July “record winter strips” vs September “second-widest Appalachia discount.” Different seasons and products (winter strips vs Apr–Jul cash hubs). The September TiE does not confirm a tightening wellhead floor in summer 2026 cash.
• EXE Sep 16–17 8-Ks (indexer: new agreement / financial obligation) were not fetched (sec.gov 403). Unlikely to be a realized-price print, but unread.
• No Q3 2026 EQT/EXE print as of 2026-09-19. Next primary test of the floor-in-P&L claim is the Q3 release, not this STEO.
• Data-center electricity vs gas-index contracts. September STEO’s DC language is power sales. EQT’s CPV deal remains PJM-power-linked, in-service early 2031 on the July 22 call recap — still not a 2026–27 gas-index floor.

Provenance

Rounds run: 3 of 3

Sub-questions by round:

Round 1 (broad survey):

1. What is the latest EIA STEO / Today-in-Energy Henry Hub 2026–2027 forecast as of September 2026?
2. After late-July EXE/EQT Q2, is there an August/September realized-price or 2027 hedge-ladder update?
3. Does EIA still attribute any 2027 lift to LNG rather than AI/data-center demand?
4. Has a producer realized-price floor shown up in P&L or in post-July HH prints?

Round 2 (drill-down):

1. What are the September (not August) STEO quarterly HH numbers? — Table 2: 2027 year $3.28, 2Q27 $2.76
2. What are official EIA monthly/daily HH prints for Jul–Sep 2026? — Aug $2.78; last daily Sep 15 $2.97
3. Does any post-July EQT/EXE IR or 10-Q replace the July 14 / June 30 hedge disclosures? — No year-by-year 2027 EXE ladder; EQT still July 14

Round 3 (resolve remaining uncertainty):

1. In EIA’s own balance, is 2026–27 demand growth LNG-export or power/DC? — LNG +2.3/+1.2 vs power-gas +1.0/+0.7; DC is electricity-sales language
2. Does EXE’s Q2 10-Q MD&A attribute tightness to DC vs LNG, and did a September 8-K change the hedge/price print? — LNG-led, forward; Sep 8-Ks unfetched (403)

Anchor source (Grokipedia, fetched before round 1):

• Henry Hub — 12,017 chars extracted (capped) via _lib/grokipedia.py — encyclopedic NYMEX/Erath primer; Nov 2024 $2.12 monthly average; no 2026–27 STEO path

URLs fetched (15 successful primary/IR, 2 failed this session after retry):

Round 1:

• STEO text (September 2026) — official / PDF — $3.43 / $3.28; storage 3,969 Bcf; DC in electricity sales
• STEO landing — official — release Sep 9 / completed Sep 3; overview table
• STEO natural-gas page — official — dry gas 111.70 / 115.90; HH $3.43 / $3.28
• TiE 67004 — official — January 14, 2026; ~$3.50 / ~$4.60; LNG-led
• TiE 67944 — official — August 12; record production; 2026 HH $3.44
• TiE 68124 — official — September 9; Appalachia −77¢ vs HH Apr–Jul
• TiE 67484 — official — April 16; LNG export ramp (not a Sep update)
• EIA daily HH — official — Jul–Sep 2026 daily prints
• WebFetch timeouts on several eia.gov HTML URLs — recovered with browser-UA curl (same URLs)

Round 2:

• STEO Table 2 — official / PDF — September quarterly HH
• STEO Table 5a — official / PDF — production / LNG / power-gas
• EIA monthly HH — official — Aug 2026 $2.78; release 2026-09-16
• August STEO archive — official / PDF — $3.44 / $3.31 vs July $3.67 / $3.49
• EQT Q2 2026 results — issuer IR — $2.65 realized; July 14 hedge table
• EXE Q2 2026 results — issuer IR — $2.90 realized; no 2027 ladder

Round 3:

• EXE Q2 10-Q — issuer / SEC — 2,771 Bcf notionals; LNG-led MD&A; 65% hedged through 2026
• EXE 8-K Ex. 99.1 — issuer / SEC — regional $2.15 / $2.62
• [Failed: https://www.sec.gov/Archives/edgar/data/895126/000089512626000053/exe-20260916.htm] — SEC undeclared-automated-tool 403 (Sep 16 8-K unread)

Tools used: WebSearch, WebFetch, curl (browser UA for eia.gov after WebFetch timeouts), _lib/grokipedia.py fetch, pypdf on *.gov STEO tables. Generated: 2026-09-19 Source-reliability notes: eia.gov HTML WebFetch timed out this session; browser-UA curl succeeded — treat as Periodic-failure for WebFetch, Reliable via curl. sec.gov mixed: Q2 10-Q/99.1 retrieved via search-fetch; later 8-K 403 (already documented as “prefer browser UA / curl”). ir.eqt.com and investors.expandenergy.com succeeded.