Natural Gas Elliott Wave Analysis & Live Henry Hub Chart
Natural gas prices at the Henry Hub are navigating a pivotal Elliott Wave juncture in July 2026. The August futures contract dropped 6%+ on July 10 to approximately $3.01–3.15/MMBtu — a 6-week low — as Freeport LNG announced maintenance beginning July 10 through late August (temporarily reducing feedgas export demand) and the EIA reported a 61 Bcf injection into storage for the week ending July 3, widening the surplus above the five-year average to 185 Bcf (~6%). Yet the Elliott Wave structure tells a different medium-term story. EWForecast identified natural gas as ending its bearish cycle at the February 2026 low of $2.779/MMBtu (wave II complete), now forming a "nest" — a series of overlapping 1-2 wave setups signalling an imminent wave 3 impulse breakout. The bullish wave 3 targets: $4.357–$4.409 (first target) and $5.296–$6.183 (main target zone). The EIA STEO (July 7) forecasts Henry Hub averaging ~$3.70/MMBtu in 2026, rising to $3.78/MMBtu in Q4 2027 as new LNG export facilities (Plaquemines LNG, Corpus Christi Stage 3, Golden Pass LNG) ramp up and demand outpaces supply by 1.6 Bcf/day in 2027. For professional natural gas wave counts, professional Elliott Wave services cover natural gas daily. Educational only, not financial advice.
Natural Gas Elliott Wave Count — Wave II Complete, Wave 3 Breakout Pending
EWForecast confirmed (March 2026): "Natural Gas ended its bearish cycle in February 2026, now in a nest formation, expected to break higher while the February 2026 low is not breached." The nest is a multi-layered 1-2 wave setup — a compression pattern that typically precedes explosive wave 3 impulse advances. The February 2026 low of $2.779/MMBtu is the critical anchor. This is educational, not financial advice.
Nest Formation — Triple 1-2 Setup Before Wave 3 Launch
EWForecast: "From the March 2024 low, a fresh bullish cycle began in a 5-wave structure, concluding in January 2026." This was the initial major 5-wave advance that established the bullish direction after natural gas hit multi-year lows near $1.50–2.00/MMBtu in 2024. Cycle degree wave I peaked in January 2026 — completing the impulse structure that created the roadmap for the subsequent bull cycle.
EWForecast: "A subsequent, highly volatile pullback ensued, ending in February 2026 at $2.779." This 3-wave corrective structure was driven by a warm winter reducing heating demand, ample storage, and profit-taking after wave I's advance. The $2.779 February low is the most important level on the natural gas chart — it is the wave II anchor that must not be breached for the entire bullish structure to remain valid.
EWForecast: "Since then, the commodity has been in a 'nest' formation, awaiting a bullish momentum to initiate a breakout higher. The chart shows a triple nest emerging, suggesting a significant bullish move could soon follow." A nest in Elliott Wave theory is a series of overlapping 1-2 wave setups that compress price into a tighter and tighter range — like a spring being coiled. When the nest resolves (a 5-wave advance in wave 3 launches), the resulting move is typically the longest and strongest wave of the entire cycle.
Once the nest resolves with a confirmed 5-wave advance above the January 2026 high, wave III launches. EWForecast: "In the coming days/weeks, we anticipate a 5-wave advance. Once confirmed, we can confidently buy dips within the blue box." The wave 3 extends to $4.357–$4.409 (first target) and $5.296–$6.183 (main target zone) — consistent with the EIA's LNG-driven demand surge forecast for 2027. The trigger for wave III is a 5-wave pattern clearly visible on the daily chart above the nest structure.
After wave III completes near the $5–6 zone, a wave IV correction is expected (typically 23.6%–38.2% retracement of wave III) followed by a final wave V advance. EIA's longer-term LNG demand ramp provides a multi-year structural backdrop for waves III through V: feedgas demand reaching 21.1 Bcf/day in 2027 vs 18.1 Bcf/day now represents structural demand growth that cannot be met by current supply levels alone.
From $3.15 Current → $4.36–$6.18 Wave 3 Zone
Elliott Wave extended wave 3 maximum target — reached if LNG demand surge accelerates faster than EIA forecasts. Full invalidation anchor sits far below at $1.874.
Primary wave 3 target — consistent with LNG-driven 2027 demand growth and tightening storage balance that EIA projects as demand outpaces supply by 1.6 Bcf/d in 2027.
First Elliott Wave target range ceiling — expected to be reached once the nest breakout confirms with a 5-wave advance on the daily chart.
EIA's 2027 price forecast for Q4 2027 ($3.78/MMBtu) and the EIA January 2026 forecast of $4.60/MMBtu 2027 average both point to this zone as a fundamental anchor for the first wave 3 target.
EIA STEO (July 7): Henry Hub averages ~$3.70/MMBtu for full-year 2026. Above-average storage and record production keep a lid on near-term prices.
Down 6%+ on Freeport LNG maintenance + 61 Bcf storage injection beat. Heatwave through Jul 23 provides partial demand support.
EWForecast: "the commodity is expected to break higher while the February 2026 low is not breached." This is the single most important level on the chart — the anchor of the entire bullish cycle.
EWForecast tracks the natural gas nest formation with daily updates — identifying the exact 5-wave launch signal that confirms wave 3, daily storage injection expectations, LNG feedgas monitoring, and the precise $4.357 first-target confirmation. The nest breakout signal is the highest-value alert in natural gas EW analysis.
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Natural Gas Key Fibonacci Levels
Natural gas Fibonacci analysis anchors to the March 2024 structural low (start of cycle wave I) and the January 2026 wave I peak. Note: natural gas prices are quoted per MMBtu (million British thermal units) — one NYMEX natural gas futures contract = 10,000 MMBtu, so a $0.10/MMBtu move = $1,000 per contract.
| Level | Wave Context in Natural Gas | Zone |
|---|---|---|
| $1.874 | Full Elliott Wave invalidation — below here the entire bullish cycle from March 2024 must be reconsidered | Full Invalidation |
| $2.779 | February 2026 wave II low — critical anchor; EWForecast: "break higher while this is not breached" | EW II Low |
| $2.990 | Initial bull structure weakens — EW near-term warning level | Warning |
| ~$3.15 | Current Aug futures price (Jul 10) — nest compression zone after Freeport LNG maintenance drop | Current |
| $3.57 | EIA Q4 2026 Henry Hub forecast — near-term fundamental ceiling for price expectations | EIA Q4 2026 |
| $3.70 | EIA full-year 2026 average forecast — structural price anchor for 2026 | EIA 2026 avg |
| $3.78 | EIA Q4 2027 forecast — rising as LNG export demand tightens storage in 2027 | EIA Q4 2027 |
| $4.357–$4.409 | EW wave 3 first target range — post-nest breakout confirmation level | First Target |
| $4.60 | EIA January 2026 2027 annual average forecast — structural demand ceiling for 2027 | EIA 2027 Jan |
| $5.296–$6.183 | EW wave 3 main target zone — driven by LNG feedgas 21.1 Bcf/d demand + storage tightening | Main Target |
Why Storage Data Drives Natural Gas Wave Direction
Natural gas storage is the single most important weekly price catalyst — more so than any other fundamental for this commodity. The EIA releases weekly storage data every Thursday at 10:30am ET. Every wave trader must understand the storage cycle: injection season (Apr–Oct) builds inventory, withdrawal season (Nov–Mar) depletes it. Current status (Jul 3): storage at 2,983 Bcf — 6% above the five-year average.
Two bearish catalysts hit simultaneously on July 9–10: Freeport LNG (one of the largest US LNG export terminals in Freeport, Texas) announced maintenance beginning July 10 through late August — temporarily removing approximately 2.1 Bcf/day of feedgas demand. The same week's EIA storage report showed a 61 Bcf injection — above the five-year average of 51 Bcf — widening the storage surplus from 175 Bcf to 185 Bcf. Combined: August natural gas futures dropped 6%+ in a single session to $3.01/MMBtu, their lowest in six weeks.
An intense heatwave settled across the eastern US over the Fourth of July weekend, pushing electric power demand sharply higher. Natural gas demand for electric power generation averaged 45.6 Bcf/day for the week ending July 7 — more than 15% higher than the previous week. The EIA noted this heatwave has "the potential to raise natural gas consumption for power generation in the near term." Above-normal temperatures are forecast through July 23, providing partial demand support that limits how far prices fall despite the Freeport maintenance and storage beat.
EIA forecasts US dry natural gas production averaging 111.2 Bcf/day in 2026 — a new record, led by growth in the Permian Basin region. Rystad Energy concurs: 111.6 Bcf/day for 2026, up 3.6% from 2025. Record production is the primary reason storage inventories remain above the five-year average despite rising LNG exports and strong summer power demand. Lower 48 output fell slightly to 109.7 Bcf/day in early July from 110.0 Bcf/day in June — modestly below the December 2025 monthly record of 110.6 Bcf/day. Output below 109 Bcf/day for a sustained period would materially tighten the storage balance.
The EIA projects US working natural gas inventories will reach 3,966 Bcf by end-October 2026 — the end of injection season — approximately 5% above the five-year average. With above-average inventories heading into winter, the EIA expects Henry Hub to average $3.57/MMBtu in Q4 2026, which is 5% below the same quarter last year. The storage surplus vs the five-year average is the primary anchor keeping natural gas below $4.00 near-term — it limits how fast the Elliott Wave nest can resolve upward.
2,983 Bcf Working Gas · 6% Above 5-Year Average
Six Variables That Move Natural Gas Waves in 2026–2027
Natural gas is a complex market driven by weather, LNG exports, production, storage, and power demand — all simultaneously. Currently: 3 medium-term bulls (LNG ramp, demand growth, supply lag in 2027) vs 3 near-term bears (Freeport maintenance, storage surplus, record production).
LNG feedgas averaged 18.1 Bcf/d through July 7 (+19% YoY). Three new facilities ramp up in 2026: Plaquemines LNG, Corpus Christi Stage 3, Golden Pass LNG. Rystad: 21.1 Bcf/d LNG feedgas by 2027. This 16% jump is the structural engine of EW wave 3 target $4.357–$6.183.
EIA: summer 2026 power sector averages 42.2 Bcf/d (+0.5 Bcf/d YoY). Heatwave week hit 45.6 Bcf/d (+15% WoW). New annual record forecast for 2027: 38.1 Bcf/d average (+4%). Power demand is the seasonal floor keeping prices above $3.00 even with storage surplus.
EIA: demand grows +2.5 Bcf/d in 2027 while supply grows only +0.9 Bcf/d — a 1.6 Bcf/d deficit. Storage will draw below the 5-year average. This tightening is the fundamental driver behind EIA's 2027 Henry Hub rising to $3.78 Q4 and the structural support for EW wave 3 toward $4–6.
Freeport LNG (major US export terminal, ~2.1 Bcf/d capacity) maintenance temporarily removes significant feedgas demand. Combined with the 61 Bcf storage injection beat, this drove the July 10 price drop. Maintenance end (late August) is a bullish catalyst when LNG volumes resume.
185 Bcf surplus vs 5-yr average. EIA projects end-October at 3,966 Bcf (5% above avg). Above-average storage heading into winter = limited price pressure = Henry Hub anchored near $3.57 in Q4 2026. Surplus must narrow before EW wave 3 can fully materialise.
Record US production (Permian Basin growth leading) keeps supply above demand in 2026 by 0.5 Bcf/d. This prevents a storage deficit in 2026 and limits how fast the EW nest can launch wave 3 upward — the supply tipping point comes in 2027 when demand growth exceeds supply growth.
EIA: $3.57–$3.78 · EW Wave 3: $4.357–$6.183
How to Apply Elliott Waves to Natural Gas Futures
Important: This is educational content, not financial advice. Natural gas futures are highly volatile — daily price moves of 5–10% are common during weather events, storage surprises, or LNG disruptions. One NYMEX NG contract = 10,000 MMBtu, so a $0.10/MMBtu move = $1,000 per contract. Always use stop-losses and consult a licensed financial advisor.
Natural Gas Wave-Analysis Mistakes
The nest is a compression zone — price can trade sideways for weeks or months before wave 3 launches. Wave analysts who entered long on the EWForecast nest signal in March 2026 and held through Freeport maintenance to $3.01 in July 2026 experienced a $0.78/MMBtu adverse move — approximately $7,800 per contract — without wave 3 having launched.
The traditional model — injection season bearish, withdrawal season bullish — is being disrupted by LNG exports. LNG feedgas at 18.1 Bcf/day is now the second-largest US natural gas demand sector. LNG demand follows global pricing, not US seasons. Summer 2026 bearishness is specifically driven by Freeport maintenance, not a structural seasonal headwind — when maintenance ends in late August, feedgas resumes and the storage surplus narrows.
Natural gas at $3.15/MMBtu looks "cheap" compared to crude at $72/bbl — but one NG contract (10,000 MMBtu) carries $31,500 notional vs WTI's $72,000. The critical distinction: natural gas daily percentage moves (5–10%) are far larger than crude's typical 1–3%. A 7% NG move = $2,205 per contract — comparable to a 3% WTI move at $2,160. The lower nominal price does not mean lower risk per contract.
The EIA's full-year 2026 average of $3.70/MMBtu does not cap the peak price for any individual month. If natural gas spends January–September 2026 near $2.80–3.50 and spikes to $5.00 in Q4 as wave 3 launches, the annual average could still be $3.70. Annual averages are backward-looking composites — they do not constrain forward price targets during wave 3 impulse moves.
Natural Gas Elliott Wave — Questions Answered
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