Natural Gas Price Forecast (NG00): Futures Crash to $2.58 as 103 Bcf Storage Build Buries Bulls and Waha Prints Negative for 54 Days
NG00 near $2.58 (-4.04%) hits lowest since Oct 2024 as EIA storage build blows past 94 Bcf forecast | That's TRadingNEWS
Natural Gas Futures (NG00) are getting hammered on Thursday's session, with the front-month May contract on the New York Mercantile Exchange falling 10.2 cents or 3.7% to $2.62 per million British thermal units (mmBtu) — some prints registering even lower at $2.58 per mmBtu after the EIA storage report landed, representing a 5.18% decline that puts the contract on track for its lowest close since April 15 and the weakest print observed since October 2024. The drop comes after six consecutive sessions of gains, making the reversal particularly sharp and creating a technical failure pattern that bulls will struggle to recover from quickly. For context, the broader commodities complex has been diverging sharply across energy categories — while WTI Crude (CL00) surged 3.30% to $96.03 and Brent (BRN00) climbed 3.16% to $105.10, Natural Gas has collapsed 4.04% in the opposite direction, a split that reveals how differently the two markets process the same geopolitical news flow. Gasoline at the US pump has nudged higher toward $4.02 per gallon national average, with the Center for American Progress data showing the national benchmark has risen 34.9% or $1.04 per gallon from the $2.98 pre-war February level. Diesel sits at $5.49 per gallon, up 46%. Jet fuel has climbed to $3.99 per gallon, up 59.6%. Heating oil prints $3.83, up 47.3%. Yet Natural Gas — the one category where the United States has genuine energy sovereignty — is collapsing, and that divergence is the single most important analytical framing for the current tape.
The EIA Storage Report That Triggered the Sell-Off
The storage data released Thursday morning was the proximate trigger for the violent repricing lower, and the numbers deserve careful examination because they expose just how oversupplied the US market has become. The Energy Information Administration reported that energy firms added 103 billion cubic feet (bcf) into storage during the week ended April 17. That print blew past the 94 bcf analyst consensus in the Reuters poll, and it dwarfs the 77 bcf injection during the comparable week last year. More significantly, the build is dramatically above the five-year (2021-2025) average of 64 bcf for the same period — meaning inventories are filling at a pace roughly 61% faster than the historical norm. Analysts had flagged heading into the release that the build would likely exceed seasonal expectations because mild weather kept heating demand subdued, but the magnitude of the beat compared to consensus was still enough to trigger mechanical selling across the futures curve. The cumulative storage trajectory now points toward seasonal peaks well above historical comparisons, which is precisely the condition that keeps producers under margin pressure and forces continued price weakness until either demand accelerates or supply responds.
Waha Hub Negativity — The Bellwether of Permian Supply Glut
The single most remarkable data point in the entire natural gas complex right now is the Waha Hub in West Texas, where cash prices have printed in negative territory for 54 consecutive days — a record streak that captures exactly how trapped supply has become in the Permian Basin, the nation's largest oil-producing shale region. Daily Waha prices first averaged below zero in 2019, with just 17 negative days that year. That count dropped to six in 2020, was zero in 2021 and 2022, printed once in 2023, then exploded to 49 times in 2024, 39 times in 2025, and now a record 63 times so far in 2026. Year-to-date, Waha has averaged a negative $1.91 per mmBtu, compared with a positive $1.15 in full-year 2025 and a positive $2.88 across the five-year 2021-2025 average. The negative pricing means Permian producers are effectively paying midstream operators to take gas off their hands, a mechanical symptom of the massive associated-gas production growth tied to the region's oil extraction that has overwhelmed the existing pipeline capacity. Until additional pipeline infrastructure comes online to transport the supply out of the basin to Gulf Coast LNG export terminals or other demand centers, the Waha discount will continue to function as the single largest drag on national benchmark pricing.
The Supply Side — Production Running at Near-Record Levels
US natural gas production continues to run at historically elevated levels despite the subdued pricing, which reinforces the oversupply narrative that is crushing the futures complex. LSEG data shows average gas output in the Lower 48 states has eased to 110.3 billion cubic feet per day (bcfd) so far in April, down marginally from 110.4 bcfd in March. For context, the monthly record high was 110.7 bcfd in December 2025, meaning current production sits within a fraction of all-time peaks even as prices have collapsed. On a daily basis, output was on track to drop roughly 3.8 bcfd over the past 17 days to a preliminary 11-week low of 108.3 bcfd on Thursday, though preliminary data is typically revised later in the day and the underlying trend remains aggressive. The reality is that US natural gas abundance has become so structural that, with discovered reserves plus conventional production trajectories, the country has access to roughly 300 years of domestic gas supply at current consumption rates — and Canada's reserves add even more. When a commodity is that plentiful and the storage cushion is already full, only demand-side catalysts can break the bearish cycle.
The Demand Side — Mild Weather Keeps Heating Consumption Subdued
The demand-side story is equally negative for bulls. Meteorologists project that weather will remain mostly near normal through May 8, eliminating the kind of abnormal cold snap that could trigger a meaningful drawdown in stored gas. LSEG projects that average gas demand in the Lower 48 states, including exports, will slide from 103.7 bcfd this week to 100.5 bcfd next week — a drop of roughly 3.1% week-over-week that tells the story. The forecast remains consistent with LSEG's outlook from Wednesday, meaning there has been no meaningful demand-side catalyst to reverse the trajectory. When supply runs above 110 bcfd and demand drops toward 100 bcfd, the gap gets deposited directly into storage, which is precisely how the 103 bcf weekly build materialized. The seasonal transition out of winter heating and into the shoulder season typically produces weak demand readings, but the current configuration combines normal seasonal softness with unusually mild weather conditions — a double-headwind that leaves bulls without an obvious catalyst until summer cooling demand begins accelerating meaningfully in June and July.
LNG Exports — The Structural Bull Case That Exists But Isn't Enough Yet
The one piece of the market architecture that provides a structural bull case for Natural Gas Futures (NG00) over the medium term is the LNG export channel, which is scaling aggressively. Average gas flows to the nine large US LNG export plants have risen to 18.9 bcfd so far in April, up from 18.6 bcfd in March. That figure compares with a monthly record high of 18.7 bcfd in February, meaning April is on pace to deliver fresh export record territory. The capacity expansion continues — the first tanker departed QatarEnergy and ExxonMobil's 2.4 bcfd Golden Pass LNG export plant in Texas on Wednesday, marking the facility's inaugural cargo shipment and adding material new export capacity that will structurally tighten the domestic balance once the plant reaches full run rate. Chevron Australia has also resumed full LNG production at its Wheatstone gas facility in Western Australia, which affects the global LNG picture but does little for US domestic pricing. The longer-term thesis is that continued LNG export capacity expansion will eventually absorb the surplus domestic production and force prices higher, but the current build-out pace is not fast enough to overcome the immediate storage overhang and production surge. Export demand of 18.9 bcfd represents only about 17% of total Lower 48 output, leaving the vast majority of supply exposed to domestic demand dynamics that remain weak.
The US-Iran War Divergence — Why Gas Is Behaving Differently
The most analytically interesting feature of the current energy tape is the divergence between Natural Gas and oil/gasoline pricing in response to the US-Iran conflict. Gasoline prices have climbed 34.9% since February 27 (the pre-war reference date), with state-level increases ranging from 23.5% in Washington up to an extraordinary 51.7% in Utah, 45.7% in Idaho, 45.6% in Tennessee, 45.4% in Mississippi, and 45% in Kentucky. Even the lowest-impact states like Michigan (26.2%) and California (25.6%) have seen material gasoline price increases. Yet Natural Gas is not participating in this war-premium repricing, and the reason is structural. The United States produces most of its own natural gas, importing very little, and all imports come from Western Hemisphere nations — specifically South America and the Caribbean. That means the Strait of Hormuz closure, which has disrupted roughly 20% of global seaborne crude flow and driven Brent above $100 per barrel, has virtually no impact on US domestic LNG pricing. Approximately 13% of US oil feedstock for gasoline production comes from Persian Gulf countries, which is why gasoline at the pump responds sharply to Hormuz disruptions. But domestic natural gas pricing is driven almost entirely by domestic weather patterns and storage levels, both of which currently argue for lower prices.
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The Global LNG Complex — TTF and the European Energy Shock
The international context matters for understanding what is happening at Henry Hub. Dutch Title Transfer Facility (TTF) natural gas has surged to €41.93 per MWh, up 31.1% from the €31.98 pre-war level. European gas prices are spiking on supply security concerns as Russian flows remain constrained and LNG imports become the marginal source of supply. That global price surge increases the arbitrage opportunity for US LNG exporters — when TTF sits at €41.93/MWh (roughly $13.80/mmBtu at current exchange rates) while Henry Hub prints $2.58/mmBtu, the gross margin for US exporters reaches exceptional levels. The persistent US-European gas spread is exactly what will keep the LNG capacity buildout aggressive and what creates the medium-term bull case for Henry Hub pricing. However, the current terminal capacity is insufficient to close the arbitrage fully, which means the spread can persist for quarters before US prices lift meaningfully. US Treasury chief Scott Bessent has predicted that gas prices will drop below pre-war levels once the Iran conflict ends, a forecast that aligns with the current domestic oversupply dynamics but conflicts with the reality that global gas remains structurally tight.
Regional Spot Market Context — Türkiye and Global Benchmarks
The global spot market delivers additional context for understanding relative pricing. Türkiye's spot natural gas market saw trading volume increase 14.3% to approximately 3.8 million lira on Wednesday, with 1,000 cubic meters of gas costing 17,186 Turkish lira (equivalent to roughly $382 per 1,000 cubic meters at the current 44.95 lira-to-USD exchange rate). That translates to roughly $10.80 per mmBtu — significantly above Henry Hub pricing and reflective of the typical premium international markets pay over US domestic benchmarks. The cumulative natural gas trade volume amounted to around 222,000 cubic meters on Wednesday, and Türkiye received approximately 161.20 million cubic meters overall — a meaningful throughput that reflects active regional gas trade even as global markets remain stressed. The spot pricing in Türkiye has held steady near 17,000 lira per 1,000 cubic meters across the past several sessions, underscoring the price stability in international markets even as US domestic pricing collapses.
Technical Architecture on the Daily Chart — The Downtrend Continues
The technical picture on NG00 is genuinely bearish and deserves careful examination. The daily candlestick chart shows natural gas continuing to move lower, with the current price near $2.58 to $2.62 representing the lowest levels since October 2024. The next major psychological and structural support sits at $2.50, a round-number level that will likely trigger mechanical buying interest from range traders but does not have the fundamental backdrop needed to produce a sustained reversal. Below $2.50, the chart opens to deeper downside pockets toward the $2.25 to $2.30 zone where longer-term structural support has held during prior bear cycles. On the upside, $3.00 functions as the psychological ceiling and the 50-day EMA sits near that level, which means any rally to $3.00 should be treated as a shorting opportunity rather than a buy signal. A move above $3.00 would require either a genuine demand catalyst — extreme weather or unexpected supply disruption — or a structural LNG capacity ramp that meaningfully tightens the domestic balance. Neither looks imminent. The 14-day RSI and other momentum indicators are likely reading oversold in the near term, which could produce a reflex bounce, but the structural downtrend remains firmly in control.
The Producer Economics and the Capital Discipline Dynamic
The producer-side response to current pricing is worth examining because it provides the mechanism through which supply could eventually rebalance. At $2.58 per mmBtu Henry Hub with Waha cash prices printing negative $1.91 year-to-date average, many US gas producers are operating at or below breakeven economics. Historically, prices at these levels would trigger aggressive rig count reductions and well completion deferrals, which would eventually slow production growth and tighten the supply-demand balance. However, a significant portion of US gas production now comes as associated gas from oil-focused drilling in the Permian Basin, and with WTI oil at $96.03 the incentive for Permian operators to keep drilling oil wells remains strong — which keeps associated gas volumes flowing into the market even if gas prices collapse. That dynamic has broken the traditional supply-response mechanism and is a major reason the current oversupply has persisted longer than historical patterns would suggest. Until either oil prices collapse (reducing Permian drilling activity) or pipeline capacity catches up (relieving the Waha trap), the supply side will remain structurally burdensome for Natural Gas Futures (NG00) pricing.
The Jordan-Syria Gas Flow Development — Regional Integration Progressing
One constructive development in the broader regional gas market is the resumption of daily gas flows from Jordan to Syria at 2 million cubic meters per day. The energy minister noted that some areas are receiving uninterrupted electricity for 24 hours for the first time in years, which reflects how critical these regional flows have become for post-conflict reconstruction efforts. While these volumes are minor relative to global markets, they demonstrate the slow normalization of regional gas flows despite the broader Hormuz tensions. Over time, regional gas integration in the Middle East could become a meaningful demand anchor for global LNG markets, though the current scale is too small to affect Henry Hub pricing directly.
The Seasonal Calendar and What Comes Next
The forward calendar for natural gas deserves careful attention because it maps directly onto the probability of a price recovery. May and June typically see seasonal demand remain weak as temperatures moderate and both heating and cooling loads are minimal. July and August bring meaningful cooling demand as air conditioning use surges, which historically drives modest price recoveries from spring lows. The specific risk for bulls is that 2026 is entering the cooling season with storage levels materially above historical norms, meaning even a hot summer would need to be exceptional to produce the kind of drawdowns required to tighten the balance. Longer-term, the November through February winter heating cycle provides the most significant demand catalyst, but that is six months away and current positioning will face substantial time decay waiting for that window to open. The LNG capacity expansion through the Golden Pass ramp and other facilities over the next 12 months represents the most durable bull case, though it operates on a multi-quarter timeframe rather than immediate pricing support.
Price Targets and the Range Map
The level structure on NG00 is mapped with clarity. The immediate test is $2.50 as the first psychological support pocket. Below that, $2.40 represents a deeper structural floor where longer-term range traders typically step in. A break below $2.40 exposes $2.25 and potentially the $2.00 psychological zone that has marked generational bottoms in prior cycles. On the upside, the first resistance is at $2.75, followed by $2.90, and the critical structural barrier at $3.00 where the 50-day EMA aligns with round-number psychological pressure. Above $3.00, $3.15 to $3.25 opens, then $3.50 as the zone that would signal a genuine regime change rather than just a tactical bounce. The preferred execution framework favors short exposure on any rally toward $2.90 to $3.00 with stops above $3.10, targeting $2.50 and potentially $2.40 on the extended move. Long exposure at current levels is only justified for aggressive mean-reversion positioning with very tight risk management, recognizing that the structural setup remains hostile.
The Broader Energy Policy Context
The policy backdrop deserves acknowledgment because it shapes the forward trajectory. The Trump administration's Iran war has cost taxpayers roughly $33 billion according to Center for American Progress estimates, and the gasoline price shock has delivered approximately $38 per month in additional costs for the average American car owner and $55 per month for light truck owners. For the lowest-income quintile of US households, the combination of elevated gas prices and cuts to Medicaid and SNAP benefits from the Big Beautiful Bill is projected to dampen real income growth according to Goldman Sachs analysis. Pew Research polling shows more than two-thirds (69%) of Americans are concerned about high gas prices as a result of the Iran war. None of these dynamics directly affect Natural Gas pricing given the structural differences between the gas and petroleum complexes, but they create political pressure for accelerated LNG export capacity expansion and domestic drilling incentives, both of which are longer-term bullish for natural gas producers but neutral-to-bearish for near-term NG00 pricing.
The Rating Call — Bearish on NG00
The stance on Natural Gas Futures (NG00) at current levels is Bearish with Defensive Risk Management. The convergence of factors supporting the negative rating is overwhelming. Storage build of 103 bcf for the week ended April 17, which is 61% above the 64 bcf five-year average. Production at 110.3 bcfd near all-time record highs. Waha cash prices negative for 54 consecutive days at an average of negative $1.91 year-to-date. Mild weather forecast through May 8 suppressing demand to just 100.5 bcfd next week. LNG exports at 18.9 bcfd representing only 17% of domestic output. Seasonal demand transition moving away from heating and not yet into cooling. The preferred execution framework favors short exposure on rallies toward $2.75 to $3.00 with stops above $3.10, targeting $2.50 as the first objective and $2.40 on the extended move. A break below $2.40 opens the path toward $2.25 and potentially $2.00. The invalidation scenario requires a combination of a genuinely cold summer weather pattern, an accelerated LNG capacity ramp delivering 2+ bcfd of new demand, and a production slowdown triggered by sustained sub-$2 pricing — all three would need to materialize for the bearish setup to resolve higher. None of those conditions look imminent.
The Probable Path Forward and the Stance to Carry
The most probable near-term sequence carries Natural Gas Futures (NG00) lower toward the $2.50 psychological floor over the coming weeks, with potential for a tactical bounce from oversold conditions but no structural bull case until either weather patterns shift meaningfully or the LNG capacity ramp accelerates. A test of $2.40 becomes credible if the next storage report delivers another build above 90 bcf, and a break to $2.25 opens if summer cooling demand disappoints. The medium-term stance on a 3-to-6-month horizon remains Cautiously Bearish given the structural supply overhang, though the emergence of summer cooling demand could provide a modest floor near $2.40 to $2.50. The long-term stance on a 12-month+ horizon is Neutral to Cautiously Bullish as the cumulative LNG capacity expansion through Golden Pass and other terminals begins to materially tighten the domestic balance — that thesis targets a recovery back toward $3.50 to $4.00 over the 2026-2027 cycle if export growth sustains. The tactical stance is Sell on Strength at current levels with disciplined risk management above $3.10. The global context where Dutch TTF sits at €41.93/MWh and international LNG prices remain elevated provides the structural foundation for eventual US price recovery, but the mechanism for closing that arbitrage is LNG export capacity that will come online over quarters, not weeks. Position sizing should reflect the binary character of weather risk — any unexpected heat dome event in summer could produce a sharp short-covering rally that would damage aggressive short positions — but the base case remains decisively weak given the oversupply architecture. The $2.50 level separates a controlled move from a deeper flush into the $2.00 to $2.25 zone, and that is the critical inflection point that will define trading action over the next four to six weeks. The combination of the largest monthly gasoline price increase since BLS tracking began in 1967 and a Natural Gas complex collapsing to October 2024 lows in the same week tells the entire story of how differently these markets process the same geopolitical shock — and why US natural gas remains one of the cleanest structural short setups in the commodity complex today.
