Natural Gas Futures Price Forecast: June Futures Settle at $2.864 as Hammerfest LNG Outage and Iran Stalemate Test the $2.953 50-Day Wall

Natural Gas (NG=F) is changing hands at $2.864 to $2.877 per million British thermal units on Wednesday, May 13, 2026, after settling the June front-month contract up 2.1 cents or 0.7% at $2.864/MMBtu on the New York Mercantile Exchange. The intraday tape has run between an earlier morning print at $2.914 — up 2.5% — and the settle near the bottom of the day's range, with the session high at $2.945 representing the highest level since April 8 and a clean test of the 50-day moving average resistance at $2.953. The cash market tape tells a meaningfully different story than the futures market — Henry Hub spot prices have firmed to $2.91 on the SNL feed against the prior-day $2.82, while Waha Hub prices have remained in negative territory for a record 68 consecutive days at -$2.87, deepening from -$3.87 the prior session as Permian pipeline constraints continue to trap gas in the nation's largest oil-producing shale basin. The regional cash spread is genuinely extraordinary — Transco Z6 New York at $2.10, PG&E Citygate at $1.60, Eastern Gas at $2.00, Chicago Citygate at $2.50, Algonquin Citygate at $2.38, SoCal Citygate at $2.27, AECO at $1.18 — a fragmented price map that captures both the regional pipeline bottleneck dynamics and the early-summer demand transition. The cooling degree day forecast at 106 against the 10-year norm of 84 represents a 26% positive deviation, while the heating degree day forecast at 41 against the 60 prior year reading captures the warm-spring transition that has been the dominant fundamental driver of the recent price action. The market capitalization framework for natural gas futures sits within the broader $79.16 billion to $87 billion crypto context this morning, but the structural fundamental backdrop is genuinely defined by the convergence of three specific catalysts hitting simultaneously — the Hammerfest LNG facility outage in Norway, the stalled Iran peace negotiations that have kept the Strait of Hormuz blockade active, and the EIA storage report on deck for Thursday that the market is positioning around.

The 50-Day Moving Average At $2.953 Is The Decision Point

The single most important technical level on the natural gas chart right now sits at the 50-day moving average at $2.953. June Natural Gas Futures rejected the level on Wednesday after challenging it from below, with the intraday high at $2.945 falling roughly 8 cents short of a confirmed breakout. The intermediate trading range that defines the multi-week structure runs from $3.622 to $2.592, with the 50% retracement at $3.107 representing the next upside target if the 50-day breaks decisively. The short-term range from $2.592 to $2.945 produces a pivot at $2.769 that sits as the immediate downside support floor on any pullback. The technical configuration is genuinely binary — June Natural Gas (NG=F) either reclaims and holds above $2.953 on confirmed daily-close basis with elevated volume, opening the path toward $3.107 and ultimately the $3.622 longer-range target, or rejects at the 50-day for a third consecutive session and rotates lower toward $2.769 as the structural support base. The early Wednesday price action has indicated a developing upside bias with the 50-day moving average acting as the primary directional pivot. Trader reaction to this indicator over the next 48 hours will set the tone heading into the EIA storage release Thursday morning, with heightened volatility expected around both the storage number and any new Iran headline. The momentum indicators on the daily timeframe lean constructive without producing decisive trend confirmation, which is precisely the configuration that historically precedes the kind of explosive directional move that short-covering dynamics can produce.

The Hammerfest LNG Outage That Tightened Global Supply

The most acute supply-side catalyst behind the recent rally sits with the Hammerfest LNG facility in Norway going offline this week due to an operational issue, with repairs expected to take several days. Hammerfest is not the largest LNG facility in the world, but spare global LNG capacity is structurally limited in the current environment, and any reduction in supply during the European inventory refill period creates immediate pricing pressure because the system has no slack to absorb the disruption cleanly. European buyers are still rebuilding storage ahead of next winter following the structural loss of Russian pipeline gas, and the continent is competing directly with Asian buyers for every available spot cargo. An unplanned outage at a producing facility during that bidding war does not stay local — it ripples through global pricing immediately, and the impact has already been visible in the Dutch TTF benchmark surge to $16.04/MMBtu against the $11.94 prior-year average and the $18.51 five-year average. UK natural gas futures (GWM1) have settled at 114 pence per therm after holding most of the prior sessions' gains, with the persistent uncertainty over how long supply disruptions in the Middle East will last keeping the geopolitical premium embedded in European pricing. The Strait of Hormuz remains largely closed, with shipping routes facing restrictions from both sides and choking off approximately one-fifth of global LNG supply. While most gas from the Persian Gulf flows to Asia, the disruption has tightened global supply broadly and increased competition, which has fueled European concerns about winter inventory adequacy. The Japan-Korea Marker benchmark at $16.99/MMBtu sits well above the $12.24 prior-year average, capturing the same dynamic on the Asian demand side. The global LNG complex is structurally pricing the disruption regardless of what the U.S. domestic storage situation suggests, which is what is creating the persistent upward bid on U.S. natural gas futures despite comfortable inventory levels.

The Iran Stalemate That Refuses To Resolve

The geopolitical backdrop is reinforcing the bullish setup through the safe-haven and supply-disruption channels simultaneously. President Trump dismissed Iran's response to the U.S.-backed peace proposal earlier this week, intensifying concerns that the 10-week war could continue and further disrupt shipping through the Strait of Hormuz. Iran's Aladdin Boroujerdi, a member of Parliament's National Security and Foreign Policy Commission, has stated explicitly that Iran "will by no means relinquish the achievement of the Strait of Hormuz" and will not enter into negotiations regarding nuclear enrichment — language that signals the diplomatic track has fundamentally stalled. The Strait blockade dynamics matter for natural gas pricing because Qatar moves a substantial share of global LNG supply through the Strait of Hormuz region, and any escalation involving Iran does not need to produce a direct supply interruption to move prices — the threat alone is enough. The geopolitical premium currently embedded in June natural gas futures reflects that exact mechanism, with the global LNG market tight enough that even a temporary disruption in cargo flows changes the calculus for European and Asian buyers immediately. The natural gas market has historically ignored geopolitical risk when domestic storage was comfortable and demand was strong, but the current configuration is structurally different — storage is above average but the global supply picture is too fragile to ignore the Iran headline. The first LNG tanker has broken the Hormuz blockade earlier this week, and Chinese oil tankers are testing safe passage through the Strait, but ExxonMobil has confirmed a long Qatar LNG repair timeline after the Hormuz crisis hit supply infrastructure, suggesting that even if shipping resumes the operational delays will extend the global supply tightness through the summer.

The EIA Storage Print Setup For Thursday

The single most important domestic catalyst sits with the Energy Information Administration storage report scheduled for Thursday morning. The Wall Street Journal analyst survey expects an 87 Bcf injection for the week ended May 8, which would put inventories 142 Bcf above the 2021-2025 five-year average against the previous week's 139 Bcf surplus. NGI's estimate sits slightly lower at 86 Bcf. The five-year average for the week ended May 8 sits at +84 Bcf, meaning the consensus is actually pricing a roughly in-line injection rather than the bearish surplus build that the spot price action might suggest. The year-ago figure for the comparable week was +109 Bcf, meaning the current pace is materially tighter than 2025 levels. U.S. total natural gas in storage sits at 2,290 Bcf as of the week ended May 8, against 2,205 Bcf the prior week and 2,239 Bcf one year ago — a 51 Bcf year-on-year deficit that captures the structural tightening despite the headline surplus against the five-year average. The five-year average storage level for the comparable week sits at 2,150 Bcf, putting current inventories 6.5% above normal — down from 6.7% above normal the prior week, confirming the gradual tightening that has been underway. EBW Analytics' Eli Rubin has framed the expectation precisely — two more supportive EIA storage reports are likely before triple-digit injections return at the end of May, with seasonal upside more probable in early summer than during the next seven to ten days leading into the typical physical market weakness around Memorial Day weekend. The implication is that the immediate near-term tape may continue to face headwind from the seasonal weakness pattern, but the structural setup beneath the price action favors the broader bullish thesis over the early-summer horizon.

Lower 48 Production Tape That Reinforces The Tightening

The supply-side fundamentals are providing meaningful support to the rally beyond the headline geopolitical and LNG-specific drivers. Average U.S. Lower 48 gas output has slid to 109.3 Bcf per day so far in May, down from 109.8 Bcfd in April and well off the monthly record high of 110.6 Bcfd in December 2025. The daily production tape shows an even more aggressive contraction — output is on track to drop by 3.8 Bcfd over the past four days to a preliminary 15-week low of 106.4 Bcfd on Wednesday, with the declines concentrated in Texas and Louisiana. The production weakness is structurally driven by the low spot price environment that has forced energy firms including EQT, the second-largest U.S. gas producer, to deliberately reduce production while waiting for prices to recover. The deliberate curtailment dynamic is the cleanest signal that the supply side has rationalized in response to the negative Permian basis and the broader low-price environment, which structurally tightens the medium-term supply-demand balance even if the immediate weekly storage prints continue to show comfortable surpluses. Kinetik Holdings has separately confirmed that Permian Basin natural gas markets are facing unprecedented pressure from deeply negative Waha pricing and rising producer curtailments, but executives have framed the weakness as a temporary bottleneck rather than a long-term structural growth issue. The EIA's most recent Short-Term Energy Outlook cut the 2027 natural gas price forecast by 11% on expectations of higher Permian associated gas production from increased crude oil drilling, which captures the longer-term supply expansion thesis that competes with the near-term tightening dynamics. The combination of voluntary production curtailments now and expected supply expansion later creates a precise window for higher prices in the immediate three-to-six-month horizon before the longer-term supply story reasserts itself.

The Waha Negative Pricing Record That Tells The Pipeline Story

The Waha Hub in West Texas has produced one of the most extraordinary fundamental anomalies in the entire commodity complex over the past 68 days. Cash prices at the Waha Hub have remained in negative territory for a record 68 consecutive sessions, with the latest print at -$2.87/MMBtu against the prior session at -$3.87. The negative pricing dynamic reflects acute pipeline constraints that have trapped gas in the Permian region, the nation's biggest oil-producing shale basin, with producers effectively paying buyers to take molecules off their hands rather than facing flaring restrictions or production curtailment penalties. The Waha situation is the most aggressive manifestation of the broader regional pricing divergence that has defined the U.S. natural gas market in 2026, with the spread between Henry Hub at $2.91 and Waha at -$2.87 representing nearly $6/MMBtu of regional dislocation. The pipeline build-out timeline that would relieve the constraint is measured in quarters rather than weeks, with new takeaway infrastructure scheduled for completion through 2026 and 2027 that should eventually normalize the regional pricing structure. In the meantime, the Permian situation creates a structural divergence where associated gas production from the oil-drilling activity continues to flood the system regardless of the price signal, which is the precise dynamic that the EIA cited in cutting its 2027 price forecast by 11%. The Waha-Henry Hub spread provides a clean read on the structural pipeline bottleneck pressure that will persist through the summer 2026 season, regardless of what the broader storage and demand trajectory looks like at the Henry Hub benchmark level.

The Demand Map And The Cooling Transition

The demand-side trajectory is being reshaped by the seasonal transition from heating to cooling, with the specific pattern producing genuinely interesting fundamental implications. LSEG has projected average gas demand in the Lower 48 states including exports holding around 98.9 Bcfd this week and next, with those forecasts upgraded from the prior LSEG outlook on Tuesday. The detailed demand composition shows U.S. power plant demand at 30.7 Bcfd in the current week, rising to 32.5 Bcfd next week — the largest single demand category and the primary driver of the cooling-season transition. U.S. residential demand is collapsing from 7.3 Bcfd the prior week to 6.1 Bcfd current and 4.9 Bcfd next week as the heating season ends. U.S. commercial demand follows the same pattern, dropping from 6.5 Bcfd to 5.8 Bcfd current and 5.1 Bcfd next week. The Industrial demand line holds relatively steady at 22.1 to 21.7 Bcfd across the comparison period. U.S. exports to Mexico are climbing from 6.8 Bcfd to 7.4 Bcfd, while exports to Canada hold steady at 2.7 Bcfd. The total weekly U.S. demand including exports is projected at 99.0 Bcfd current week and 98.7 Bcfd next week — both meaningfully above the 94.8 Bcfd five-year average for the month, which captures the structural demand expansion that the lower-price environment in 2026 has enabled. Andy Huenefeld at Pinebrook Energy Advisors has framed the dynamic precisely — the lower price environment in 2026 is driving higher utilization of gas-fired generation assets across the country, increasing gas consumption on a weather-normalized basis, with demand from this sector likely to continue outpacing year-ago levels and potentially limiting storage growth into the peak summer months. The weekly power generation share of natural gas at 37% currently against the 40-42% 2024-2025 historical average captures the temporary share decline driven by elevated wind and solar generation, but the absolute consumption figures continue to rise on the underlying weather and demand expansion.