Natural Gas Futures Price Forecast (NG1!, TTF): Hormuz Closure Threatens 20% of Global LNG, EU Storage at 31% — Buy

Natural Gas Futures Price Forecast (NG1!, TTF): Hormuz Closure Threatens 20% of Global LNG, EU Storage at Just 31%, Qatar Suspends Shipping — Buy

Sunday, March 1, 2026 | TradingNews.com

European natural gas futures (TTF) are set to gap higher Monday morning into what could become the most significant disruption for gas markets since Russia's invasion of Ukraine upended global trade in 2022. The Strait of Hormuz carries approximately 20% of the world's liquefied natural gas exports — and Iran's Revolutionary Guards have declared the strait closed to commercial traffic. Qatar, one of the planet's largest LNG producers and the source of roughly 15% of Europe's LNG imports, has urged shipowners to suspend maritime activities entirely. The U.S. Navy advised tanker companies to avoid nearby waters because it could not guarantee their safety. Dozens of tankers have already diverted from the Persian Gulf. Some sought refuge in Qatar and the UAE while others abandoned the region altogether. A loaded supertanker chartered by Shell that was supposed to cross the strait has idled. Tanker crews reported hearing explosions near Iran's Kharg Island, through which the country exports 90% of its crude oil. EU gas storage levels have fallen to below 31% — compared to 40% at this point last year. Germany's storage stands at just 20.5%. France sits at 21%. The combination of a physical chokepoint closure and depleted European reserves creates a supply vulnerability that did not exist twelve months ago. Meanwhile, U.S. natural gas equities are already responding to the tightening global picture: Northwest Natural Gas (NYSE:NWN) surged 5.51% to $53.04 after posting Q4 adjusted EPS of $1.39 (beating consensus by $0.03), guiding FY26 EPS to $2.95–$3.15 (above the $2.98 midpoint consensus), and committing to a $2.6–$2.9 billion capital expenditure plan through 2030 that targets 6–8% rate base growth. BTIG raised its price target from $53 to $55 with a Buy rating. The gas market is about to reprice Monday — and the repricing has barely begun.

23% of Global LNG Passes Through Hormuz — Qatar Suspends Shipping, the U.S. Navy Can't Guarantee Safety, and Europe Has 31% Storage

The Strait of Hormuz is not just an oil chokepoint. Nearly one-fifth of the world's LNG exports transit through the same narrow passage between Iran and Oman, and the disruption to gas markets from the strait's closure is structurally different from the oil disruption — and potentially more dangerous for European consumers. Oil can be rerouted around the Cape of Good Hope at additional cost and time. LNG requires specialized tankers, regasification terminals, and long-term supply contracts that cannot be redirected overnight. When Qatar — the world's second-largest LNG exporter — tells shipowners to suspend maritime activities, the global gas market loses a supply source that takes weeks to replace through alternative cargoes from the United States, Australia, or West Africa.

Qatari LNG volumes account for approximately 15% of Europe's total LNG imports. Any sustained disruption would hit Asian buyers hardest (Japan, South Korea, and China are Qatar's largest customers), but the knock-on effects for Europe are immediate: Asian buyers competing for alternative cargoes from U.S. Gulf Coast terminals, Australian North West Shelf facilities, and West African producers drive up spot prices globally. Europe's LNG import terminals in the Netherlands, Belgium, France, and Spain face higher input costs regardless of whether the gas physically originates from the Gulf. The market is global, the pricing is global, and the Hormuz disruption reprices every molecule.

The vulnerability is amplified by Europe's storage deficit. EU gas storage has fallen below 31% — nine full percentage points below the 40% level at this same time last year. Germany, the continent's largest gas consumer, sits at just 20.5% storage. France stands at 21%. These numbers mean that Europe enters the spring refilling season with a significantly larger gap to close before next winter, and the refilling must happen at precisely the moment when Hormuz-related supply disruptions are driving spot prices higher. The cost of refilling European storage to the 90%+ level mandated before winter 2026–2027 has just increased dramatically — and that cost flows through to industrial energy prices, household heating bills, and ultimately to the ECB's inflation calculations.

The Worst Natural Gas Market Disruption Since Russia 2022 — Why the Hormuz Closure Is Structurally Different From Nord Stream

The comparison to Russia's 2022 invasion of Ukraine is direct and warranted. When Russia weaponized its gas exports and Nord Stream pipelines were sabotaged, European TTF natural gas prices spiked above €300/MWh in August 2022 — a level that forced industrial shutdowns, emergency demand rationing, and a continent-wide scramble for alternative LNG supply. The current situation differs in three critical ways that could make it either better or worse than 2022.

First, Europe has more LNG import capacity in 2026 than it did in 2022. Floating storage and regasification units (FSRUs) deployed in Germany, the Netherlands, and Italy since 2022 have significantly expanded the continent's ability to receive seaborne gas. This structural improvement provides a buffer that did not exist four years ago — if alternative LNG cargoes are available to purchase, Europe can physically receive them.

Second, the Hormuz disruption is potentially broader than the Russian supply cut because it simultaneously affects oil and gas markets. Russia's gas cutoff was isolated to piped gas flowing to Europe through specific corridors. The Hormuz closure disrupts LNG exports from Qatar, pipeline gas from the Gulf region, and crude oil from Saudi Arabia, UAE, Iraq, Kuwait, and Iran simultaneously. The cross-commodity contagion means energy prices across the entire complex — gas, oil, refined products, petrochemicals — move higher together, creating a broader inflationary impulse than the 2022 gas-specific shock.

Third, the duration is unknowable. Russia's gas cutoff was a strategic decision that became effectively permanent — pipelines were physically destroyed. The Hormuz closure is a military action that could end in days (if de-escalation occurs) or persist for months (if the conflict broadens). This uncertainty is itself a premium: gas markets will price worst-case scenarios until evidence of de-escalation materializes, because the consequence of being wrong on the downside (running out of gas) is catastrophic for buyers.

The Inflation Transmission — Capital Economics: $100 Oil Adds 0.6–0.7 Percentage Points to Global Inflation, and Natural Gas Amplifies It

Capital Economics estimates that if crude oil surges to $100 per barrel, the addition to average global inflation would be 0.6 to 0.7 percentage points. That figure captures the oil-specific transmission through gasoline prices, transportation costs, and manufacturing inputs. It does not fully capture the natural gas amplification. European TTF gas prices feed directly into electricity generation costs (gas-fired power plants set the marginal price in most European electricity markets), industrial heating, chemical feedstock pricing, and fertilizer production. A simultaneous spike in gas and oil prices creates a double inflationary shock that exceeds the sum of its parts because supply chains face cost increases from both energy inputs at once.

For the ECB, the implications are severe. German CPI just dropped to 1.9% in February — briefly below the 2% target — and the broader eurozone number is expected Tuesday. That soft print was supposed to provide runway for further rate cuts. If Hormuz-driven energy prices push headline CPI back above 2.0% and potentially toward 2.5%+ within weeks, the ECB faces the same impossible dilemma it confronted in 2022: cut rates to support a weakening economy or hold rates while energy costs crush consumers and corporate margins. The ECB's internal language — "not pre-committing to a rate path" — reflects maximum flexibility, but flexibility in this context means uncertainty, and uncertainty is bearish for European equities and the euro.

The Fed faces a parallel problem. U.S. core PPI already stands at 3.6% — nearly triple consensus expectations. If Brent crude reaches $100 and U.S. Henry Hub natural gas prices follow global LNG pricing higher (as they did in 2022 when U.S. LNG export demand pulled domestic gas prices to $10/MMBtu), the Fed's inflation fight gets materially harder. The CME FedWatch pricing of 42% odds for a June rate cut becomes untenable. Rate cuts are off the table in an environment where both headline and core inflation accelerate from already elevated levels.

Northwest Natural Gas (NYSE:NWN) — Q4 EPS Beat, FY26 Guidance Above Consensus, 70th Consecutive Dividend Increase, and a $2.9B Capex Plan

Northwest Natural Gas (NYSE:NWN) surged 5.51% to $53.04 on Friday — breaking above the $50.00 bottoming formation that had contained the stock for weeks. The catalyst was a Q4 earnings report that delivered adjusted EPS of $1.39 versus the $1.36 consensus estimate, a $0.03 beat that confirmed the company's operational execution in a challenging utility environment. Revenue came in at $394.16 million, missing the $420.04 million expectation — a shortfall driven by weather-related demand variability rather than structural weakness.

The more significant numbers were forward-looking. FY26 EPS guidance of $2.95–$3.15 exceeded Wall Street's $2.98 midpoint consensus, with the upper end implying 7.5% earnings growth from the record adjusted EPS of $2.93 delivered in 2025. BTIG responded immediately, raising its price target from $53 to $55 and reaffirming its Buy rating. The stock's close at $53.04 — already near the prior target — means the new $55 objective implies modest but achievable near-term upside of approximately 3.7%.

NWN's capital expenditure plan is the structural story. The company committed to $2.6–$2.9 billion in capital spending through 2030, targeting 6–8% rate base growth annually. Rate base growth in the regulated utility model translates directly into earnings growth because utilities earn an allowed rate of return on their invested capital. Each dollar of incremental rate base generates a regulated return that flows to the bottom line with near-certainty, making NWN's earnings trajectory among the most predictable in the equity market.

The MX3 gas storage expansion project is a critical component of the capex plan. Expanding storage capacity positions NWN to capture higher margins during periods of gas price volatility — precisely the kind of environment that the Hormuz crisis is creating. Long-term agreements have already been secured for the MX3 capacity, ensuring steady returns regardless of short-term commodity price fluctuations. The SiEnergy acquisition further diversifies the company's geographic and operational footprint.

From a shareholder return perspective, NWN increased its dividend for the 70th consecutive year — one of the longest dividend growth streaks of any publicly traded company in the United States. The consistency through seven decades of economic cycles, interest rate environments, and energy market disruptions speaks to the durability of the regulated utility model and the conservatism of NWN's financial management.

NWN Valuation and Technical Structure — P/E 20, Gross Margin 88%, Debt-to-Equity 1.76, Breakout Above $50

NWN trades at approximately 20x earnings — reasonable for a regulated utility with 6–8% rate base growth, an 88% gross margin, and a 25.4% EBITDA margin. The gross margin at 88% reflects the regulated pricing structure: NWN passes through most commodity costs to ratepayers and earns its margin on the distribution and service component. The EBITDA margin of 25.4% represents the operating profitability after accounting for operating expenses, maintenance, and regulatory costs.

Return on equity of 7.39% is modest relative to some utility peers but consistent with the regulated model where capital allocation is constrained by rate cases and regulatory approvals. The debt-to-equity ratio of 1.76 and leverage ratio of 4.1 reflect the capital-intensive nature of utility infrastructure investment — the $2.6–$2.9 billion capex plan requires significant debt financing. Enterprise value stands at $4.85 billion. The price-to-book ratio of 1.45 is attractive relative to utility sector averages. The price-to-cash-flow ratio at -32.7 is distorted by timing of capital expenditures and working capital movements — not a meaningful valuation metric for the current period.

Technically, the move from $49.99 to $53.04 over the past week represents a decisive breakout above the $50.00 bottoming formation. Volume increased during the rally, confirming institutional buying interest rather than short covering. The $50.27 level now functions as support. The $55.00 BTIG target represents the next resistance level. A stop-loss below $50.00 (the pre-breakout support) provides approximately 5.7% downside risk against 3.7% upside to the $55 target — not an ideal risk/reward in isolation, but the Hormuz-driven tailwind to gas utility valuations adds asymmetric upside that the pre-crisis price target does not capture.

The company added nearly 98,000 new gas and water connections — a metric that demonstrates customer growth in the service territory and supports the rate base expansion that drives earnings. Customer growth in the regulated utility model is the foundation: more connections mean more rate base, more rate base means more allowed earnings, more allowed earnings mean a higher stock price. The 98,000 additions confirm that NWN's service territory is growing, not shrinking — a distinction that separates it from utilities in declining population areas.

Turkey's Spot Natural Gas Market — 14,584 Liras Per 1,000 Cubic Meters, Volume Up 10%, and 213.9 Million Cubic Meters Received Saturday

Turkey's position at the crossroads of European and Middle Eastern gas flows provides a real-time indicator of market conditions. On Saturday, 1,000 cubic meters of natural gas on Turkey's spot market cost 14,584 Turkish liras (approximately $332 at the 43.92 lira/dollar exchange rate). Cumulative trade volume reached approximately 465,000 cubic meters, with total trade value rising approximately 10% to 6.8 million liras from Friday's 6.2 million.

Turkey received approximately 213.9 million cubic meters on Saturday — a substantial daily intake that reflects the country's position as a major gas transit and consumption hub. Turkey sources gas from Russia (via TurkStream), Azerbaijan (via TANAP), Iran (via pipeline), and global LNG markets. The Iranian pipeline supply — which transits directly from Iran to Turkey — is immediately at risk if the conflict disrupts Iranian domestic infrastructure or if Turkey curtails Iranian imports in response to the geopolitical situation. Turkey has already raised its security level for ships following reports of Iran restricting Hormuz transit.

The Turkish spot price trajectory over the past week tells a story of pre-crisis stability: 14,485.50 liras on Thursday February 19, 14,548 on Friday February 20, 14,583 on Saturday February 21, 14,615 on Sunday February 22, 14,661 on Monday February 23, 14,705 on Tuesday February 24, 14,670 on Wednesday February 25, 14,606.54 on Thursday February 26, 14,678 on Friday February 27, and 14,584 on Saturday February 28. The range has been remarkably tight — approximately 1.5% from low to high — reflecting a pre-crisis equilibrium that Monday's Hormuz repricing is about to shatter. When Turkey's spot market reopens with the Hormuz closure priced in, the 14,584 lira/1,000m³ price level becomes a historical marker of where gas traded before the disruption.

Saudi Arabia's Emergency Plan, Pipeline Bypasses, and Why OPEC+ Output Increases Cannot Solve the LNG Shortage

Saudi Arabia activated an emergency plan to increase crude oil exports to their highest level in nearly three years, and both Saudi Arabia and the UAE operate pipelines that allow some exports to bypass Hormuz. These are meaningful mitigants for crude oil markets. They are irrelevant for natural gas markets. Qatar's LNG exports have no pipeline bypass — the gas must be liquefied, loaded onto specialized tankers, and shipped through the strait. There is no overland alternative. No pipeline connects Qatar's North Field to European or Asian consumers. The LNG must physically transit the waterway, and the waterway is closed.

OPEC+'s agreement to increase oil output by 206,000 barrels per day similarly addresses crude supply but does nothing for gas. The global LNG market operates on separate infrastructure, separate contracts, and separate pricing mechanisms. A barrel of oil cannot substitute for a cubic meter of gas in electricity generation, industrial heating, or chemical production. The OPEC+ announcement may calm oil markets marginally, but it provides zero relief to TTF natural gas prices, which are driven entirely by LNG supply availability and European storage dynamics.

The duration question applies with even greater force to gas than to oil. Oil can be stored in strategic petroleum reserves and commercial tanks for extended periods. LNG storage is more limited — regasification terminals have buffer capacity measured in days, not months. If Qatar's LNG exports are disrupted for two weeks, the impact on European and Asian gas balances is severe. If disrupted for a month, it creates a storage deficit heading into summer refilling season that cannot be closed without sustained high prices attracting every available alternative cargo. If disrupted for a quarter, Europe faces a 2022-style energy crisis with storage unable to reach adequate levels before winter.

The Verdict — Natural Gas Futures (NG1!, TTF): Buy Monday's Open, EU Storage at 31% Meets Hormuz LNG Shutdown

Natural gas is a Buy at Monday's open. European TTF futures are poised for a significant gap higher — the combination of Hormuz closure, Qatar suspending shipments, the U.S. Navy unable to guarantee tanker safety, and EU storage at 31% (versus 40% a year ago) creates the most acute supply threat since Russia's 2022 invasion. Germany at 20.5% storage and France at 21% mean Europe's two largest economies enter the crisis with dangerously low reserves. The 20% of global LNG that transits Hormuz cannot be replaced by pipeline alternatives because no pipeline alternatives exist for Qatari gas. OPEC+ oil output increases are irrelevant to the gas market. Saudi pipeline bypasses apply to crude, not LNG.

U.S. natural gas prices will follow global LNG pricing higher as export demand from U.S. Gulf Coast terminals increases to compensate for lost Qatari supply — the same dynamic that pushed Henry Hub to $10/MMBtu in 2022. NWN at $53.04 is a Buy within the gas utility complex: Q4 EPS beat, FY26 guidance above consensus at $2.95–$3.15, 6–8% rate base growth on $2.6–$2.9 billion capex, the MX3 storage expansion capturing volatility premiums, and the 70th consecutive dividend increase. BTIG's $55 target is the near-term ceiling, but a sustained Hormuz disruption reprices gas utility valuations higher than pre-crisis targets reflect. Support at $50.27, stop below $50.00.

The asymmetry favors longs. If de-escalation occurs within 48 hours and the strait reopens, TTF returns to pre-crisis levels and the trade is flat. If the disruption persists for weeks, TTF reprices 30–50% higher as Europe scrambles for alternative LNG supply while simultaneously attempting to refill storage from 31% to 90%+ before winter. The downside is a return to Friday's close. The upside is a rerun of 2022 gas pricing that doubled, tripled, and eventually rose tenfold from pre-crisis levels. The probability distribution is not symmetric. The tail risk is entirely on the upside for gas longs. Position accordingly.

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