Weather forecasts shifted a bit cooler over the weekend, adding some pressure to nearby futures, although there were no major changes to the broader outlook. Strong summer demand remains in place, particularly across Texas and the West, but the market continues to show little concern about the current balance. With August now trading to new lows, the near-term price trend now appears to be pointed lower.

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• Natural gas futures remained rangebound, although winter pricing strengthened. The August 2026 NYMEX contract declined $0.04 to $2.87 per MMBtu, Summer ’26 held at $2.89, and Winter ’26–’27 gained $0.10 to $3.65.

• The EIA reported a 32-Bcf storage injection for the week ended July 17. The surplus to the five-year average widened slightly to 183 Bcf, while the deficit to last year narrowed to 16 Bcf.

• Heat intensified across Texas and the West, lifting regional natural gas and power prices. ERCOT established a new all-time system demand peak above 91 GW.

• Northeast winter natural gas basis surged, with Winter ’26–’27 pricing gaining nearly $1.00 as higher global LNG prices increased the premium associated with winter supply constraints.

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The broader picture remains largely unchanged heading into the weekend. Stronger summer demand and tighter storage injections have helped establish some support, but the front of the curve has still struggled to generate a sustained move higher. For now, the front of the curve continues to look comfortable trading below $3.00, even as firmer winter pricing suggests somewhat greater concern further into the future.

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Today’s storage report showed a 32-Bcf injection, the smallest build since the beginning of the injection season. The data implies that market fundamentals tightened by nearly 1.5 Bcf per day from the previous week as warmer temperatures and weaker wind generation increased demand from natural gas-fired power generators. Reduced LNG feedgas demand and marginally higher production provided some offset, but the balance should tighten further as persistent heat in Texas continues to support elevated power-sector consumption.

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This morning’s storage report showed the smallest build since the early stages of the injection season, as cooling demand continues to ramp up seasonally and limit the volume of gas available for injection. The 32-Bcf injection marginally outpaced both the five-year average build for the same week and the corresponding build in 2025, which came in at 30 Bcf and 27 Bcf, respectively. This narrowed the deficit to year-ago stocks to 16 Bcf and widened the surplus to the five-year average to 183 Bcf, the largest gap to that benchmark since September 2025.

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More persistent heat in Texas and stronger natural gas demand from power generators appear to be combining to provide support. The Wall Street Journal survey points to a 34-Bcf injection for the week ended July 17, down from 41 Bcf the previous week, although still slightly above the five-year average of 30 Bcf. Even so, sustained heat and firmer power-sector consumption have helped the market regain some footing ahead of Thursday’s storage report.

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Weather forecasts were also mostly unchanged, giving the market little fresh fundamental direction. Near-term heat remains insufficient to materially alter expectations for natural gas-fired generation, while the broader outlook continues to favor generally manageable summer demand. With mixed fundamentals and rangebound trading, the path of least resistance again looks to be sideways for natural gas futures.

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The market remains weighed down by mild weather expectations following last week’s brief heat, with forecasts showing generally cooler conditions returning across much of the East. Traders are also monitoring a tropical disturbance in the Gulf, which could disrupt LNG exports and reduce power generation demand along the coast. While there is always risk to offshore production, the current system appears unlikely to cause a significant interruption to Gulf supply. With no sustained heat visible in the forecast, prices may struggle to regain meaningful ground in the near term.

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• Natural gas futures remained under pressure but avoided another major downside break. The August 2026 NYMEX contract declined $0.03 to $2.91 per MMBtu, while Summer ’26 slipped $0.02 to $2.90.

• The EIA reported a 41-Bcf storage injection for the week ended July 10, reducing the surplus to the five-year average to 181 Bcf and widening the deficit to last year to 21 Bcf.

• Natural gas demand from power generators increased sharply, with stronger gas-fired output in MISO, CAISO, and ERCOT followed by rising peak loads across the East and Midwest.

• Forward power prices reversed much of the prior week’s increase, led by declines of nearly $10 per MWh in PJM and more than $6 per MWh in MISO.

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The fundamental picture remains relatively comfortable despite periods of intense summer heat. Recent storage data has shown that the market is maintaining healthy inventory growth, with weaker-than-expected gas-fired generation so far this season. With production remaining strong, Freeport LNG maintenance reducing feedgas demand and sustained heat still absent from the longer-range forecast, the market continues to lack a clear bullish catalyst for a rebound.

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Natural gas futures have shifted into a lower trading range as storage inventories remain healthy, power-sector demand continues to underperform expectations, and LNG maintenance adds to domestic supply. This update examines the growing influence of renewable generation, recent storage trends, and increasingly attractive pricing across the Winter 2026–27 strip.

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The selloff came despite a storage report that showed a smaller injection and a meaningful week-over-week tightening in the fundamental balance. The 41-Bcf build was roughly in line with expectations but lighter than historical benchmarks, narrowing the surplus to the five-year average and widening the deficit to last year. The implied tightening was largely driven by stronger natural gas-fired generation as wind output dropped sharply during the report week, offsetting the impact of generally milder temperatures. Even so, the market appears more focused on the lack of sustained heat in the forecast, relative weakness in power generation demand, and the broader expectation that inventories will remain comfortable through the balance of the injection season.

An archive of Daily Natural Gas Market Notes can be found here.

After three straight weeks of materially exceeding expectations, today’s storage report showed a 41-Bcf injection that was roughly in line with consensus forecasts. The build came in marginally lighter than historical benchmarks for the same week, widening the deficit to 2025 by 6 Bcf and narrowing the surplus to the five-year average by 4 Bcf. This represents the smallest net injection since late March, during the initial phase of the injection season.

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Attention now turns to tomorrow’s storage report, with the Wall Street Journal survey pointing to a 44-Bcf injection for the week ended July 10. That would be nearly in line with the five-year average build of 45 Bcf, leaving the surplus largely unchanged at 184 Bcf. Although weather was relatively mild during the report week, wind generation output fell sharply, increasing the need for gas-fired power and likely contributing to a lighter build than the week prior. Analyst estimates range from 33 Bcf to 52 Bcf, while inventories are expected to remain 18 Bcf below year-ago levels.

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Tomorrow could be the hottest day of the summer so far on a population-weighted basis. Peak load in PJM is currently forecast to reach 164 GW, which would approach all-time record levels. During the previous heat wave in June, power generation demand for natural gas came in lower than expected due to strong wind output in the Midwest and Texas. Recent summers have featured several days when generation demand spiked above 50 Bcf per day, but that threshold has not yet been crossed this season. If gas demand again disappoints amid extreme heat in the coming days, it could prompt the market to further reassess seasonal fundamental risk.

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Temperatures are expected to briefly warm to extremes across the Midwest and East this week, but the heat does not appear likely to linger. Forecasts turn cooler again beyond the near-term window, reducing the chances of an extended surge in cooling demand. With Freeport LNG maintenance also weighing on feedgas demand and inventories maintaining a healthy surplus to the five-year average, the market remains firmly focused on increasingly loose near-term fundamentals.

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• Natural gas futures broke decisively below the recent trading range as bearish storage data and reduced LNG demand shifted market sentiment. The August 2026 NYMEX contract fell $0.26 to $2.94 per MMBtu, while Summer ’26 dropped $0.22 to $2.92.

• The EIA reported a 61-Bcf storage injection covering the hottest week of the summer, expanding the surplus to the five-year average to 185 Bcf.

• Balance-of-2026 forward power prices spiked in PJM and MISO, rising by more than $10 and $9 per MWh, respectively, even as ERCOT pricing moved sharply lower.

• Freeport LNG began major maintenance that is expected to reduce feedgas demand by roughly 1 Bcf per day through the remainder of peak summer.

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Thursday’s bearish sentiment carried over into trading ahead of the weekend. With no extended heat on the horizon, the market remained focused on impending feedgas reductions due to maintenance at Freeport LNG and the implications of Thursday’s storage report. Liquefaction demand at Freeport was reduced by about 1 Bcf per day on Friday compared with recent levels, with similar disruptions expected to persist through August. Meanwhile, Thursday’s storage report, which covered the hottest week of the year so far, still showed an expanding surplus and healthy inventory growth. The data indicates that power generation demand may not spike as high as previously estimated during subsequent hot-weather events, especially if Texas continues to be spared from major heat.

An archive of Daily Natural Gas Market Notes can be found here.

The natural gas market was hit with a wave of bearish news today, with the EIA Weekly Natural Gas Storage Report showing a larger than expected build of 61 Bcf into inventories for the week ending July 3. That storage addition outpaced market expectations by nearly 10 Bcf, suggesting a looser supply/demand balance than the market had anticipated.

Additionally, news that Freeport LNG would begin “major maintenance turnaround work” on Friday, July 10 further pressured prices lower as the market discounted lower LNG feedgas levels. To cap off the bad news, the mid-day American weather forecasting model run (the GFS Ensemble) showed a reduction in the cooling demand expected next week, suggesting lower natural gas demand for power generation.

Looking ahead, the market is likely to remain focused on how temperature forecasts evolve for the rest of the summer. So far this season, Texas has been spared any extreme heat, while the Midwest and East have seen intense but short-lived heat events. If that pattern persists through July and into August, the natural gas market may need to begin adjusting end-of-season storage expectations higher.

An archive of Daily Natural Gas Market Notes can be found here.

This morning’s storage report showed an unexpectedly large build into underground inventories. The reported 61-Bcf injection came in stronger than consensus expectations while also outpacing historical benchmarks for the same week. This marked the second consecutive build to exceed the same week in 2025, following a streak of nine straight weeks of lagging that benchmark. The deficit to last year has narrowed to just 15 Bcf, while the surplus to the five-year average expanded to 185 Bcf, its highest level since September 2025.

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