Whalesbook
Pipeline Bottleneck Sends Texas Gas Prices Negative
Natural gas prices at the Waha trading hub in West Texas have plunged to historic lows, trading below zero for next-day delivery. This means sellers are paying buyers to take gas, highlighting a severe shortage in the region's midstream infrastructure. Producers in the Permian Basin, accounting for about a quarter of U.S. natural gas output, are producing more gas than existing pipeline capacity can handle. Waha basis differentials to the benchmark Henry Hub have widened considerably, averaging $1.43/MMBtu below Henry Hub in September 2022 and even dropping over $5.00/MMBtu during past maintenance. Recent reports show daily cash prices at Waha near -$8/MMBtu, with monthly forward contracts settling over -$5.25/MMBtu, indicating a persistent problem. This oversupply and lack of transport is worsened because most Permian gas is 'associated gas,' produced alongside crude oil. Drillers therefore prioritize oil economics and keep producing regardless of gas prices.
Producers Still Pumping Amid Oil Boom, Gas Glut
Major Permian producers, including ExxonMobil (XOM), Chevron (CVX), ConocoPhillips (COP), Pioneer Natural Resources (PXD), and Diamondback Energy (FANG), continue strong operations despite negative gas prices. This is mainly due to high crude oil prices, influenced by global supply disruptions from the conflict in Iran, which pushed oil prices up more than 25%. This situation creates a mixed financial scenario. For example, ExxonMobil has a P/E ratio of about 24.1, Chevron's is around 30.4, ConocoPhillips's is 17.5, Pioneer Natural Resources's is 13.3, and Diamondback Energy's is 13.2. While these valuations suggest investor confidence, the negative gas prices directly reduce profits for companies heavily involved in the Permian's associated gas. When pipeline capacity is limited, capturing this gas is less incentivized, often leading to increased flaring. This practice, regulated by Texas Railroad Commission Statewide Rule 32, allows operators to flare gas for up to 180 days if they seek exceptions. Permian raw gas production has grown significantly, from about 5 Bcf/d in 2012 to around 25 Bcf/d by late 2023, far exceeding infrastructure development and worsening price issues.
Texas Glut Contrasts With Volatile Global Markets
The sharp drop in Texas gas prices is a stark contrast to the volatile global energy market. An attack on Qatar's liquefied natural gas (LNG) facility has tightened worldwide supplies, pushing up European gas prices and showing the delicate nature of international energy networks. The ongoing conflict in Iran adds to this instability, disrupting vital shipping routes like the Strait of Hormuz, through which about 20% of global oil and LNG trade passes. This global situation highlights how U.S. infrastructure problems can occur even as global demand struggles for reliable supply. The U.S. energy sector is vulnerable to unexpected disruptions, relying heavily on concentrated production, shipping bottlenecks, and centralized processing facilities.
Infrastructure Lag Creates Long-Term Risk
The ongoing lack of infrastructure creates significant risks. New pipeline projects like the Gulf Coast Express (GCX) expansion and the Matterhorn Express are planned, but many won't add substantial new capacity until the second half of 2026. This means Permian producers will likely face deeply negative basis spreads through 2026, potentially affecting investment and future production growth. Building the necessary infrastructure is a massive undertaking, with estimates suggesting $1 trillion in investment needed across North America by 2052. For companies with weaker finances or higher debt, extended periods of negative gas prices could strain their financial flexibility. Additionally, relying heavily on oil economics to justify gas production leaves these companies exposed to any major drop in oil prices, even with current high levels. Growing rig counts and production, despite pipeline limits, could lead to further price issues. Pipeline capacity will be the key factor determining Permian producers' profitability soon.
Demand Growth Hinges on New Pipeline Capacity
Analysts forecast significant growth in U.S. natural gas demand, driven by LNG exports and a rapidly expanding data center sector expected to absorb over 20 Bcf/d of new demand. Meeting this requires major midstream expansion. Projects like the GCX expansion adding 550 MMcf/d and the Matterhorn pipeline adding 2.5 Bcf/d are vital steps. However, building new pipelines is slower and more complex than drilling wells. Without substantial and timely infrastructure development, the Permian Basin's gas production growth could be limited, leading to ongoing price volatility and discouraging investment in gas drilling. The industry must address these midstream constraints to capture long-term demand growth and prevent repeated price issues.