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Kinder Morgan reported Q2 earnings of $0.37 a share, topping the $0.31 consensus estimate by 19%, according to Zacks Investment Research. "The results reflect continued strength in natural gas demand across our pipeline network," the company said in its earnings release. Earnings rose 32% from $0.28 per share in the same period a year ago. Revenue figures for the quarter were not yet disclosed. The Houston-based midstream operator benefited from higher natural gas transport volumes, driven by rising power generation demand and LNG export activity. Natural gas consumption in the US power sector has climbed as utilities add gas-fired capacity to support data center growth and electrification. | Metric | Actual | Consensus | Beat/Miss | |--------|--------|-----------|-----------| | EPS | $0.37 | $0.31 | +$0.06 | | Revenue | not yet disclosed | not yet disclosed | — | The beat marks the second consecutive quarter of upside for KMI, which operates about 83,000 miles of pipeline across North America. The company's performance aligns with broader strength in the midstream energy sector, where rising natural gas consumption for data center power and industrial use has boosted throughput volumes. Peer pipeline operators including Williams Companies and Energy Transfer have also reported higher transport volumes this earnings season. The earnings beat shows that Kinder Morgan's core pipeline assets continue to generate strong cash flow as natural gas demand remains elevated. Investors will watch for updated full-year guidance and commentary on LNG export project timelines on the company's earnings call. This article is for informational purposes only and does not constitute investment advice.
Artificial intelligence data centers will push U.S. natural gas demand to levels that outpace supply growth, creating a deficit the market is not prepared for, according to Chronometer Partners' Matthew Smith. "The scale of electricity demand from AI data centers is unlike anything the natural gas market has seen," Smith, a partner at Chronometer Partners, said. "Investors are underestimating how quickly this will tighten the supply-demand balance." U.S. natural gas consumption from power generation is projected to rise by more than 10 billion cubic feet per day by 2030 as data centers ramp up operations, according to industry estimates cited by Smith. That incremental demand is equivalent to roughly 10% of current total U.S. natural gas production of about 103 Bcf per day, per the Energy Information Administration. The U.S. has added more than 30 gigawatts of data center capacity over the past three years, with another 40 GW under construction, according to McKinsey & Co. The stakes are significant for energy markets and the broader economy. A sustained natural gas deficit would push Henry Hub prices higher, raising electricity costs for industrial and residential consumers at a time when the Federal Reserve is still battling inflation. The last time natural gas prices spiked above $6 per million British thermal units in 2022, the U.S. saw a 12% increase in wholesale electricity costs, according to EIA data. Smith argues the current trajectory could produce a similar or larger price shock. **Why AI data centers are reshaping gas demand** Each gigawatt of data center capacity requires roughly 200 million cubic feet of natural gas per day to generate the electricity needed for round-the-clock operations, Smith estimates. With AI workloads requiring far more computing power than traditional cloud applications, the energy intensity per data center has climbed sharply. Nvidia's latest GPU architecture, for example, draws up to 1,200 watts per chip, compared with roughly 300 watts for conventional server processors, according to the company's published specifications. The U.S. Energy Information Administration projects natural gas will account for about 38% of U.S. electricity generation through 2026, making it the primary fuel source for the data center buildout. Renewable sources such as solar and wind, while growing rapidly, cannot yet provide the 24/7 baseload power that data centers require, leaving natural gas as the default bridge fuel. **Three stocks positioned for the supply crunch** Smith recommends three companies that stand to benefit from the tightening gas market. The first is EQT Corp., the largest U.S. natural gas producer by volume, which has the scale to ramp up output quickly as prices rise. The second is Cheniere Energy Inc., the leading U.S. liquefied natural gas exporter, which can capture premium pricing from both domestic and international markets. The third is Kinder Morgan Inc., the largest midstream natural gas pipeline operator in North America, whose infrastructure assets become more valuable as throughput volumes increase. EQT produced about 1.8 Bcf per day in the first quarter of 2026, according to company filings, giving it direct leverage to Henry Hub prices. Cheniere's Sabine Pass and Corpus Christi terminals have a combined liquefaction capacity of about 45 million tonnes per year, making it a key conduit for U.S. gas exports. Kinder Morgan operates roughly 80,000 miles of pipeline, transporting about 40% of the natural gas consumed in the U.S. The warning from Chronometer Partners comes as the AI arms race among technology companies accelerates capital spending. Microsoft, Amazon, Google and Meta Platforms are expected to spend a combined $200 billion on data center infrastructure in 2026, according to estimates from Dell'Oro Group, up from about $150 billion in 2025. That spending trajectory suggests the natural gas demand pressure will intensify through the end of the decade. *This article is for informational purposes only and does not constitute investment advice.*
**A pair of new pipelines has pulled Permian Basin natural-gas prices out of negative territory, but analysts warn the relief may be short-lived as planned drilling threatens to overwhelm the added capacity.** The Permian Basin's natural-gas prices climbed above zero in recent weeks after Kinder Morgan and Energy Transfer brought new pipeline capacity online, ending a first-half supply glut that forced producers to pay buyers as much as $7.95 per million British thermal units to take the fuel. "The big question is how quickly gas production grows into the new capacity," said Rob Wilson, president of energy data firm East Daley Analytics. "Gas tends to grow faster than crude in the Permian." At the region's Waha trading hub, gas prices averaged negative $2.19 per million British thermal units during the first six months of 2026, compared with $2.72 at the Henry Hub benchmark in Louisiana on the same day in late April when Waha hit its record low of negative $7.95. Diamondback Energy, one of the Permian's largest producers, sold oil for an average $96.82 a barrel in the quarter ended June 30 but fetched negative $2.15 per thousand cubic feet for its gas — and negative $0.34 even after hedging. The congestion threatens to constrain the Permian, which accounts for about 20 percent of U.S. gas production and has driven most of the domestic supply growth that kept prices low and stable in recent years. With the Strait of Hormuz closure keeping oil prices elevated and encouraging continued drilling, the basin could quickly refill the new pipelines before the next batch of egress comes online toward the end of the decade. The Kinder Morgan Gulf Coast Express expansion and Energy Transfer's 400-mile Hugh Brinson pipeline to the Dallas area have provided temporary relief, lifting Waha prices to about 40 percent below the national benchmark. A third conduit, the Blackcomb pipeline being built by a consortium including Targa Resources, is expected to add further egress when it opens later this year. **Pipeline Capacity Runs Ahead of Drilling Plans** Permian gas production grew at less than half the rate of the past few years during the first half of 2026, according to Bank of America analysts, as negative prices prompted some drillers to turn rigs away from gassier prospects. Devon Energy and APA curtailed output. But the curtailments suggest it will not take long to fill the new lines, Wilson said. "The gas is there," he said. "It's ready to hit the pipes." The Permian is unique in that producers typically underwrite drilling based on oil prices, treating the associated gas as a costless byproduct. That dynamic has created a high tolerance for low prices and situations where gas is treated more like a nuisance than a coveted fuel. Some drillers flare or vent the excess, though regulatory limits constrain how much they can burn. Producers are exploring ways to use more gas within the basin rather than risk having to pay buyers to take it away. Matador Resources last month touted savings from using its own well gas to run drilling equipment. Chevron said it would build a gas-fueled power plant in Reeves County to supply electricity to a large data center Microsoft has planned nearby. "It's arguably going to continue to get worse before it gets better as we think about the cadence of volume growth that we're seeing on our system and that we're seeing more broadly in the Permian and how that interplays with not enough takeaway capacity," Jennifer Kneale, president of Permian pipeline operator Targa Resources, told investors this spring. The consequences extend beyond Texas. Ample natural gas from the Permian has underpinned the artificial-intelligence boom by keeping electricity costs low for data centers, while also supporting U.S. energy exports through growing LNG shipments. If pipeline bottlenecks cap Permian output, those ambitions could face headwinds. This article is for informational purposes only and does not constitute investment advice.
**Kinder Morgan's $10.1 billion project backlog positions the pipeline giant to capture surging U.S. natural gas demand from LNG exports and data center power consumption.** Kinder Morgan Inc. is betting $10.1 billion on a structural shift in U.S. energy demand, with its project backlog concentrated on natural gas infrastructure to serve growing LNG exports and electricity consumption from data centers. "KMI's asset base is uniquely positioned to support LNG export growth along the Gulf Coast, particularly at the Texas and Louisiana hubs," said Jeremy Tonet, an analyst at JPMorgan who covers the midstream sector. "The backlog reflects a multiyear demand cycle that extends well beyond typical commodity price swings." The Houston-based midstream giant transports about 40% of U.S. natural gas across 78,000 miles of pipelines and operates 136 terminals with more than 700 billion cubic feet of working storage capacity. More than 60% of the $10.1 billion project pipeline is directed toward power generation and utility demand, while about 20% targets LNG export infrastructure. The backlog signals that Kinder Morgan expects the U.S. natural gas demand growth story to persist for years. Data center expansion, coal-fired power plant retirements, industrial reshoring and population migration to the Southern U.S. are all driving electricity consumption higher, boosting the need for gas-fired generation. If realized, the projects could convert these structural trends into predictable cash flows. The company's infrastructure is concentrated in regions that serve as gateways for LNG exports. The Gulf Coast, where Kinder Morgan operates extensive pipeline and storage networks, is home to multiple LNG export terminals that are expanding capacity to meet global demand. The U.S. is on track to become the world's largest LNG exporter, and midstream companies with existing infrastructure hold a competitive advantage over new entrants. The rise of artificial intelligence and cloud computing has added a new demand driver. Data centers require massive amounts of electricity, and natural gas has emerged as the primary fuel source for new power generation capacity in the U.S., given the slow pace of renewable energy interconnection and the retirement of coal plants. The Edison Electric Institute estimates that data center electricity consumption could more than double by 2030, creating sustained demand for gas-fired power. Kinder Morgan's business model provides downside protection. The company operates under long-term, fee-based contracts that generate stable cash flows regardless of short-term commodity price fluctuations. This structure allows the company to finance its $10.1 billion backlog with predictable revenue streams, reducing execution risk for investors. The last time Kinder Morgan reported a backlog of this magnitude was in 2014, when the shale boom drove a wave of pipeline construction across the Permian Basin and Marcellus Shale. That cycle added roughly 15% to the company's EBITDA over the following three years, according to company filings. The current backlog is more diversified, with exposure to LNG exports and power generation rather than just upstream production growth. Other midstream companies are pursuing similar strategies. Enbridge Inc. is expanding its natural gas storage facilities to capture data center demand, while Venture Global, one of the largest U.S.-based LNG exporters, is developing multiple export projects in Louisiana with a combined target capacity of about 68 million tons per annum. This article is for informational purposes only and does not constitute investment advice.