Natural Gas & LNG Tracker
America's dominant fuel generates ~43% of US electricity. Production at record highs, LNG exports above 100 million tons, and new gas plants under development for data centers. The emissions debate continues.
Last updated: March 2026 · Sources: EIA, Reuters, IEA, Global Energy Monitor
01. Henry Hub Price Tracker
The Henry Hub in Erath, Louisiana is the pricing benchmark for US natural gas. After hitting an inflation-adjusted record low in 2024 ($2.26/MMBtu average), prices recovered in 2025, but remain historically cheap compared to pre-shale-revolution levels.
Natural gas prices are highly seasonal. Cold snaps increase demand for both direct heating and gas-fired electricity generation. Northeast hubs are especially volatile: Algonquin Citygate near Boston hit $16.37/MMBtu in January 2025 due to pipeline constraints. The rest of the country sees much milder swings.
Bullish: Record LNG export demand, surging data center electricity load, cold winters.
- SoftBank + AEP: 9.2 GW gas plant at former Portsmouth uranium site, OH — $33B (March 2026)
- Texas: 80.6 GW of gas capacity under development, 40 GW earmarked for data centers
- DOE issued Section 202(c) emergency orders to keep Indiana coal running through June 2026
Bearish: Record production levels (~109 Bcf/d forecast for 2026, per EIA STEO Jan 2026), continued efficiency gains, renewable energy displacing gas in shoulder months.
02. The Gas Paradox
Natural gas is simultaneously the hero that killed coal and the villain that locks in fossil fuel dependence. Both narratives are true, and that makes gas the most debated fuel in the energy transition.
- Coal killer: Gas displaced coal from ~50% of US generation (2005) to ~16% today. This is the single largest driver of US emissions reductions.
- Half the CO₂: Gas produces roughly 50% less CO₂ per MWh than coal when burned for electricity.
- Flexible partner: Gas plants can ramp up and down quickly, backing up intermittent solar and wind when the sun doesn't shine or wind doesn't blow.
- Bridge fuel: Gas provides reliable baseload while nuclear, storage, and renewables scale up over the next 20+ years.
- Energy security: US gas exports (LNG) help Europe and Asia reduce dependence on Russian and Middle Eastern energy.
- Cheap power: Abundant shale gas keeps US electricity prices among the lowest in the developed world.
- Still fossil: Gas is a fossil fuel. Burning it produces CO₂, just less than coal. Net-zero requires eventually eliminating it.
- Methane leaks: Methane is 80× more potent than CO₂ over 20 years. Leaks during production, transport, and processing may erase much of gas's CO₂ advantage over coal.
- Lock-in risk: New gas plants have 30–40 year lifespans. Building them now commits to fossil generation through 2060+.
- Crowding out renewables: Cheap gas can undercut the economics of solar, wind, and storage investment.
- Stranded asset risk: As renewables + storage get cheaper, gas plants may become unprofitable before their expected end of life.
- Actual emissions 4× higher: MethaneSAT data shows US oil & gas methane emissions are over 4× higher than EPA estimates.
The math isn't simple. If methane leakage rates are below ~3%, gas is significantly better than coal for the climate. If they're above ~3%, the advantage shrinks dramatically. Current best estimates put US oil & gas methane leakage at 2–3% of total production, right at the tipping point. The IEA says almost all methane emissions from oil & gas could be eliminated with known technologies at modest cost, but the industry has been slow to act.
03. The Gas Plant Boom
Data centers are driving the biggest wave of new gas plant construction in decades. In 2025, the US saw 97+ GW of gas-fired capacity proposed specifically for data center power, up from just 4 GW in 2024. Texas alone added 58 GW to its development pipeline.
Texas added 58 GW of new gas power projects to its development pipeline in 2025 alone, more than the peak power demand of the entire state of California. The Permian Basin is ground zero: companies plan to build massive gas plants directly co-located with data centers, using associated gas from oil production.
The most jaw-dropping: Pacifico Energy's GW Ranch project in Pecos County, a 7.65 GW gas-fired power plant and data center complex that just received the nation's largest air pollution permit. At full capacity, it would consume 1–2 billion cubic feet of gas per day.
| Project / Developer | Location | Capacity | Status | Notes |
|---|---|---|---|---|
| GW Ranch (Pacifico Energy) | Pecos County, TX | 7.65 GW | Permitted | Nation's largest air permit; gas plant + data center complex |
| NextEra + ExxonMobil JV | Texas | 1.2 GW | Announced | Part of NextEra's 15 GW data center plan by 2035 |
| Entergy (for Meta Hyperion) | South Central US | 2.2 GW | Under Construction | Three new gas plants to power Meta's Hyperion data center campus |
| Talen Energy Expansion | Pennsylvania | ~1 GW | Planned | Adjacent to Susquehanna nuclear; gas backup for data center load |
| Various Texas Permian projects | West Texas | 58 GW pipeline | Various | Multiple developers rushing to build in the Permian oil patch |
Reliability: AI workloads need 99.999% uptime. Gas plants provide firm, dispatchable power that solar and wind can't guarantee.
Speed: Gas plants can be built in 2–3 years. Nuclear takes 10+. Renewables + storage at data center scale take time to permit.
Co-location: Building behind-the-meter means bypassing grid interconnection queues that can take 5+ years.
Climate impact: Locking in 30–40 years of gas generation contradicts net-zero goals. The Guardian calls it "hard-wiring decades of pollution."
Air quality: Communities near new plants face NOx, PM2.5, and other pollutants. Environmental justice concerns are rising.
Stranded assets: If AI demand doesn't materialize as projected, or renewables undercut gas economics, these plants could become stranded.
04. LNG Exports: World's Largest Exporter
In 2025, the United States became the first country ever to export more than 100 million metric tons of LNG in a single year, reaching 111 million metric tons. US LNG export capacity is set to more than double by 2029.
Operating LNG Export Terminals
| Terminal | Location | Operator | Capacity | Status |
|---|---|---|---|---|
| Sabine Pass | Cameron Parish, LA | Cheniere Energy | ~4.7 Bcf/d (6 trains) | Operational |
| Cameron LNG | Hackberry, LA | Sempra/TotalEnergies | ~2.1 Bcf/d | Operational |
| Freeport LNG | Freeport, TX | Freeport LNG Dev. | ~2.4 Bcf/d | Operational |
| Corpus Christi | Corpus Christi, TX | Cheniere Energy | ~2.5 Bcf/d (+ Stage III) | Operational |
| Elba Island | Savannah, GA | Southern LNG/Kinder Morgan | ~0.35 Bcf/d | Operational |
| Cove Point | Lusby, MD | Berkshire Hathaway | ~0.82 Bcf/d | Operational |
| Calcasieu Pass | Cameron Parish, LA | Venture Global | ~1.5 Bcf/d | Operational |
| Plaquemines LNG | Plaquemines Parish, LA | Venture Global | 2.6 Bcf/d (full build) | Ramping Up |
Under Construction / Approved
| Terminal | Location | Operator | Capacity | Expected |
|---|---|---|---|---|
| Golden Pass LNG | Sabine Pass, TX | ExxonMobil / QatarEnergy | 2.4 Bcf/d (18 MTPA) | 2026 |
| Corpus Christi Stage III | Corpus Christi, TX | Cheniere Energy | ~1.5 Bcf/d | Shipping cargoes |
| Port Arthur LNG | Port Arthur, TX | Sempra | ~1.7 Bcf/d | 2027–2028 |
| Rio Grande LNG | Brownsville, TX | NextDecade | ~2.4 Bcf/d | 2027–2028 |
| CP2 LNG | Cameron Parish, LA | Venture Global | ~2.8 Bcf/d | Approved |
US LNG exporters have announced plans to add an estimated 13.9 Bcf/d of new liquefaction capacity between 2025–2029, according to the EIA. This would more than double current North American LNG export capacity. The combined new projects under construction have 5.3 Bcf/d of nominal capacity (up to 6.3 Bcf/d peak).
Europe: After Russia's invasion of Ukraine, Europe rapidly shifted to US LNG. In December 2023, 87%+ of US LNG went to the EU, UK, or Asian markets.
Asia: Japan, South Korea, and increasingly China and India are major buyers. US LNG provides an alternative to pipeline gas from Russia and the Middle East.
Energy diplomacy: LNG has become a geopolitical tool, deepening US influence in global energy markets.
Biden (Jan 2024): Paused all pending LNG export approvals to non-FTA countries, citing environmental review. Industry and allies called it a "ban."
Federal judge (July 2024): Reversed the pause, ruling DOE overstepped.
Trump (Jan 2025): Formally ended the pause on Day 1 via executive order. DOE returned to "regular order" on export reviews as part of the "energy dominance" agenda.
05. The Methane Problem
Methane is natural gas's Achilles heel. It's 80× more potent than CO₂ as a greenhouse gas over 20 years. New satellite data reveals emissions are far worse than previously thought, and the rules keep changing.
Satellite Monitoring Revolution
Regulatory Landscape
| Regulation | Agency | Status | Details |
|---|---|---|---|
| EPA Methane Rule (OOOOb/c) | EPA | Finalized 2024 | Most comprehensive US methane regulations ever. Requires leak monitoring, plugging, and reporting for oil & gas operations. |
| Super Emitter Program | EPA | Extended to 2027 | Third-party certified monitors (satellite, aircraft, mobile) can report super-emitter events. Deadline extended via 2025 interim rule. |
| Methane Emissions Fee | EPA (IRA) | In Effect 2025 | $900/ton fee on excess methane emissions from large facilities. First fees assessed for 2024 emissions. |
| Global Methane Pledge | International | Voluntary | 150+ countries pledged to cut methane 30% by 2030 from 2020 levels. Progress uneven. |
The Trump administration has signaled skepticism toward methane regulations. The Super Emitter Program deadline was extended to 2027. Industry groups are challenging the methane fee in court. Whether these regulations survive the current political environment is one of the biggest uncertainties in US climate policy.
Meanwhile, the IEA says nearly all methane emissions from oil and gas could be eliminated with known technologies, often at low or even negative cost (capturing leaked gas = selling it). The gap between what's technically possible and what's actually happening is enormous.
06. Pipeline Infrastructure
The US has over 3 million miles of natural gas pipelines, but constraints in key regions create bottlenecks, price spikes, and political battles. The Mountain Valley Pipeline saga illustrates everything about modern energy infrastructure fights.
The Mountain Valley Pipeline (MVP) is a 303-mile gas pipeline from northwestern West Virginia to southern Virginia. What should have been a routine project became one of the most contentious energy infrastructure fights in US history:
2017: FERC issued the original construction certificate.
2017–2023: Years of legal challenges, permit revocations, and construction delays. Environmental groups sued repeatedly over water crossings, endangered species, and erosion.
June 2023: Congress intervened, the Fiscal Responsibility Act (debt ceiling deal) required all federal permits to be issued by June 24, 2023, and stripped courts of jurisdiction to review them.
June 2024: FERC authorized the pipeline to be placed in service. Gas began flowing.
2025: Operating, but flowing only ~750 MMcf/d, well below its 2 Bcf/d capacity, due to downstream constraints on the Transco pipeline system that won't be resolved until ~2027.
Key Pipeline Constraints & Developments
| Region | Issue | Impact |
|---|---|---|
| Northeast (New England) | Severe pipeline capacity constraints, no new major pipelines built in decades | Winter price spikes of $15–20/MMBtu; region imports LNG from overseas despite sitting near Marcellus Shale |
| Permian Basin → Gulf Coast | New pipelines being built to feed LNG export terminals | Plaquemines LNG and other terminals reshaping flow patterns across TX/LA Gulf Coast |
| Appalachia (Marcellus/Utica) | World's largest gas field, but limited takeaway capacity to East Coast markets | Producers face basis differentials; MVP helps but downstream constraints limit impact until 2027 |
| Transco System (Southeast) | Debottlenecking projects needed to handle MVP + growing demand | Full MVP flows won't be possible until ~2027 Southeast Supply Enhancement project |
| Pacific Northwest | Ample Canadian supply from Montney shale | Northwest Sumas prices actually fell in 2025: $0.24/MMBtu lower than 2024 |
MVP took 7 years from FERC certificate to first gas flow, and that was with a literal act of Congress. Other proposed pipelines have been cancelled entirely (Constitution Pipeline, PennEast). The combination of state-level opposition, environmental litigation, and federal permitting delays has made building new interstate gas pipelines nearly impossible in much of the Eastern US.
This creates a paradox: the Northeast burns expensive imported LNG while sitting on the world's largest gas field (Marcellus Shale) just a few hundred miles away. Pipeline constraints, not gas supply, are the bottleneck.