What’s moving the
markets now.

The through-line across the grid this week is simple: the load coming for data centers is being met with gas, and it is being locked in now. Gas took nearly half of PJM's first reformed interconnection queue, the PPL-Blackstone venture secured 5 GW of turbines for Pennsylvania sites, and NRG is closing on a 1.2 GW customer-backed plant in Texas. That is a lot of firm, dispatchable capacity being committed against demand that has not fully arrived yet.

For suppliers and marketers, the takeaway is directional pressure on power prices. More firm load queued against a fleet that is still retiring older units keeps the supply-demand balance tight, and PJM's move to rewrite ride-through standards after 3.8 GW of data center load tripped offline in a single event underlines how fragile that balance is at the margin. When large loads drop unexpectedly, the reliability response gets baked into future capacity and ancillary costs. Hedge the forward curve accordingly and watch capacity auctions for the next leg up.

Supply is winning the gas story right now. EIA's August outlook has US marketed production averaging a record 122.5 Bcf/d in 2026, and the agency cut its 3Q Henry Hub call 50 cents to $2.87/MMBtu, citing that output plus softer LNG feedgas while Freeport sits down for maintenance. It now expects storage to reach a record 3,985 Bcf by the end of October, roughly 5% above the five-year average and the fattest cushion into winter since 2016.

The one counterweight is that weekly builds are running lean: the 33 Bcf injection for the week ended July 31 lifted stocks to 3,117 Bcf but came in under the normal seasonal pace as heat kept power burn high. That trims the surplus at the edges without changing the picture. For marketers, the message is that the prompt and near-curve stay heavy and prices are likely capped under $3 into November, but the lean injection pace is worth watching, because if power burn stays elevated the surplus can erode faster than the headline storage number suggests.

Storage is scaling faster than almost anything else on the grid. EIA puts US utility-scale battery capacity at nearly 52 GW by mid-2026, up from 43.6 GW at the end of 2025, growing near 70% a year with another 14 GW due before year end. Batteries charge on cheap midday power and discharge into the evening peak, which is precisely when scarcity pricing shows up, so every gigawatt added shaves a little more off the top of the peak.

That matters for the book in two ways. First, it is a soft bearish force on peak power prices even as firm load grows, which partly offsets the gas-fired buildout above. Second, the politics are catching up: Texas senators are floating gas build minimums specifically because renewables and storage now dominate the ERCOT queue. For suppliers, the operational reality is that peak shape is flattening in the highest-price hours, and any hedging or shaping strategy that assumes yesterday's peak profile is leaving value on the table.