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Two grids set demand records this month, and neither has the supply to match. ERCOT expects summer peak demand to top 92 GW, roughly 7.6% over the 85.5 GW record set in August 2023. PJM issued a Maximum Generation Alert as heat pushed forecasted peaks toward 164,078 MW, serving a preliminary 151,105 MW on July 14 while leaning on a DOE emergency order for backup generation.

The part that should stop you is the timing. The same week PJM was scrambling for peak supply, FERC Chairman Laura Swett said the RTO's latest capacity auction, which cleared nearly 7 GW short of the reliability target and drew just 500 MW of new resources, compounds the alarm bells. FERC holds a technical conference July 23 on PJM's slow, opaque governance. So demand is setting records while the mechanism meant to secure supply comes up short and draws federal scrutiny. For anyone carrying load in PJM or ERCOT, record demand against a widening capacity hole is not a one-summer problem. It is structural cost risk that shows up in every real-time spike and every capacity line item.

S&P Global says US feedgas demand for LNG will double to 36 Bcf/d within five years, making LNG the country's second largest net export industry by 2031, behind only aircraft. Then look at the tape. August futures just booked a third straight weekly loss. EIA reported a 41 Bcf injection for the week ended July 10, lifting Lower 48 storage past 3,024 Bcf, about 181 Bcf and 6.4% over the five-year average, with production near 111 Bcf/d and few heat risks into late July.

Both are true at once. The structural demand story is enormous, and the front of the curve is soft because supply keeps covering the heat and refilling storage. S&P even pegs the hit to household gas costs at just 1.6% through 2031, thanks to record production. For marketers, that gap is the opportunity, not a contradiction. A demand pull that size with supply still ample means more volume to move without blowing out Henry Hub. The near-term tape and the multi-year curve are telling two different stories, and a book positioned for only one of them is leaving money on the table.

Data center load is reshaping US power markets faster than anyone can build a gas plant. PJM's 2028/2029 auction pulled in just 525 MW of new supply against a 6,831 MW shortfall, and turbines are back-ordered for years. So watch where the near-term answer is actually coming from. It is not steel in the ground. It is flexibility.

New Jersey released a Virtual Power Plant straw proposal. In Pennsylvania, parties filed reply comments in the PUC's rulemaking on distributed energy resource aggregations, with lawmakers pushing for stronger final rules. Energy Risk reports interest in battery and flexibility contracts soaring as traders structure bespoke deals around them. The pattern is the same across markets: while utilities wait on hardware, regulators are writing the rules that let aggregated batteries, demand response, and distributed resources bid in as real capacity. The policy scaffolding for VPPs is going up ahead of the physical build. For suppliers and asset operators, distributed flexibility is moving from pilot to market product, and any capacity strategy that assumes you only clear with a new generator attached is working from last year's rulebook.