Energy Market Daily Digest — August 19, 2026

Market status — August 19, 2026

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PJM — Shoulder-season load, but the 5CP window stays open through September

• 5CP Capacity Tags: Load is running far below peak territory. PJM was serving roughly 86,574 MW on Aug. 16, versus the 156,400 MW summer forecast and the all-time 168,158 MW peak set July 2. Four of the five likely coincident peaks were probably set during the July heat waves, but the window runs through September, so a late-August or September heat return could still displace a lower-ranked peak day (PJM Inside Lines).
• Real-Time LMP: No spike, congestion or negative-pricing events reported at Western Hub, NI Hub or AEP-Dayton in the last 24 hours. With loads near 55% of the summer peak, hub spreads are compressed.
• Demand Response: No DR dispatch or emergency activation. For context on what a called event looks like, PJM logged roughly 6,113 MW of DR performance on July 2 and 5,037 MW on July 3 during emergency procedures (PJM Inside Lines).

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NYISO — Quiet operationally, active on the interconnection rulebook

• ICAP Tag Tracking: No UCAP tag revisions or off-cycle auction results posted. The Summer Capability Period is running normally, and demand curve reset methodology work remains in the stakeholder process rather than at a decision point (NYISO).
• CBEP Program Alerts: No Customer Benefit Emergency Participation alerts or activations issued.
• Day-Ahead Pricing: No unusual zonal spreads flagged for NYC, Long Island or Capital. The notable development is regulatory: New York moved yesterday to change tariff rules for distributed energy interconnection, which over time affects how behind-the-meter resources qualify (RTO Insider).

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ERCOT — Reserves deployed two evenings ago and a generation trip yesterday morning

• 4CP Season Tracking: The 4CP window is open and August is the third of four settlement months. August load has already touched 83,645 MW (Aug. 7 at 13:16), so afternoon peaks this month remain live candidates for a coincident peak interval (ERCOT Operations Messages).
• ORDC Pricing: Reserves tightened enough on Aug. 17 that ERCOT deployed roughly 308 MW of Non-Spin at 19:30, holding it until a full recall at 22:20. Evening-hour reserve pressure matches ERCOT’s own August outlook, which put the highest EEA probability at hour-ending 22:00 (ERCOT MORA, August 2026).
• Grid Condition Alerts: No Weather Watch, Watch, Warning, Emergency or Conservation Alert is active. ERCOT did report a sudden loss of 656 MW of generation on Aug. 18 at 05:57, with frequency dipping to 59.961 Hz at 60,414 MW of load, and ran a DC Tie Curtailment Notice on the East tie the prior evening (ERCOT Operations Messages).

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ISO-NE — Large-load rules take shape as capacity auction reform advances

• FCM Tag Events: No qualification events, de-list bid deadlines or show-cause notices in the last 24 hours. ISO-NE did outline its proposed treatment of large loads yesterday, the substance of which will shape how data centers and flexible load interact with capacity obligations (RTO Insider).
• Capacity Market Integration: The 2026-27 commitment period began June 1 on FCA17 obligations of 31,370 MW. FERC accepted the first phase of capacity auction reform on March 30, and the second phase filing is still expected in the fourth quarter, moving the region toward a prompt, seasonal auction (ISO-NE).
• Load Forecasting: No peak-load advisory or above-normal demand notice for today or the balance of the week.

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MISO — Comfortable margins after a sharply cheaper capacity auction

• Zonal Pricing: No notable LMP dislocation across Zones 4 through 7 and no binding transmission constraint worth flagging in the last 24 hours.
• Planning Resource Auction: The 2026-27 PRA cleared with sufficient capacity and materially lower prices. Summer fell to $424.30/MW-day in North and Central, $384.10 in Arkansas and Mississippi, and $412.10 in Louisiana and Texas, down from $666.50 region-wide a year earlier. Annualized, all ten zones now sit between roughly $116 and $126/MW-day, versus $212 to $217 last year, and the auction cleared 3.5% above the 7.9% summer planning reserve margin target (MISO).
• Real-Time Settlements: Nothing unusual reported in settlement intervals or make-whole payments.

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CAISO — No alerts, but midday oversupply remains the standing condition

• Flex Alerts: No Flex Alert or emergency notification is active, and no DR call-outs have been issued (CAISO).
• Renewable Curtailment: Curtailment is structural rather than event-driven. CAISO curtailed 600,081 MWh of combined wind and solar in June 2026, and the same midday oversupply pattern continues to shape net-load ramps into the evening peak (CAISO Key Statistics).
• NQC Integration: No RA deficiency notices or NQC revisions posted. A report released yesterday argues California should simplify its overlapping programs to unlock more flexible load, which is directly relevant to anyone weighing DR enrollment across CAISO and utility programs (RTO Insider).

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Cross-Market Watch — Every RTO is rewriting its large-load rules at once

• FERC show cause proceedings: FERC issued Federal Power Act section 206 show cause orders on June 18 to all six jurisdictional grid operators, directing each to justify or reform tariffs governing how data centers and other large loads connect. The orders cover cost-shift protection, co-location and behind-the-meter generation, and new transmission services for flexible loads (FERC).
• Timeline slipping: Every ISO and RTO has asked FERC for an additional three months on the 60-day compliance deadline, so the substantive filings that will reshape large-load and co-location economics are now likely to land in the fourth quarter rather than this month (RTO Insider).
• No reliability events: No NERC alerts, fuel supply disruptions or multi-region heat events are in effect. Weather is not the story today; the rulebook is.

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