Market status — August 11, 2026
Emergency
Elevated
Watch
Normal
PJM — Capacity costs at ceiling; extreme heat could trigger demand response deployment
- 5CP Capacity Tags: 2026/27 Base Residual Auction closed at $325/MW-day price collar—record high for second consecutive year. Summer peak demand forecasted to rise with potential extreme heat; if realized, NERC expects PJM will need to deploy demand-response resources to manage load.
- Real-Time LMP: Real-time pricing continues standard operations across Western Hub, Northern Illinois, and AEP-Dayton zones. Heat-driven congestion could spike LMPs in transmission-constrained areas.
- Demand Response: DR resources expected to be critical if temperatures reach forecast extremes; no emergency activations reported to date, but monitoring heightened through August.
NYISO — Northeast grid under stress; ICAP prices remain elevated
- ICAP Tag Tracking: New York ICAP market operating within normal parameters. UCAP certification processes ongoing for summer months. Northeast capacity remains tight as part of broader regional constraints.
- CBEP Program Alerts: Customer Benefit Emergency Participation program active but no emergency calls to date. Program standing ready if grid stress escalates.
- Day-Ahead Pricing: Capacity market reflects elevated resource scarcity across Northeast region. NYC and Long Island zones showing typical summer spread patterns.
ERCOT — 4CP season active with extreme heat potential; August peak demand expected
- 4CP Season Tracking: ERCOT’s four-month 4CP window (June-September) is in full swing. August traditionally marks peak demand season. Summer 2026 outlook forecasts potential extreme heat combined with significant load growth—conditions that could surpass ERCOT’s all-time summer peak.
- ORDC Pricing: Operating Reserve Demand Curve pricing reflects normal summer levels. Extreme heat events could rapidly activate ORDC adders; watch for any Weather Watch or Watch declarations from ERCOT.
- Grid Condition Alerts: No Conservation or Emergency Alerts issued as of August 11. ERCOT monitoring weather forecasts closely; above-average temperatures and 61% probability of El Niño conditions present elevated risk of grid stress by late August.
ISO-NE — Elevated risk designated for August-September extreme conditions
- FCM Tag Events: Forward Capacity Market operating within normal summer certification cycle. New England explicitly identified by NERC as “elevated risk” for meeting once-in-a-decade extreme load conditions in August and September 2026.
- Capacity Market Integration: 2026-27 capacity auction completed; resources deemed adequate for normal operations but thin margin for extreme scenarios. Regional interconnection with neighboring utilities under scrutiny.
- Load Forecasting: August is historically ISO-NE’s second-highest peak demand month (after winter). Load forecasts show expected peaks within normal ranges, but extreme heat could exceed capacity margins.
MISO — Adequate capacity; soft pricing reflects supply surplus
- Zonal Pricing: 2026/27 PRA cleared at $116-126/MW-day across MISO zones—down 42% from prior year. Abundant solar capacity (12.2 GW added, up 59%) is moderating summer pricing. No zone-level congestion alerts.
- Planning Resource Auction: 2026/27 PRA demonstrated sufficient capacity at regional, subregional, and zonal levels. Summer pricing of $384-424/MW-day reflects adequate resource stack and eased scarcity.
- Real-Time Settlements: Standard RT settlement intervals; no unusual make-whole payments or dispatch anomalies reported.
CAISO — Summer season active; flex alert procedures positioned for potential deployment
- Flex Alerts: No Stage 1, 2, or 3 Flex Alerts issued as of August 11. CAISO grid operating within normal summer parameters. Procedures updated effective May 26, 2026; program funding extended through 2026 and positioned for rapid deployment if needed.
- Renewable Curtailment: Solar and wind resources performing within forecast ranges for August. No structural overgeneration events reported; typical midday solar peak management in place.
- NQC Integration: Net Qualifying Capacity filings current. Resource adequacy position reflects stable inventory with anticipated strong solar production through August.
Cross-Market Watch — NERC alerts and extreme heat risk
- NERC Critical Reliability Alert: NERC issued a Level 3 alert focused on unpredictable large loads, particularly data center demand. All NERC registered entities required to respond by August 3, 2026. This reflects emerging demand-forecasting challenge as computational loads behave differently than traditional electricity consumption.
- Extreme Heat and Weather Risk: NOAA forecasts above-average temperatures across much of the U.S. through August 2026. 61% probability of El Niño conditions, 1-in-4 chance of strong El Niño later this year, elevating risk of persistent extreme heat. August U.S. electricity demand expected to peak at 426 TWh (5% higher than August 2025).
- Regional Resilience: Three U.S. regions identified at elevated risk by NERC: New England and Northwest explicitly flagged for August-September. Northwest elevated risk specifically occurs in August-September window. Overall grid has added 58 GW of new capacity since summer 2025, easing year-over-year pressure.
HOW INTELLASTAR ENERGY ANALYST CAN HELP
Today’s conditions create specific opportunities—and risks—for your organization.
Extreme heat and all-time peak risk require aggressive 4CP demand response strategy
ERCOT’s August demand could exceed all-time summer peak if forecasted extreme heat materializes. Intellastar Energy Analyst tracks your organization’s 4CP exposure in real time and models demand-response dispatch scenarios to minimize summer transmission charges while maintaining operational resilience.
NERC elevated-risk designation means once-in-a-decade heat could stress your power supply this August
New England explicitly flagged by NERC for elevated risk in extreme scenarios through September. Intellastar Energy Analyst integrates real-time grid stress metrics with your facility load profiles to recommend dynamic demand-response positioning and procurement strategies now.
Record-high capacity costs and expected demand-response deployment signal peak-season opportunity
PJM’s 2026/27 capacity auction hit the $325/MW-day price collar—record high for a second year. NERC expects extreme heat will trigger DR deployment. Intellastar Energy Analyst helps you quantify DR value, optimize enrollment across programs, and coordinate dispatch timing for maximum revenue impact.