PDR monitors forward curves across all 17 deregulated electricity markets and natural gas pipelines daily. Our market intelligence informs every procurement recommendation we make — and we share it directly with clients.
Henry Hub prompt-month and 12-month strip. Seasonal storage reports, production data, and LNG export flows that move the curve.
On-peak and off-peak forward prices at major hubs: ERCOT HB North, PJM West, PJM AEP Dayton, NI Hub, Mass Hub, NYISO Zone A/G/J.
Local pipeline and LDC basis spreads versus Henry Hub. Regional supply/demand imbalances and pipeline capacity constraints that drive local price divergence.
PJM RPM and ISO-NE ICAP clearing prices. Capacity costs are set by annual forward auctions and can add $10–$40/MWh to all-in commercial rates depending on zone.
One email per month covering: forward curve movement, seasonal factors, capacity auction updates, and PDR's procurement timing recommendation for each major ISO. Written for commercial energy buyers — no jargon, no filler.
The following are illustrative examples of the kinds of market analysis we publish. Actual content is updated monthly based on current conditions.
Working gas in storage is running above the 5-year average following a mild shoulder season, putting downward pressure on prompt-month NYMEX. However, the Dec–Feb strip is pricing in normal winter demand and LNG export volumes that didn't exist in prior reference years. Fixed-price buyers locking 12-month terms are capturing near-term surplus without taking on winter strip risk.
Installed solar capacity in Texas has grown substantially, pushing midday real-time prices negative on high-generation days. For buyers on index structures, this is suppressing daytime costs but amplifying evening ramp exposure. Fixed-price products increasingly price in a "duck curve" premium. Buyers with flexible process loads are best positioned to capture index downside.
The PJM Base Residual Auction for the 2026/27 delivery year cleared significantly above prior years as plant retirements outpaced new entry. Capacity costs account for $10–$30/MWh of all-in electricity rates in PJM markets. Buyers currently on index contracts should request capacity cost projections from their supplier before choosing between fixed and passthrough structures at renewal.
These are general market signals — not personalized advice. Contact PDR for a recommendation tailored to your load, market, and risk profile.
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