How to Check Power Pricing and Grid Congestion Data for a Solar or Wind Site
To check power pricing and grid congestion for a solar or wind site, pull the historical locational marginal price (LMP) at the pricing node (P-node) where the project would inject power, split it into its energy, congestion, and loss components, and compare it with the nearest trading hub. Then measure how often that node clears at negative prices, check curtailment history in the surrounding zone, and pair the price view with substation capacity and interconnection queue data. The gap between the node and the hub, multiplied by your generation profile, is the revenue you could lose to congestion every year.
Most developers check the resource first and the price last. That order made sense when wholesale prices were relatively flat across a region. It no longer works. In 2024, a megawatt-hour of utility-scale solar was worth $60 in SPP and $18 in CAISO, according to Lawrence Berkeley National Laboratory's Utility-Scale Solar 2025 Data Update. Same technology, roughly 3.3 times the revenue. This guide walks through exactly where to find the pricing and congestion data that explains gaps like that, and how to read it before you sign a lease or file an interconnection request.
What power pricing and congestion data should you check for a renewable site?
Five data points do most of the work. Each one answers a different question about whether the energy your site produces will be worth what your pro forma assumes.
Data point | What it tells you | Where it shows up in your model |
Nodal LMP (historical, hourly) | What the grid actually paid for power at your injection point | Merchant revenue, PPA price floor |
Congestion component of LMP | How much transmission constraints push your local price below (or above) the system price | Basis risk, long-term price deck |
Node-to-hub basis spread | The gap between your node and the hub most PPAs and hedges settle at | Hub-settled PPA and hedge exposure |
Negative price frequency | How many hours you would be paid less than zero to generate | Lost revenue, PTC economics, storage case |
Curtailment history and forecast | How often generators near you are told to stop producing | Annual MWh delivered, P50 and P90 output |
These are not abstract risks. Berkeley Lab researchers found that once wind and solar reach about 20% of a region's capacity, their value can fall 30% to 40% below the regional average, with transmission congestion a major driver for wind in particular. Price data at the node is how you see that coming.
How do you check power pricing and grid congestion for a solar or wind site, step by step?
Step 1: Identify the pricing node where your project would inject power
Every wholesale market prices power at thousands of individual nodes, not one regional number. Your project will settle at the node tied to the substation or bus where it interconnects, so start by mapping the candidate parcel to its likely point of interconnection. A site that sits between two substations can face very different prices depending on which one it ties into. LandGate's power infrastructure and transmission data layers map substations, lines, and voltage alongside parcels, so you can see the realistic interconnection options before you look at a single price.
Step 2: Pull at least three to five years of hourly LMP at that node
Use hourly (or five-minute, where available) real-time and day-ahead LMPs, not monthly averages. Averages hide the midday solar trough and the overnight wind trough that actually determine your revenue. Each grid operator publishes this data for free, although the formats differ:
ERCOT: settlement point prices and LMPs by bus on the ERCOT Market Prices page.
PJM: nodal LMPs through PJM Data Miner 2, including an API.
ISO New England: real-time and day-ahead LMPs through ISO Express pricing reports.
CAISO, MISO, SPP, and NYISO: each publishes nodal prices on its own market data portal. Lawrence Livermore's open-source ISO-DART tool can automate downloads across several ISOs.
Hub-level context: the EIA's wholesale electricity market data tracks daily prices at major trading hubs back to 2001, which is useful for the hub side of a basis comparison.
National picture: Berkeley Lab's free Wholesale Electricity Prices (WEP) tool maps nodal price trends across the country.
The free route works, but stitching seven different formats together for a site screen takes time. LandGate's power pricing data covers 100% of U.S. real-time P-nodes with hourly historical LMPs going back 30 years, exportable in one format.
Step 3: Break the LMP into energy, congestion, and loss components
An LMP is the sum of three parts: a system energy price, a congestion component, and a marginal loss component (this primer from Yes Energy and FERC's Energy Primer both walk through the math). The energy component is roughly the same across a market. The congestion component is the one that tells you about your site. A persistently negative congestion component means transmission out of your area is constrained and local supply is being discounted to stay on the grid. That is the signature of a node that is already crowded with generation, and adding your project makes it worse.
Step 4: Calculate the basis spread between your node and the hub
Most corporate PPAs and financial hedges settle at a trading hub, not at your node. If the project earns the nodal price but owes the hub price, every dollar of difference is yours to absorb. Calculate the node-to-hub spread hour by hour, then weight it by your expected generation profile (an 8760 hourly output file). A solar project only cares about the spread during daylight hours, and a wind project cares most about nights and shoulder seasons. A flat annual average spread can look harmless while the generation-weighted spread is large.
Step 5: Count negative price hours and check curtailment
Negative prices occur when there is more supply at a location than the grid can absorb or move. Berkeley Lab found that in 2020, negative real-time prices hit about 4% of all hours and nodes nationally, but more than 25% of hours in parts of western Texas and in Kansas and western Oklahoma. That clustering is the point: negative pricing is a local problem.
Recent data shows it can move in either direction. CAISO's Department of Market Monitoring reported that negative price frequency fell by roughly 20% in 2025 as batteries and regional market integration absorbed more midday solar (day-ahead negative intervals dropped from 8.8% to 7.7%, as summarized by the Energy Institute at Haas). Yet the same 2025 annual report found downward dispatch of wind and solar rose about 22% year over year. In New England, by contrast, negative prices added up to only about 31 hours in 2024. Curtailment rates vary by market too: solar curtailment ran 7.1% in ERCOT, 3.7% in CAISO, and 2.8% in SPP in 2024, per Berkeley Lab.
Step 6: Look forward, not just back
Historical congestion only tells you what the grid looked like before your project, and before the projects queued ahead of you. Grid operators were still holding about 2,061 GW of capacity in interconnection queues at the end of 2025, and the typical path to commercial operation exceeds five years, according to Berkeley Lab's Queued Up data. If a large share of that queue is solar or wind near your node, today's congestion is a floor, not a ceiling.
To look forward, combine three things: a nodal price forecast, the queue of projects at nearby substations, and the available transfer capacity (ATC) on the lines leaving the area. LandGate provides 7-day hourly and 30-year monthly nodal LMP forecasts with all marginal components, plus ATC heat mapping and injection studies and long-term congestion and curtailment risk forecasts for any project location.
Step 7: Check the site's grid fundamentals alongside price
Pricing tells you what the power is worth. Grid capacity tells you whether you can deliver it at all. Before advancing a site, confirm the substation's remaining injection capacity, the estimated network upgrade costs, and the competing queued projects at the same point of interconnection. LandGate's offtake capacity data and solar and wind siting tools layer these on the same map as the price data, which is what makes a quick site comparison possible.
How is checking pricing different for solar versus wind sites?
Factor | Solar sites | Wind sites |
When generation happens | Midday, concentrated in a few hours | Often overnight and in spring and fall |
Biggest pricing risk | Midday price collapse as regional solar grows (value factor fell to 80% nationally and 30% in CAISO in 2024) | Transmission congestion out of remote, wind-rich areas |
Hours to weight most | Roughly 9 a.m. to 5 p.m., spring months | Night hours, shoulder seasons, high-wind events |
Typical mitigation | Pair with battery storage to shift output into evening peaks | Choose nodes with stronger export capacity; consider storage or hub-to-node hedges |
For a deeper look at the wind side, see LandGate's guide to wind farm development with LMP, and for how pricing feeds into contract structures, see our introduction to LMP and PPAs.
What are the red flags in a site's pricing and congestion data?
A congestion component that is negative most daylight hours (for solar) or most night hours (for wind). The local grid is already saturated during your production window.
A widening node-to-hub spread over the past three years. Congestion is getting worse, not better.
Negative prices in more than a few percent of your generation hours. Each one cuts revenue and can erode tax credit economics.
A deep queue of same-technology projects at nearby substations. Today's spread does not yet reflect what is coming.
Low ATC on the lines leaving the area with no planned upgrades. There is no relief valve for future congestion.
Frequently asked questions
What is LMP in solar and wind development?
Locational marginal price (LMP) is the wholesale price of electricity at a specific node on the grid at a specific time. It equals the system energy price plus a congestion component and a marginal loss component. For a solar or wind project selling into a wholesale market, the LMP at its interconnection node determines merchant revenue and shapes the value of any PPA or hedge. Because LMPs vary by location and hour, two sites in the same state can earn very different revenue for the same output.
Where can I find free LMP data for a specific location?
Each grid operator publishes nodal prices for free: ERCOT on its Market Prices page, PJM through Data Miner 2, ISO New England through ISO Express, and CAISO, MISO, SPP, and NYISO on their own market portals. Berkeley Lab's Wholesale Electricity Prices tool offers a national view, and the EIA publishes daily hub prices. The trade-off is time: each source uses different formats, node names, and time conventions. Commercial platforms such as LandGate consolidate nodal data nationwide in one format.
How do I measure grid congestion near a potential solar or wind site?
Look at the congestion component of the LMP at the node where the project would interconnect, ideally over three to five years of hourly data. A congestion component that is consistently negative during your production hours indicates that transmission out of the area is constrained. Supplement that with the node-to-hub price spread, curtailment history in the zone, available transfer capacity on outbound lines, and the number of similar projects queued at nearby substations.
What is basis risk for a renewable energy project?
Basis risk is the exposure created when a project earns one price but is paid or hedged at another. Most commonly, a wind or solar project sells at its nodal LMP while its PPA or hedge settles at a trading hub price. If congestion pushes the nodal price below the hub, the project absorbs the difference. Basis risk should be measured hour by hour and weighted by the project's expected generation profile, not averaged over the year.
Why do power prices go negative near wind and solar farms?
Prices go negative when local supply exceeds what the grid can consume or export at that moment. Wind and solar have near zero fuel cost, and many projects earn production-based tax credits, so they can keep generating at prices below zero. Negative prices cluster where renewable output is high and transmission is limited. Berkeley Lab found that some areas of western Texas, Kansas, and western Oklahoma saw negative prices in more than 25% of hours in 2020.
How much historical pricing data do I need for a site screen?
Three to five years of hourly data is a practical minimum for screening, because it captures several spring seasons (when negative prices and curtailment peak) and at least one extreme weather year. For financing and long-term revenue modeling, pair the history with a forward-looking nodal price forecast that accounts for queued projects and planned transmission, since historical congestion reflects the grid before your project and its competitors come online.
Does adding battery storage reduce congestion and pricing risk?
Often, yes. A battery co-located with solar or wind can charge during low or negative price hours and discharge into higher priced hours, which raises the project's realized price and reduces curtailment. CAISO's market monitor credited battery growth as one reason negative price frequency fell in 2025. Storage does not fix a node with structurally weak export capacity, though, so it should be evaluated alongside transmission and ATC data, not as a substitute for it.
How does LandGate help check power pricing and congestion for a site?
LandGate combines nodal pricing and grid data with parcel-level land data on one map. The platform covers 100% of U.S. real-time P-nodes with 30 years of hourly LMP history broken into energy, congestion, and loss components, 7-day hourly and 30-year monthly nodal price forecasts, congestion price monitoring, PPA data, ATC heat mapping, interconnection queue data, and long-term congestion and curtailment risk forecasts for specific project locations.
Check pricing and congestion for your next site
Price and congestion data belong at the start of site selection, not the end. If you want to see nodal LMP history, congestion components, ATC, and queued projects for a specific parcel on one screen, schedule a LandGate demo, or explore the solar, wind, and power pricing tools. For a regional view of where grid conditions favor new generation, see LandGate's 2026 ranking of the best regions for data center and renewable colocation.
