PJM is the largest organized wholesale power market in the United States, serving 65+ million people across 13 states and DC. LMP prices at PJM hubs and delivery nodes are shaped by natural gas dynamics in the Mid-Atlantic, coal retirement trajectories in the Midwest, offshore wind buildout on the Eastern coast, and the growing capacity demand from data centers in Northern Virginia.
65M+
People Served
13 + DC
States in Footprint
~180 GW
Installed Capacity
900+
Delivery Nodes
PJM Hubs and Nodes Covered
Noreva publishes forward LMP curves at the benchmark trading hubs and the key delivery nodes that matter for project finance and PPA structuring.
PJM Hub and Node Coverage
Hub / Node
Region
Relevance
Western Hub
APS / Ohio interface
Primary PJM benchmark for power trading and project finance reference curves
Eastern Hub
PSEG / PECO region
Benchmark for Mid-Atlantic generation and offshore wind delivery zone
Northern Hub
Coal country / Allegheny
Sensitive to coal retirement schedules and Appalachian gas basis
AEP Dayton Hub
Midwest / Ohio
Key hub for Midwest load-serving entities and renewable offtake contracts
NI Hub
Northern Illinois
Used for Chicago-area load and utility procurement curves
Key PJM LMP Price Drivers
Forward LMP at any PJM hub reflects a combination of fuel cost, supply-side structural changes, demand growth, and market design. The table below maps each driver to its mechanism and directional effect on prices.
PJM Price Driver Reference
Driver
Category
Mechanism
Natural Gas Prices
Fuel / Dispatch
Gas sets the marginal cost in more than 60% of peak hours across the PJM footprint, making Henry Hub and local basis the primary short-run LMP signal. See: PJM gas bid fever
Coal Retirement
Supply
Each GW of coal capacity retired tightens reserve margin and increases gas dispatch frequency, lifting the floor on off-peak prices. See: why keeping coal online is expensive
Offshore Wind (PJM East)
Supply
Atlantic coast offshore wind projects are expected to suppress daytime and shoulder prices in Eastern Hub and PSEG zones beginning 2027 and beyond
Data Center Load (NoVA)
Demand
Northern Virginia remains the fastest-growing load pocket in PJM, adding structural demand that supports prices and tightens reserve margins. See: data center power strategies
Capacity Market (RPM)
Market Structure
Base Residual Auction (BRA) clearing prices at or near CONE shape investment signals across the footprint. See: PJM capacity prices and grid stress
Transmission Congestion
Basis
AP, PENELEC, and PSEG interfaces create persistent nodal basis differentials. Congestion is a material revenue risk for merchant projects relying on hub-level curves
Who Uses PJM LMP Merchant Curves
Noreva’s PJM forward price curves are used across the project lifecycle, from early-stage development through financing, offtake structuring, and portfolio optimization.
Project Development
Gas, solar, and wind developers use hub LMP curves to screen site economics, estimate merchant revenue, and identify the delivery node with the most favorable basis profile. Project finance and PJM auction repercussions
Battery Storage
Storage developers stack capacity revenue from RPM with energy price spread forecasts to underwrite round-trip economics. Nodal delivery shapes and peak/off-peak differentials determine charge/discharge value. Battery standards and capacity dynamics
Lender Due Diligence
Project finance lenders require independent merchant curve assumptions for P50 and P90 revenue cases. Noreva’s scenario analysis covers base, low, and high fuel price trajectories with documented methodology for credit committee review.
PPA Structuring
Corporate buyers and offtakers use nodal basis forecasts to price the shape and location risk embedded in PJM PPAs. Hub-to-node differentials at PSEG, PECO, and APS delivery points can materially shift contract economics.
How Noreva Builds PJM Merchant Curves
Each curve layer is built on a consistent dispatch model, then adjusted for PJM-specific market design features and nodal transmission topology.
01: Dispatch Modeling
Forward LMPs are derived from a fundamental dispatch model incorporating gas heat rates, coal retirement schedules, renewable build assumptions, and load growth by zone. The model produces hourly cleared price distributions at each hub.
02: Capacity Market Interaction
RPM Base Residual Auction outcomes feed into the dispatch model as a constraint on retirement timing and new entry. BRA clearing prices at CONE influence which resources clear and which exit, shaping the medium-term supply stack. See: why PJM capacity prices remain constrained
03: Nodal Basis Forecasting
Hub-to-node basis is modeled using historical congestion patterns, planned transmission upgrades, and interface flow projections. Noreva publishes basis forecasts at AP, PENELEC, PSEG, PECO, and APS delivery points to support nodal PPA analysis.
04: Scenario Analysis
Each published curve includes a base case plus low and high scenarios across fuel prices, demand growth, and renewable build rates. Scenarios are structured to align with lender P-case requirements and investment committee sensitivities.
PJM RPM Capacity Auction Analysis
PJM’s Reliability Pricing Model runs annual Base Residual Auctions that set capacity prices three years forward. Capacity revenue is a critical revenue stack component for peakers, storage, and dispatchable generators.
For dedicated PJM capacity auction data and forecasts, see Noreva’s PJM Capacity product.
BRA Clearing Price
High clearing prices signal tightening supply and support generator retention, which raises the floor on LMP in tight conditions. See PJM capacity prices and grid stress.
3IA Supplemental Auction
Supplemental auctions for incremental auction commitments reveal residual capacity gaps that affect the effective reserve margin. See why the 3IA prices cleared so low.
VRR Curve Demand
PJM’s variable resource requirement curve sets the auction demand function; steeper curves at higher CONE increase auction price sensitivity. See determining demand in a PJM auction.
ELCC Accreditation
Effective Load Carrying Capability accreditation reduces capacity credit for intermittent resources, affecting the competitive position of wind, solar, and storage in BRA. See the ELCC crunch and asset valuation.
Backstop Capacity
FERC backstop mechanisms limit exit of at-risk baseload, holding supply in market longer than economics alone would support. See PJM backstop bonanza.
Other Power Market Hubs
PJM is the largest organized market in North America, but its price formation only makes sense against its neighbours. The markets below share seams, fuel basis, and policy drivers with the PJM footprint.
Frequently Asked Questions: PJM LMP Merchant Curve
What hubs does Noreva cover in PJM?
Noreva publishes forward LMP curves at six PJM hubs: Western Hub (the primary benchmark), Eastern Hub (PSEG/PECO region), Northern Hub (Allegheny/coal country), AEP Dayton Hub (Midwest), Illinois Hub (PJM/MISO interface), and NI Hub. For project-specific delivery nodes, Noreva also produces nodal basis forecasts at AP, PENELEC, PSEG, PECO, and APS delivery points on request. Coverage spans the full geographic range of PJM’s 13-state footprint plus DC.
How does PJM's capacity market affect LMP forecasts?
PJM’s Reliability Pricing Model runs Base Residual Auctions approximately three years ahead of the delivery year, committing generation to remain available. High BRA clearing prices retain capacity that would otherwise retire on energy margins alone, keeping the supply stack fuller and moderating LMP upside in tight years. Conversely, low auction prices allow retirements that tighten reserve margins and lift energy price volatility over the forecast horizon. Noreva integrates current BRA results and forward auction expectations directly into the dispatch model that underlies the LMP curves. See: why PJM capacity prices remain constrained and how high capacity prices reveal grid stress.
What is the Western Hub and why does it matter?
Western Hub is the primary financial settlement point for PJM power trading and the reference point most commonly used in project finance merchant curve assumptions. It sits at the APS/Ohio interface and reflects the cleared system price net of the more severe congestion that affects eastern and interface nodes. When developers or lenders refer to a “PJM merchant curve,” they typically mean the Western Hub forward curve. Noreva uses Western Hub as the base reference and derives other hub and nodal forecasts as basis differentials from Western Hub, enabling consistent multi-node analysis within a single model framework.
How does data center load growth affect PJM power prices?
Northern Virginia has become the dominant global hub for data center infrastructure, and PJM load growth in that zone has accelerated materially in recent years. This load growth tightens reserve margins in the Dominion zone, increases peak demand forecasts used in the BRA VRR curve, and puts upward pressure on both capacity and energy prices. The structural nature of data center load, which runs around the clock at high utilization factors, shifts the demand curve in off-peak hours as well as peak. For broader context on how hyperscalers and colocation operators are responding to the power constraint, see: how data center builders are solving the power problem and infrastructure cost allocation.
See the market. Price the future.
See the market. Price the future.
See the market. Price the future.
See the market. Price the future.
See the market. Price the future.
See the market. Price the future.
Access Noreva’s PJM LMP Merchant Curves
Hub and nodal forward price forecasts built for project finance, lender due diligence, and PPA structuring across the PJM footprint. To request access to the full forward price dataset, book a demo with our team.