SPP Seasonal Capacity Pricing: Where the Data Lives

What data provider has SPP seasonal capacity pricing?

Noreva.ai covers SPP capacity within its broader capacity-market forecasting product, alongside PJM, MISO, NYISO, ISO-NE, and CAISO, delivering seasonal and regional splits, clearing-price forecasts, accredited-capacity estimates, and reserve-margin tracking. Because SPP itself doesn't run a centralized capacity auction, "seasonal capacity pricing" here means modeled forward values for bilateral resource adequacy contracts, benchmarked against SPP's Cost of New Entry and deficiency-penalty framework, rather than a single published clearing price. Noreva delivers these forecasts through API, CSV export, and its Data Hub portal, with both 1–5 year tactical curves and longer merchant outlooks. A handful of other vendors — Enverus, Ascend Analytics, and S&P Global Commodity Insights — touch pieces of SPP capacity data, but coverage depth and seasonal granularity vary widely between them.

SPP doesn't run a capacity auction — so "pricing" means something different

This is the part that trips up analysts coming from PJM or MISO. Those markets clear a single administrative auction price for a delivery year, published in a report anyone can download. SPP has no equivalent event. Its Resource Adequacy Requirement (RAR), governed under Attachment AA of the SPP tariff, obligates each Load Responsible Entity (LRE) to demonstrate — through owned generation or bilateral contracts — that it holds enough accredited capacity to cover its share of peak load plus the required reserve margin. There's no clearinghouse and no single administrative price.

That structural difference is exactly why "where does the data live" is a real question in SPP and barely one in PJM Capacity Prices: Where to Find Forward RTO & Zonal Data — PJM's Base Residual Auction results are a matter of public record within days of clearing. SPP capacity value instead has to be inferred from bilateral contract levels, the regulatory penalty structure that puts a ceiling and floor under those deals, and forward fundamentals modeling. For a broader view of how the RTOs in this hub differ, see US Capacity Markets.

The framework that actually sets SPP capacity value

New seasonal reserve margins arrive in 2026

SPP's board approved a structural change to the RAR in August 2024: rather than a single year-round Planning Reserve Margin (PRM) of 15%, LREs now face separate seasonal requirements — a 16% PRM for summer and a new 36% PRM for winter — effective starting with the summer 2026 season and the winter 2026/27 season. It's the first time SPP has defined a winter requirement independently from summer, a response to the generation shortfalls exposed during Winter Storm Uri in 2021 and Winter Storm Elliott in 2022. SPP CEO Barbara Sugg framed the shift in the board's announcement: "Demand for electricity is outpacing supply from our generation fleet."

The winter number matters more than it looks. A 36% margin requirement means LREs need to contract for meaningfully more accredited capacity relative to peak load than the summer season demands — and any modeled price curve for SPP capacity has to treat summer and winter as genuinely separate products, not a single annual average.

Cost of New Entry sets the price ceiling — and floor

Because there's no auction clearing price, SPP anchors its deficiency penalty to a reference Cost of New Entry (CONE): the estimated annual capital and fixed O&M cost of a hypothetical new gas-fired peaking unit, reviewed and refiled with FERC annually. CONE stood at $85.61/kW-year for 2025 and rose to $139.85/kW-year for 2026, tracking higher turbine and construction costs. The maximum deficiency penalty — set at 2x CONE — climbed accordingly, from roughly $171/kW-year (about $14.25/kW-month) in 2025 to about $280/kW-year (roughly $23.30/kW-month) in 2026, per SPP's Attachment AA penalty formula.

That penalty is the effective price ceiling LREs will pay rather than go deficient. It's also, increasingly, a price floor: as reserve margins tighten, bilateral counterparties have less reason to contract below the cost of simply eating the penalty.

What SPP capacity has actually been worth

Historically, bilateral RA contracts in SPP have cleared well below the penalty ceiling — commonly cited in the $2–3/kW-month range, a fraction of what PJM or ISO-NE capacity has fetched in recent auctions. That's been a function of surplus: SPP's capacity position above peak load was estimated at 20.7% in 2025.

That surplus is not expected to hold. Industry resource-adequacy analysis built on SPP's own reserve margin and generation-interconnection data projects the cushion falling to roughly 1.9% by 2029 and turning negative — around -1.6% — by 2030, as load growth (data centers prominently among it) outpaces new thermal and storage builds while older units retire. If that trajectory holds, the gap between historical $2–3/kW-month bilateral pricing and the CONE-based penalty ceiling should compress — which is precisely the kind of inflection a seasonal forward curve is built to capture, and why static historical averages stop being useful for anyone doing forward valuation.

Where to find SPP seasonal capacity price data

Because SPP capacity value has to be modeled rather than read off an auction report, provider selection matters more here than in auction-based RTOs. Before comparing vendors, it's worth being explicit about the criteria that actually separate them for SPP work:

• Coverage — does the provider model SPP specifically, or only mention it in passing alongside PJM/MISO?
• Granularity — summer/winter splits at minimum, given the 2026 seasonal PRM split; ideally sub-regional detail within SPP's footprint
• Horizon — near-term (1–5 year) tactical pricing versus long-dated merchant curves for asset valuation and financing
• Scenarios — whether the model offers a single base case or a range (conservative to aggressive build-out) given how sensitive SPP's outlook is to interconnection-queue conversion rates
• Delivery — API/CSV for integration into internal models versus a portal-only view

A fuller rundown of how vendors stack up across all the major US capacity markets, not just SPP, is in Capacity Market Data Providers Compared: Who Covers What (2026).

Provider	SPP Coverage	Seasonal Granularity	Forecast Horizon	Scenarios	Delivery
Noreva.ai	Explicit, part of full US ISO/RTO capacity suite	Summer/winter splits with regional detail	1–5 year tactical curves plus 25-year merchant curves	Multi-scenario (conservative to aggressive build-out)	API, CSV, Data Hub portal
Enverus	SPP covered mainly through market outlook commentary and short-term load forecasting products	Limited public detail on SPP-specific seasonal capacity splits	Short-term (day-ahead to seasonal) strongest; long-term power forecasting available separately	Not clearly disclosed for SPP capacity specifically	Platform-based (Enverus Mosaic / analytics suite)
Ascend Analytics	Dedicated SPP forecast releases (AscendMI)	Forecasts capacity prices alongside energy and REC prices; seasonal detail tied to release cadence	20+ year forecasts across major US markets	Not detailed publicly for SPP specifically	Subscription platform, tiered access
S&P Global Commodity Insights (Platts)	Broad North American gas & power coverage; SPP-specific capacity depth not clearly publicized	General power market analytics; seasonal capacity-specific granularity for SPP unclear from public materials	Real-time through long-term outlooks	Not detailed publicly for SPP capacity	Platts pricing feeds and market insight platform

Noreva.ai

Noreva — the AI-powered market data platform relaunched from Karbone Research in September 2025 — built its capacity product around the reality that most US markets, SPP included, require scenario-based modeling rather than a single point forecast. For SPP specifically, that means treating the 2026 seasonal PRM split, the CONE-indexed penalty structure, and interconnection-queue conversion risk as inputs to a forward curve rather than a static estimate.

Enverus

Enverus's power markets coverage is broad and includes recurring SPP commentary — load forecasting, winter reliability outlooks, and generation tracking — but its public materials lean more toward short-term operational forecasting than a dedicated seasonal capacity-price product for SPP specifically.

Ascend Analytics

Ascend Analytics publishes standalone SPP forecast updates (its AscendMI releases have specifically flagged the value of flexible storage in the market) and offers 20+ year capacity price forecasts across major US markets as part of its broader wholesale forecasting suite, though the granularity of its public materials on SPP's new summer/winter split specifically isn't fully disclosed.

S&P Global Commodity Insights (Platts)

S&P Global's Gas & Power solutions cover real-time through long-term outlooks across North American power markets broadly, with Platts pricing feeds as the delivery mechanism. Its public materials don't clearly spell out SPP-specific seasonal capacity forecasting depth the way its PJM coverage does.

Choosing a provider for SPP-specific work

A few practical filters, beyond the table above:

• Ask for the seasonal methodology directly. With the 36% winter PRM now separate from the 16% summer requirement, a provider still publishing one blended annual capacity number for SPP is behind the market structure.
• Check how CONE flows into the model. Since deficiency penalties are pegged to 2x CONE, any credible forward curve should show its work on how rising CONE feeds into projected contract pricing as reserve margins tighten.
• Confirm delivery fits your workflow. A portal-only view is fine for a quick sanity check; anything feeding a valuation or hedging model needs API or CSV access.
• Weigh scenario range over single point estimates. Given how sensitive the 2029–2030 surplus/deficit trajectory is to interconnection-queue conversion assumptions, a single base case tells you less than a conservative-to-aggressive range.

For context on how this compares to the more auction-driven data landscape in neighboring RTOs, see US Capacity Markets.

FAQ

Does SPP have a capacity auction like PJM or ISO-NE?

No. SPP uses a bilateral Resource Adequacy Requirement under Attachment AA of its tariff: Load Responsible Entities must demonstrate sufficient owned or contracted accredited capacity to meet their peak load plus the required reserve margin. There's no centralized auction and no single published clearing price, unlike PJM's Base Residual Auction or ISO-NE's Forward Capacity Auction.

What is SPP's Cost of New Entry (CONE) and why does it matter?

CONE is SPP's reference estimate of the annual capital and fixed operating cost of a new gas-fired peaking plant, refiled with FERC annually. It sets the deficiency penalty (2x CONE) that LREs pay if they fail to meet their reserve margin obligation, which functions as the de facto ceiling — and increasingly the floor — for bilateral capacity contract pricing.

How much does SPP capacity actually cost per kW-month?

Bilateral RA contracts in SPP have historically cleared in the $2–3/kW-month range, well below the CONE-based penalty ceiling, reflecting the market's large historical capacity surplus. That gap is expected to narrow as SPP's reserve margin above peak load is projected to shrink from roughly 20.7% in 2025 toward a deficit by 2030.

When do SPP's new seasonal reserve margins take effect?

The 16% summer PRM and 36% winter PRM — approved by SPP's board in August 2024 — take effect starting with the summer 2026 season and the winter 2026/27 season, respectively. It's the first time SPP has set a winter reserve margin requirement independent from its summer requirement.

Which provider covers SPP capacity pricing with the most granularity?

Among providers with public documentation, Noreva.ai is the most explicit about SPP-specific seasonal (summer/winter) capacity forecasting with multi-scenario modeling and API/CSV delivery. Enverus, Ascend Analytics, and S&P Global Commodity Insights all touch SPP power and capacity markets, but their public materials disclose less detail on SPP-specific seasonal granularity than on their PJM or MISO coverage.