Independent Power Producers (IPPs) — Demand vs Supply (V2)

Snapshot — the group at a glance

Independent power producers (IPPs) own and operate power plants that sell electricity into wholesale markets or under bilateral contracts called PPAs (power purchase agreements — fixed-price, multi-year supply deals). Unlike regulated utilities, IPPs earn unregulated, market-driven returns: they profit when power prices rise and lose when prices fall. The four US-listed pure-play IPPs covered here — Constellation Energy (CEG), Vistra (VST), Talen Energy (TLN), and NRG Energy (NRG) — collectively control roughly 143 GW of dispatchable generation capacity. Their fleets span natural gas, nuclear, coal, solar, geothermal, and battery storage, but the core economic asset in the current cycle is dispatchable baseload and peaking capacity — generation that runs on demand, 24/7, which data centers require and intermittent renewables cannot provide.

~143 GW

Combined generation capacity (4 IPPs)

~30 GW

Nuclear capacity (CEG ~21 GW, VST ~6.4 GW, TLN ~2.2 GW)

$329/MW-day

PJM capacity auction price (2026/27) — at the FERC cap

$197B

Combined market cap (Jun 2, 2026)

$271B

Combined enterprise value

~$16B est.

Combined 2026 adjusted EBITDA (midpoint of guidance ranges)

These four companies own roughly 143 GW of power plants and are guided to produce about $16 billion in combined EBITDA this year. The market prices the group at roughly $271 billion of enterprise value, or about $1.9 million per MW of installed capacity. PJM capacity prices jumped from $29/MW-day in 2024/25 to $329/MW-day in 2026/27, an 11x increase in two years, driven by data center load growth and generator retirements outpacing new supply.

Capacity and financial data: company 10-K/10-Q filings, earnings releases (CEG Q1 2026, VST FY2025, TLN Q1 2026, NRG Q1 2026). PJM auction: PJM BRA results (Jul 2025). Market data: yfinance, Jun 2, 2026.

The product & how money is made

IPPs sell electricity. The product is a megawatt-hour (MWh) — one million watts delivered for one hour. A typical US household uses about 10 MWh per year; a 100 MW data center uses roughly 876,000 MWh per year (100 MW x 8,760 hours). IPPs make money in three streams:

Energy revenue: selling MWh into wholesale electricity markets (PJM, ERCOT, ISO-NE, NYISO, etc.) at spot or forward prices. Average US wholesale prices ranged from $30-80/MWh in 2025 depending on region est.. Gas-fired generators set the marginal price in most hours, so when gas prices rise, wholesale electricity prices rise — and nuclear/renewable generators, whose fuel is free or fixed-cost, pocket the entire spread.
Capacity revenue: getting paid for being available to generate when called upon, even if not running. PJM's capacity auction clears years ahead. The 2026/27 auction cleared at $329.17/MW-day (the FERC-approved maximum), up from $28.92/MW-day two years prior — an 11.4x increase. For a 1,000 MW plant, that jump translates from ~$10.6M/year to ~$120M/year in capacity revenue alone.
Bilateral PPAs with hyperscalers: long-term contracts (10-20 years) selling power directly to data center operators at negotiated prices. Examples: CEG's 20-year PPA with Microsoft at Crane nuclear; VST's 20-year PPAs with AWS (1,200 MW at Comanche Peak) and Meta (2,600+ MW at PJM nuclear units); TLN's 17-year, $18B PPA with Amazon (up to 1,920 MW from Susquehanna nuclear).

Some IPPs also have retail electricity businesses — NRG is the largest US retail electricity provider, and CEG (post-Calpine) serves ~2.5M customer accounts. Retail provides a natural hedge: when wholesale prices rise, the generation side profits; when they fall, the retail side's margins expand because input costs drop.

Nuclear generators have a structural cost advantage. Nuclear fuel costs are roughly $5-8/MWh, fixed years in advance. When wholesale power clears at $50-80/MWh, the nuclear plant pockets $42-75/MWh of gross margin per hour at near-zero marginal cost. Nuclear also receives Production Tax Credits (PTCs) under the Inflation Reduction Act — up to $15/MWh indexed to inflation — which sets a floor under nuclear cash flows regardless of market price.

Energy/capacity pricing: EIA (Jan 2026 STEO), PJM BRA results. PPA details: CEG 10-K, VST 8-K (Feb 2026), TLN earnings release (Q1 2026), Power Magazine (Jun 2025). Nuclear PTC: IRA Section 45U.

Demand — how much the world will want this

Contracted demand (locked in)

Company	Counterparty	MW	Duration	Notional value	Status
CEG	Microsoft (Crane nuclear restart)	~835	20 years	Not disclosed	contracted DOE $1B loan guarantee
CEG	CyrusOne (Freestone gas, TX)	380+380	Multi-year	Not disclosed	contracted Phase 1 + Phase 2 exclusive
VST	AWS (Comanche Peak nuclear, TX)	1,200	20 years	Not disclosed	contracted
VST	Meta (PJM nuclear units)	2,609	20 years	Not disclosed	contracted
TLN	Amazon/AWS (Susquehanna nuclear)	up to 1,920	17 years (through 2042)	$18B	contracted ramp to full by 2032

The hyperscaler PPAs are a new phenomenon — none existed before 2024. Talen's Amazon PPA includes 2% annual price escalators and minimum-volume commitments with payment obligations even if Amazon builds slower than planned.

Forecast demand (not contracted)

US electricity demand is growing at the fastest rate in 25 years. The EIA (Jan 2026) projects consumption rising ~1% in 2026 and ~3% in 2027 — driven primarily by data centers. est.
Data center power demand was ~176 TWh in 2023 (~20 GW average load), per Lawrence Berkeley National Lab. Projections range from 325-580 TWh (~37-66 GW) by 2028. est.
PJM alone has 27 scheduled generator deactivations between Aug 2025 and Jun 2027 totaling ~8,483 MW, 61% from coal retirements.
New gas-fired combined-cycle plants take ~2-3 years to build from final investment decision; nuclear restarts take 3-5 years. Data centers can be built in 18-24 months. est.

Some market-size and growth figures are directional estimates, not live-verified. Company financials are from most recent public filings. For SEC-verified deep dives, see Stock Reports.

EIA STEO (Jan 2026). Berkeley Lab data center report (Jan 2025). PJM BRA results (Jul 2025). Construction timelines: Power Magazine, company filings.

Supply — how much can be made, and what limits it

Existing capacity (what can generate today)

Company	Total (GW)	Nuclear (GW)	Gas (GW)	Coal (GW)	Other (GW)	Notes
CEG	55	~21	~27	—	~7	Post-Calpine (Jan 2026). Other = geothermal ~1.4, hydro, wind, solar, oil. Largest US nuclear fleet (23 units). Divesting 6 gas plants per DOJ.
VST	~44	~6.4	~26	~4.6	~7	Pre-Cogentrix. Comanche Peak nuclear (TX) + 4 PJM nuclear units. Coal retiring by 2028. Other = solar, battery. +5.5 GW Cogentrix pending (mid-late 2026).
TLN	13.1	2.2	~6.6	~2.1	~2.2	Susquehanna (90% owned, 2,245 MW). Other = dual-fuel (Brunner Island ceasing coal 2028), oil. Acquiring ~2.5 GW Cornerstone gas (H2 2026).
NRG	~25	—	~25	—	—	Post-LS Power (Jan 2026). All gas-fired. Also 8 GW VPP (virtual power plant / demand response). No nuclear.
Total	~137	~30	~85	~7	~16	Pending acquisitions (Cogentrix, Cornerstone) add ~8 GW more → ~145 GW.

Supply being added

VST: Cogentrix acquisition — 5,496 MW of gas across 10 plants for $4B (~$728/kW vs ~$2,000/kW new-build est.). Expected mid-late 2026. Would bring VST to ~50 GW.
VST: Permian Basin expansion — 860 MW of new gas under construction, tripling existing Permian capacity.
TLN: Cornerstone acquisition — ~2,451 MW of PJM gas plants (Lawrenceburg, Waterford, Darby) for undisclosed price. Expected H2 2026.
NRG: LS Power acquisition — closed Jan 2026, 13 GW of gas across 18 plants for $12B EV (~$923/kW). Doubled NRG's fleet.
CEG: Crane nuclear restart — Three Mile Island Unit 1, ~835 MW, backed by Microsoft PPA and DOE $1B loan guarantee. Timeline: 2028 target.
CEG: Pin Oak Creek — 460 MW gas peaker in ERCOT, reached commercial operation April 2026.

Bottlenecks

New gas plants take 2-3 years. GE Vernova has said orders placed today will not deliver until 2028 est.. Turbine supply is sold out.
Nuclear is irreplaceable. No new US commercial reactor has been built since Vogtle (2023-24). Restarts (Crane/TMI, Palisades) take 3-5 years and cost $1B+. est.
Coal retirements shrink supply. ~8.5 GW of PJM deactivations scheduled by mid-2027, mostly coal. VST retiring ~4.6 GW of coal by 2028.
Grid interconnection queues. PJM has over 2,500 GW in its interconnection queue but has historically processed only a fraction. Recent reforms cleared 60% of backlog, with plans to process 63,000 MW in 2025-26.

Capacity data: CEG Q1 2026 earnings, VST 8-K (Feb/May 2026), TLN Q1 2026 earnings, NRG Q1 2026 8-K. Acquisition details: Power Magazine, company press releases. Turbine supply: GE Vernova earnings commentary. PJM interconnection: PJM BRA report (Jul 2025).

The gap — demand vs supply

Demand for dispatchable power is growing while dispatchable supply is flat-to-shrinking.

Measure	Direction	Evidence
PJM capacity price ($/MW-day)	↑ 11.4x in 2 years	$28.92 (2024/25) → $269.92 (2025/26) → $329.17 (2026/27, at FERC cap)
PJM dispatchable retirements	↓ supply shrinking	~8,483 MW scheduled deactivation by mid-2027 (61% coal)
Data center load growth	↑ demand accelerating	176 TWh (2023) → 325-580 TWh projected by 2028 est.
New gas plant lead time	→ supply delayed	2-3 year build; turbines sold out through 2028 est.
Nuclear fleet	→ fixed (irreplaceable)	~30 GW across CEG/VST/TLN. One restart in progress (Crane ~835 MW). No new builds.
Hyperscaler PPA pricing	↑ premium to wholesale	TLN Amazon PPA: $18B / 17yr / up to 1,920 MW = implied ~$55-72/MWh with 2% annual escalator est.
Wholesale electricity prices	↑ rising	ISO-NE up $29/MWh YoY (2025 vs 2024) est.

Capacity prices. PJM clearing at the $329/MW-day cap means the market wanted to clear higher but was artificially capped. A 10 GW fleet in PJM now earns roughly $1.2B/year in capacity revenue alone — versus ~$106M/year at the 2024/25 price. TLN's capacity revenue jumped from $192M (FY2024) to $485M (FY2025) and is guided substantially higher in 2026. NRG benefits in PJM post-LS Power but also has large ERCOT (Texas) exposure where the capacity market works differently (energy-only).

Acquisition multiples. All three recent major IPP acquisitions priced existing gas plants at 7-8x EBITDA est. and $728-923 per kW of capacity — roughly 35-50% of new-build replacement cost (~$2,000/kW for combined cycle est.).

PJM: BRA reports (2024, 2025). TLN capacity revenue: TLN FY2025 earnings. Acquisition multiples: Advisor Analyst (Jun 2025), company filings. Wholesale prices: EIA (Jan 2026).

The players — who captures the money

Metric	CEG	VST	TLN	NRG
Total capacity (GW)	55	~44 (→50)	13.1 (→15.6)	~25
Nuclear (GW)	~21	~6.4	2.2	—
Nuclear capacity factor (2025)	94.7%	90.8-95.4%	~90% est.	n/a
Gas (GW)	~27	~26 (→31.5)	~6.6 (→9.1)	~25
Primary market	PJM, ERCOT	ERCOT, PJM	PJM	ERCOT, PJM (post-LS)
FY2025 adj. EBITDA ($B)	~$3.9 est.	$5.84	$1.04	~$3.9 est.
2026 EBITDA guidance midpoint ($B)	~$4.0 est.	$7.2	$1.9	$5.6
Market cap ($B, Jun 2)	$97.9	$53.3	$17.5	$28.2
Enterprise value ($B)	$120.4	$75.0	$23.3	$52.0
Total debt ($B)	$22.5	$20.7	$6.8	$23.4
EV / 2026E EBITDA	~30x est.	~10.4x	~12.3x	~9.3x
EV / GW of capacity ($B/GW)	$2.2	$1.7	$1.8	$2.1
Retail business	2.5M accounts	~5M accounts	No	Largest US retail (6M+)
Data center PPAs signed	MSFT, CyrusOne, Meta	AWS, Meta	Amazon ($18B)	None disclosed
Hedged 2026 / 2027	Not disclosed	~100% / ~84%	~85% / ~65%	Not disclosed
Share buyback activity	Dividend +10%/yr	$1.0B (2025)	$2B program thru 2028	$1.0B plan (2026)

CEG is the world's largest private power producer post-Calpine and the largest US nuclear fleet owner (23 reactor units). Q1 2026 revenue roughly doubled to $11.1B on the Calpine consolidation. It trades at ~30x 2026E EBITDA. CEG does not report adjusted EBITDA; the 2026 figure is estimated from adjusted operating earnings guidance ($11-12/share x ~354M diluted shares x ~1.1x EBITDA/earnings conversion). est.

VST operates in ERCOT and PJM with nuclear, gas, coal (retiring), solar, and battery storage. Its 20-year PPAs with AWS and Meta lock in decades of nuclear revenue. The Cogentrix deal, if closed, would bring it to ~50 GW. At ~10.4x 2026E EBITDA, it trades at roughly one-third the EV/EBITDA of CEG.

TLN is the smallest but most concentrated on nuclear-powered data centers. Its $18B Amazon PPA — up to 1,920 MW from Susquehanna — is the single largest disclosed hyperscaler power contract. At full ramp (~2032), that PPA alone generates ~$1.4B/year of revenue est.. The pivot from behind-the-meter to a grid-connected retail model resolved the FERC rejection of the original co-location plan.

NRG has no nuclear and no disclosed hyperscaler PPAs. The LS Power acquisition doubled its fleet but also doubled its debt to $23.4B. NRG earns from the spread between wholesale generation costs and retail electricity prices. At ~9.3x 2026E EBITDA it carries the lowest multiple but the most leverage ($23.4B debt on $28.2B equity market cap).

All figures from company earnings releases and filings (CEG Q1 2026, VST FY2025/Q4 2025 8-K, TLN Q1 2026, NRG Q1 2026 8-K). Market data: yfinance Jun 2, 2026. CEG EBITDA estimate derived, not directly reported.

The price of exposure

Metric	CEG	VST	TLN	NRG
Share price (Jun 2, 2026)	$272.65	$157.97	$385.51	$133.51
Market cap ($B)	$97.9	$53.3	$17.5	$28.2
Enterprise value ($B)	$120.4	$75.0	$23.3	$52.0
EV per MW of capacity ($M/MW)	$2.19	$1.70	$1.78	$2.08
EV per MW of nuclear ($M/MW)	$5.73	$11.72	$10.59	n/a
EV / 2026E EBITDA	~30x est.	~10.4x	~12.3x	~9.3x
Forward P/E	20.0x	14.4x	11.5x	11.5x
Net debt ($B)	$21.6	$20.0	$5.8	$23.2
Net debt / 2026E EBITDA	~5.4x est.	~2.8x	~3.1x	~4.1x
Dividend yield	0.63%	0.58%	—	1.42%

Acquisition comparables. All three 2025-2026 gas fleet acquisitions priced at 7-8x EBITDA est. and $728-923/kW — roughly half of new-build cost est.. The public market values these same companies at 9-30x EBITDA.

What 2026 EBITDA guidance implies. Combined 2026 EBITDA guidance midpoints total ~$16.1B est.. At a 10x multiple that implies ~$161B EV; at 15x, ~$242B. Today's combined EV is $271B.

Replacement cost. New gas combined-cycle costs ~$2,000/kW ($2M/MW) est.. New nuclear is $10,000+/kW est.. The four IPPs' combined ~137 GW fleet would cost $200B+ to replicate in gas alone and far more counting nuclear. Today's combined EV of $271B is above gas replacement cost but below nuclear-inclusive replacement cost.

Market data: yfinance Jun 2, 2026. EBITDA: company 2026 guidance ranges. Replacement cost: industry estimates (Power Magazine, Lazard LCOE). Acquisition comps: CEG/Calpine ($26.6B EV), VST/Cogentrix ($4B), NRG/LS Power ($12B).

What to deep-dive next

PPA pricing transparency: Only Talen's Amazon deal discloses notional value ($18B). CEG and VST PPA prices are undisclosed — the actual $/MWh determines the NPV of these 15-20 year revenue streams.
Post-2028 hedge cliff: VST is ~100% hedged in 2026 but only ~58% in 2028. TLN drops from ~85% to ~20%. The 2028/2029 capacity auction results (not yet run) will determine whether elevated capacity prices persist or revert.
CEG's actual EBITDA: Constellation does not report adjusted EBITDA. The combined CEG+Calpine cost structure, interest expense ($22.5B debt), and nuclear PTC benefits need modeling from 10-K segments.
NRG's leverage: $23.4B debt on a $28.2B equity cap. Whether the LS Power acquisition's cash flows service and reduce that debt determines the equity outcome.
FERC co-location rules: FERC is reviewing behind-the-meter data center arrangements. Adverse rulings could affect future PPA structures, though Talen's pivot to a grid-connected retail model already addresses this.
Nuclear license renewals: CEG secured 20-year extensions for Clinton and Dresden. VST is pursuing 20-year subsequent renewals for its PJM nuclear units as part of the Meta PPA. Verify timelines and NRC approval status.

Sources & confidence

CEG: Q1 2026 earnings release (May 11, 2026); FY2025 10-K; Calpine close press release (Jan 7, 2026). Revenue ($29.9B TTM) and EBITDA ($8.0B TTM) from yfinance. 2026 adjusted operating EPS guidance ($11-12) from earnings release. EBITDA estimate derived — not directly reported by CEG. est.
VST: FY2025 earnings release (Feb 26, 2026); Q4 2025 8-K. Adjusted EBITDA $5.84B (FY2025). 2026 guidance $6.8-7.6B (excludes Cogentrix). Cogentrix details from Power Magazine (Feb 2026). Fleet capacity from company website and 10-K.
TLN: Q1 2026 earnings release (May 2026). FY2025 actual adj. EBITDA $1.04B. 2026 guidance $1.75-2.05B (excludes Cornerstone). Amazon PPA: Power Magazine (Jun 2025) and TLN earnings release.
NRG: Q1 2026 8-K (May 2026). 2026 guidance $5.3-5.8B (includes 11 months LS Power). LS Power close: press release (Jan 30, 2026). Debt: $23.4B from 10-Q. FY2025 actual EBITDA not confirmed — guided $3.9-4.0B per Q3 2025 raise; actual not retrieved. est.
PJM capacity: 2025/26 BRA ($269.92/MW-day) and 2026/27 BRA ($329.17/MW-day) from PJM press releases (Dec 2024, Jul 2025).
Data center demand: Lawrence Berkeley National Lab (Jan 2025), EIA STEO (Jan 2026).
Market data: yfinance, Jun 2, 2026. Prices, market caps, enterprise values, debt, revenue, EBITDA.

Confidence level: Company financials (capacity, EBITDA, debt, PPAs) are from primary SEC filings and earnings releases — high confidence. PJM auction prices are from official PJM reports — high confidence. Data center demand projections are from government sources (EIA, Berkeley Lab) and carry forecast uncertainty. CEG's 2026 EBITDA is an estimate, not a reported figure. NRG's FY2025 actual EBITDA was not confirmed from a primary source. Replacement cost and new-build $/kW figures are industry-level estimates.