NRG Energy (NRG)
Texas retail integrated with fossil generation: 12.3 GW owned capacity pre–LS Power, FY2025 Adjusted EBITDA of $4,087M, FCFbG of $2,210M, and ~$25.8B market cap.
Educational analysis for professional use. This profile is not investment advice or a recommendation to buy or sell any security, and it is not personalised.
Snapshot
The Texas Integrated Merchant Benchmark
NRG is the Texas-filed example of retail integrated with owned fossil generation in ERCOT: it files no consolidated power purchase agreement (PPA) or merchant percentage, so screening runs on integration and hedges instead. Pre–LS Power owned capacity was 12,276 MW at FY2025 year-end (6,345 MW coal at 52%, 5,262 MW gas at 43%, 455 MW oil at 4%, 214 MW solar at 2%). FY2025 Adjusted EBITDA was $4,087 million and FCFbG, the free-cash-flow line NRG reports in place of a yieldco's CAFD (cash available for distribution), was $2,210 million. Market capitalisation was roughly $25.8 billion as of 10 June 2026.
The model is integrated Texas retail paired with owned generation and financial or physical hedges. Pro forma post–LS Power capacity of ~25.8 GW (76% gas, 24% coal and other) is separate from FY2025 standalone fleet stats; do not blend bases when screening fuel mix or leverage.
Business Overview
NRG's retail shell sells power to Texas residential and commercial customers while the owned fleet supplies margin capture on spread between fuel, hub, and retail price. The 1.5 GW Texas Energy Fund pipeline (including Greens Bayou, a 443 MW combined-cycle gas turbine, or CCGT) adds new gas build in ERCOT, where load growth and hub volatility drive the screening case.
Net debt was approximately $11.7 billion at 31 December 2025 (total debt $16,443 million less cash $4,708 million; calculated, not a company-labelled line). Net debt divided by FY2025 Adjusted EBITDA is ~2.9× (calculated). Management targets post–LS Power leverage below 3.0×, so the standalone FY2025 ratio already sits near that ceiling before pro forma EBITDA contribution.
How the Economics Work
This site's planning assumption for ERCOT energy is $35/MWh; retail reference is 13.6¢/kWh all-sector. NRG earns on the spread between wholesale acquisition or generation cost and retail revenue, plus merchant margin on unhedged volume. Spark spread mechanics on gas plants, Henry Hub (HH) price times heat rate versus hub energy plus capacity, apply to the 43% gas pre–LS Power; coal units run on different margin drivers but the same hub-and-retail integration logic. See the spark spread guide for gas plant maths.
FCFbG funds dividends and buybacks at the C-corp level. At $2,210 million for FY2025 it converts roughly half of Adjusted EBITDA to distributable cash before growth investment, a different bridge than yieldco CAFD.
Retail integration adds semi-contracted cash flow on top of the merchant generation book, the mechanism the contracted vs merchant multiples guide teaches; NRG has no filed LTA contracted share to compare against a name like Brookfield's ~89%.
Valuation Framework
Computed EV/EBITDA on FY2025 figures was ~9.2× (enterprise value of roughly $37.5B, from market cap ~$25.8B plus net debt ~$11.7B, divided by $4,087M Adjusted EBITDA), as of 10 June 2026. LS Power pro forma ~25.8 GW shifts fuel mix toward gas (76%) and scale; screen the pro forma EBITDA and leverage once consolidated rather than adding GW to FY2025 denominators.
Capacity expansion via TEF projects is growth capex with merchant exit economics unless paired with retail load growth or hedges. Growth capex pays off only if ERCOT load and retail customer growth keep pace with TEF additions; the offsetting risk is a hub price collapse where retail churn lags the wholesale move.
Key Risks
ERCOT price volatility. Merchant margin and retail competitiveness both hinge on Texas wholesale dynamics, with no filed contracted percentage to cushion a price move.
Coal exposure pre–LS Power. 52% coal by MW on the standalone fleet faces retirement and compliance costs; pro forma dilutes coal to 24% but integration risk remains.
LS Power boundary. The acquisition completed on 30 January 2026, after the FY2025 year end, so the ~25.8 GW pro forma fleet is not in the FY2025 capacity, EBITDA, or leverage rows. Mixing distorts fuel mix and net debt/EBITDA.
Leverage at the target. ~2.9× calculated on FY2025 EBITDA approaches the <3.0× post-deal target before full pro forma earnings credit.
What the Screening Shows
Against the Renewables and IPPs Sector Primer thresholds:
- Capacity: 12.3 GW owned pre–LS Power; coal-heavy standalone. Pro forma ~25.8 GW flagged separately.
- Contract profile: Not filed; teach as retail + merchant integrated with hedges.
- Cash metric: FCFbG $2,210M (not CAFD).
- Leverage: ~2.9× net debt ÷ Adj. EBITDA (calculated). Near post-deal <3.0× target.
- Texas Energy Fund pipeline adds 1.5 GW of new gas build, including Greens Bayou 443 MW CCGT.
With no filed contract split, screening proxies retail integration and hedges rather than a filed PPA percentage. LS Power scale changes the fleet, but FY2025 standalone numbers stay the filed anchor until consolidated reporting supersedes them.
Renewables & IPPs Sector Primer
A multi-period DCF splits contracted PPA years from the merchant tail, pricing each off realised power price and term, then checks the value against spark spread and CAFD.
The Excel model is the primer's two archetype builds live across 10 sheets: a multi-period DCF with a contracted-or-merchant toggle, step-down discount rates for the PPA term and the merchant tail, a spark-spread build for the merchant case and a CAFD-and-payout bridge for the yieldco. Change the realised PPA price, the contracted discount rate or the merchant spread and the value per share moves; the premium and payout sheets update alongside it. It also splits the contracted premium into the part the pipeline explains and the part contract quality explains, splits the PV between contracted years and the merchant tail, and reads EV per kW on both archetypes.