Item 2. Properties
Item 2 — Properties
Listed below are descriptions of NRG's interests in facilities, operations and/or projects owned or leased as of December 31, 2024. The rated MW capacity figures provided represent nominal summer MW capacity of power generated. Net MW capacity is adjusted for the Company's owned or leased interest as of December 31, 2024. The Company believes its existing facilities, operations and/or projects are suitable for the conduct of its business. The following table summarizes NRG's power production and cogeneration facilities by region:
Name of Facility Power Market Plant Type Primary Fuel Location Rated MW Capacity (a)
Net MW Capacity (b)
% Owned
Texas
Cedar Bayou ERCOT Fossil Natural Gas TX 1,494 1,494 100.0
Cedar Bayou 4 ERCOT Fossil Natural Gas TX 504 252 50.0
Greens Bayou ERCOT Fossil Natural Gas TX 327 327 100.0
Limestone ERCOT Fossil Coal TX 1,660 1,660 100.0
San Jacinto ERCOT Fossil Natural Gas TX 160 160 100.0
T.H. Wharton ERCOT Fossil Natural Gas TX 1,002 1,002 100.0
W.A. Parish ERCOT Fossil Coal TX 2,514 2,514 100.0
W.A. Parish ERCOT Fossil Natural Gas TX 1,118 1,118 100.0
Total Texas 8,779 8,527
East
Chalk Point PJM Fossil Natural Gas MD 80 80 100.0
Fisk PJM Fossil Oil IL 171 171 100.0
Indian River (c)
PJM Fossil Coal DE 410 410 100.0
Indian River PJM Fossil Oil DE 16 16 100.0
Powerton (d)
PJM Fossil Coal IL 1,538 1,538 100.0
Vienna PJM Fossil Oil MD 167 167 100.0
Waukegan PJM Fossil Oil IL 101 101 100.0
Total East 2,483 2,483
West/Services/Other
Cottonwood MISO Fossil Natural Gas TX 1,139 1,139 ___(e)
Gladstone Fossil Coal AUS 1,613 605 37.5
Ivanpah (f)
CAISO Renewable Solar CA 385 210 54.5
Midway-Sunset CAISO Fossil Natural Gas CA 226 113 50.0
Stadiums and Other Renewable Solar various 4 4 100.0
Total West/Services/Other 3,367 2,071
Total Fleet 14,629 13,081
(a) MW capacity of the facility without taking into account NRG ownership percentage
(b) Actual capacity, adjusted for ownership interest, can vary depending on factors including weather conditions, operational conditions, and other factors. Additionally, ERCOT and PJM require periodic demonstration of capability, and the capacity may vary individually and in the aggregate from time to time
(c) The Company previously announced the shut down of the Indian River facility. However, PJM identified reliability impacts resulting from the proposed deactivation and Indian River Unit 4 retired on February 23, 2025
(d) Powerton is projected to close by December 31, 2028 to comply with ELG regulations
(e) NRG leases 100% interests in the Cottonwood facility through a facility lease agreement expiring in May 2025 and operates the Cottonwood facility
(f) On January 17, 2025, PG&E filed an advice letter to the CPUC seeking approval of a termination agreement between the utility and Solar Partners II, LLC and Solar Partners VIII, LLC, which include NRG’s ownership interests. If approved by the CPUC, this would result in the termination of PG&E’s PPAs with Ivanpah Units 1 and 3
NRG owns several real properties and facilities related to its generation assets, other vacant real property unrelated to its generation assets, and properties not used for operational purposes. NRG believes it has satisfactory title to its plants and facilities in accordance with standards generally accepted in the electric power industry, subject to exceptions that, in the Company's opinion, would not have a material adverse effect on the use or value of its portfolio.
NRG leases its operational and corporate headquarters in Houston, Texas, its financial and commercial corporate offices in Princeton, New Jersey, its smart home corporate offices in Provo and Lehi, Utah, as well as its retail operations offices, smart home monitoring stations, call centers, warehouses and various other office space.
42
Item 3 — Legal Proceedings
See Item 15 — Note 22, Commitments and Contingencies , to the Consolidated Financial Statements for discussion of the material legal proceedings to which NRG is a party.
Item 4 — Mine Safety Disclosures
There have been no events that are required to be reported under this Item.
43
PART II