Enterprise Products Partners L.P.

Segment rollup of ~21,430 miles of natural gas pipelines with 27,391 MMcf/d of net pipeline capacity, 1,840 MMcf/d of treating capacity and 14.1 Bcf of usable storage, plus natural gas marketing. 2025 gross operating margin of $1,558 million. Weighted-average pipeline utilization of 70.4% in 2025.

Segment rollup of natural gas processing and NGL marketing, ~18,850 miles of NGL pipelines, NGL fractionators (1,817 MBPD total capacity; 99.6% 2025 utilization), 218.5 MMBbls of NGL and related product storage, and NGL marine terminals. 2025 gross operating margin of $5,559 million. Natural gas processing facilities totaled 11,672 MMcf/d net / 12,820 MMcf/d total capacity at 67.8% weighted-average 2025 utilization. Supported by ~470 railcars and ~200 LPG tank trucks.

Segment rollup of ~5,650 miles of crude oil pipelines with 30.7 MMBbls of operational storage, crude oil terminals in Houston, Midland, Beaumont and Cushing with 44.0 MMBbls of net storage across 145 tanks, related marketing activities and a fleet of ~200 crude oil tank trucks. 2025 gross operating margin of $1,501 million. System access to ~8 MMBPD of aggregate refining capacity.

Group-level rollup of EPD's four business segments: NGL Pipelines & Services, Crude Oil Pipelines & Services, Natural Gas Pipelines & Services, and Petrochemical & Refined Products Services. Total 2025 segment gross operating margin of $10,054 million (NGL $5,559M; Crude $1,501M; Natural Gas $1,558M; Petrochemical & Refined Products $1,436M). Approximately $4.8 billion of growth capital projects scheduled for completion by end-2027. ~8,000 EPCO personnel engaged in the business.

6,010-mile Enterprise Texas and 640-mile Channel systems gathering, transporting and storing gas from the Permian, Eagle Ford and Barnett for delivery to LDCs, power plants and industrial/municipal consumers; includes the Wilson storage facility (12.9 Bcf usable). Undivided interests of 22%-80% in ~1,480 miles are proportionately consolidated. Approximately 6650 miles of pipeline.

Acadian, Acadian Haynesville Extension, Gillis Lateral and Enterprise Pelican pipelines linking Haynesville and Gulf supplies to the Baton Rouge/New Orleans/Mississippi River corridor and South Louisiana LNG markets; includes a leased 1.2 Bcf Napoleonville storage cavern. Approximately 1410 miles of pipeline.

Gathers Delaware Basin gas to regional processing plants with 270 MMcf/d of H2S/CO2 treating capacity and two high-capacity acid gas injection wells. A fourth treater at Dark Horse (+180 MMcf/d) is expected in service Q2 2026, with a fifth treater, trunk line extensions and a third AGI well announced February 2026. Approximately 2160 miles of pipeline.

Gathers Midland Basin gas for delivery to EPD's Midland Basin processing plants; expanded by the August 2025 acquisition of an Oxy affiliate owning ~200 miles of gathering pipelines for $581 million, with a long-term dedication of ~73,000 acres. Approximately 2270 miles of pipeline.

Thirteen NGL fractionators in the Mont Belvieu area (75% undivided interest in Fracs 1-3; Fracs 4-12 and 14 wholly owned) with 1,335 MBPD of total nameplate capacity, connected to ~170 MMBbls of underground salt dome storage and Houston Ship Channel/Neches River marine terminals. Frac 14 (150 MBPD nameplate, capable of up to 195 MBPD) and an associated DIB unit entered service in Q4 2025. Includes a 60 MBPD natural gasoline hydrotreater.

Gathers and treats San Juan Basin gas for delivery to interstate pipelines or the Chaco plant; nearly all transportation revenues are tied to a regional gas price index. Approximately 5530 miles of pipeline.

50% equity-method interest (Seaway Crude Holdings) in the ~1,270-mile system linking the Cushing hub to southeast Texas: the two-pipeline Longhaul System (~950 MBPD aggregate) to the Jones Creek terminal, the Freeport System marine terminal (~516 MBPD intrastate capacity) and the Texas City System (~840 MBPD) with a two-dock marine terminal loading up to 35,000 barrels per hour. 9.8 MMBbls of operational storage. Holds FERC market-based rate authority.

Marine terminal with eight deep-water ship docks and a barge dock accommodating Suezmax tankers (45-ft draft). LPG export loading capacity of ~835 MBPD with capability to load six VLGCs simultaneously; crude oil export assets capable of loading up to 2.9 MMBPD; semi-refrigerated propylene loading up to 72 MBPD; refined products operations with 2.4 MMBbls of storage; crude storage of 23.9 MMBbls across 81 tanks; NGL import capability up to 5,000 bbl/hour. The Ref 4 fourth refrigeration train (+~300 MBPD LPG capacity) is expected in service by end-2026.

Permian crude aggregation and transportation system from the Midland terminal to the ECHO terminal in Houston: the wholly owned ~420-mile Midland-to-ECHO 1 (up to ~620 MBPD), a 29% proportionately consolidated undivided interest in the ~520-mile Midland-to-Webster (Midland-to-ECHO 3, ~450 MBPD), and the wholly owned Midland-to-ECHO 2 (converted Seminole segment, up to 225 MBPD incremental, in crude service January 2026). 3.9 MMBbls of operational storage; ~1,380 total system miles; batched shipments preserve crude quality with access to every Houston/Texas City/Beaumont/Port Arthur refinery.

~1,070-mile crude gathering system, including the Loving County pipeline, connecting West Texas and southeast New Mexico gathering to the Midland terminal with transport capacity over 600 MBPD; 1.4 MMBbls of operational storage. FERC-regulated in part.

~440-mile system with capacity of ~450 MBPD transporting South Texas crude and condensate to Houston-area customers; includes Lyssy, Milton, Marshall and Sealy storage terminals (5.6 MMBbls operational storage) and the ~90-mile Rancho II pipeline from Sealy to ECHO.

Eagle Ford Shale system providing condensate gathering and processing plus gathering, treating and compression for associated gas: ~500 miles of gathering pipelines, 11 central gathering plants with 0.3 MMBbls of condensate storage, 201 MBPD of condensate stabilization capacity and 1.0 Bcf/d of associated natural gas treating capacity.

Six propylene fractionation units (66.7% undivided interest in three splitters totaling 41 MBPD; three wholly owned) with 88 MBPD of total capacity producing polymer grade propylene, integrated with the PDH facilities; combined system capable of producing an aggregate 11 billion pounds of propylene per year. 2025 weighted-average utilization of propylene production facilities was 79.6%.

~1,620 miles of propylene pipelines: Texas RGP Gathering System (700 mi), Lou-Tex Propylene (270 mi), North Dean (250 mi), Propylene Splitter PGP Distribution System (150 mi), Taurus (120 mi, 70% via Steor LLC), Louisiana RGP Gathering (60 mi), Lake Charles PGP (30 mi, 50% undivided), Sabine (20 mi) and La Porte PGP (20 mi, 80%). EHT propylene export assets can load up to 72 MBPD of semi-refrigerated propylene.

Refined products system using ~1,260 miles of pipeline to move products from Beaumont/Baytown terminals and the Mont Belvieu complex to the Permian Terminal (West Texas), Jal and Moriarty Terminals (New Mexico) and Grand Junction Terminal (Utah), which together offer 2.0 MMBbls of refined products storage and can load up to 63 MBPD.

Marine transportation business of 64 tow boats and 156 tank barges moving refined products, crude oil, asphalt, condensate, heavy fuel oil, LPG and other petroleum products on the Mississippi River, the Texas-Florida intracoastal waterway and the Tennessee-Tombigbee system; includes shipyard/repair facilities at Houma and Morgan City, Louisiana and fleeting facilities at Bourg, Louisiana and Channelview, Texas. 2025 average utilization of 91.1%.

~2,770-mile refined products and NGL system (2,650 miles FERC-regulated interstate; 120 miles Texas intrastate) from the upper Texas Gulf Coast to Seymour, Indiana, with extensions to Chicago, Lima, Selkirk and near Philadelphia; primarily NGL service east of Seymour. Includes five non-regulated refined products truck terminals and access to ~21.6 MMBbls of aggregate storage.

Ethane export terminal with a nameplate loading capacity of ~10,000 barrels per hour of fully refrigerated ethane, sourced from the Mont Belvieu complex. A December 2025 project added 0.9 MMBbls of incremental storage; one 120 MBPD refrigeration train can refrigerate either ethane or ethylene for operational flexibility. Co-located with the 50%-owned ethylene export terminal.

Gathers gas from the Jonah and Pinedale fields in the Greater Green River Basin for delivery to regional processing plants including Pioneer. Approximately 780 miles of pipeline.

Gathers Piceance Basin gas to the Meeker processing plant; includes the Central Treating Facility (200 MMcf/d treating) in Rio Blanco County. Approximately 200 miles of pipeline.

Natural gas processing facility serving the Piceance production region with 1600 MMcf/d of total nameplate processing capacity.

50% equity-method natural gas hub serving Piceance producers with access to six interstate pipelines; gross throughput capacity of 3 Bcf/d. FERC-regulated. Approximately 10 miles of pipeline.

Gathers and treats gas from the Haynesville/Bossier, Cotton Valley and Travis Peak formations (240 MMcf/d treating); includes the Fairplay Gathering System and ~60 miles of leased pipelines. Approximately 810 miles of pipeline.

Natural gas processing facility serving the Green River production region with 1400 MMcf/d of total nameplate processing capacity.

Gathers and treats Haynesville/Bossier and Cotton Valley/Taylor Sand gas (810 MMcf/d treating) for delivery to regional markets including the Acadian system. Approximately 360 miles of pipeline.

Natural gas processing facility serving the Gulf of Mexico production region with 1000 MMcf/d of total nameplate processing capacity.

Natural gas processing facility serving the Delaware production region with 900 MMcf/d of total nameplate processing capacity.

Natural gas processing facility serving the Delaware production region with 900 MMcf/d of total nameplate processing capacity.

Natural gas processing facility serving the Eagle Ford production region with 900 MMcf/d of total nameplate processing capacity.

Natural gas processing facility serving the Gulf of Mexico production region with 750 MMcf/d of total nameplate processing capacity.

Natural gas processing facility serving the San Juan production region with 700 MMcf/d of total nameplate processing capacity.

Natural gas processing facility serving the Gulf of Mexico production region with 650 MMcf/d of total nameplate processing capacity.

600 MBPD design-capacity NGL pipeline from the Delaware and Midland basins to Mont Belvieu, placed into service December 2025; 40% undivided interest sold to ExxonMobil for ~$655 million with a joint expansion to 1.0 MMBPD and the 92-mile Cowboy Extension (30% EPD interest) expected in Q4 2027; EPD operates the combined system. Approximately 550 miles of pipeline.

50% equity-method interest in a non-operated, effectively looped ~390-mile crude and condensate system from Gardendale to Corpus Christi with capacity over 600 MBPD of light and medium grades; 4.5 MMBbls of gross operational storage; connects to the Corpus Christi marine terminal.

Joint expansion with ExxonMobil adding 400 MBPD of pumping capacity to the Bahia NGL Pipeline (raising total capacity to 1.0 MMBPD) and construction of the 92-mile Cowboy Extension from ExxonMobil's Cowboy gas plant in Eddy County, New Mexico to Bahia's Delaware Basin origin, also connecting multiple EPD processing plants. EPD will own a 30% undivided interest in the Cowboy Extension and operate the combined system. Expected completion in the fourth quarter of 2027.

Natural gas processing facility serving the Eagle Ford production region with 330 MMcf/d of total nameplate processing capacity.

Ninth Midland Basin natural gas processing train under construction, with capacity to process 300 MMcf/d of natural gas and extract over 40 MBPD of NGLs, supported by long-term acreage dedication agreements. Expected in service in the fourth quarter of 2026.

Fourth refrigeration train at the Enterprise Hydrocarbons Terminal, announced July 2024, increasing propane and butane export capability by approximately 300 MBPD, raising instantaneous LPG loading rates and freeing capacity for propylene exports. Expected in service by the end of 2026.

Natural gas processing facility serving the Midland production region with 300 MMcf/d of total nameplate processing capacity.

Natural gas processing facility serving the Delaware production region with 300 MMcf/d of total nameplate processing capacity. First train placed into service in Q3 2025; a second 300 MMcf/d train is under construction for Q1 2026 service.

Second natural gas processing train under construction at the Mentone West location, with capacity to process 300 MMcf/d of natural gas and extract over 40 MBPD of NGLs, supported by long-term acreage dedication agreements and minimum volume commitments. Expected in service in the first quarter of 2026.