About Enterprise Products Partners L.P.

Enterprise Products Partners L.P. provides midstream energy services to producers and consumers of natural gas, natural gas liquids (NGLs), crude oil, petrochemicals and refined products in North America. The company is owned by its limited partners (preferred and common unitholders) from an economic perspective. Enterprise GP, which owns a non-economic general partner interest in the company, manages the company’s Partnership. The company conducts substantially all of its business operations through EPO (Enterprise Products Operating LLC) and its consolidated subsidiaries. The company’s fully integrated, midstream energy asset network (or ‘value chain’) links producers of natural gas, NGLs and crude oil from some of the largest supply basins in the United States (‘U.S.’), Canada and the Gulf of Mexico with domestic consumers and international markets. The company’s midstream energy operations include natural gas gathering, treating, processing, transportation and storage; NGL transportation, fractionation, storage, and marine terminals (including those used to export liquefied petroleum gases (‘LPG’) and ethane); crude oil gathering, transportation, storage, and marine terminals; propylene production facilities (including propane dehydrogenation (‘PDH’) facilities), butane isomerization, octane enhancement, isobutane dehydrogenation (‘iBDH’) and high purity isobutylene (‘HPIB’) production facilities; petrochemical and refined products transportation, storage, and marine terminals (including those used to export ethylene and polymer grade propylene (‘PGP’)); and a marine transportation business that operates on key U.S. inland and intracoastal waterway systems. The company’s business strategy seeks to manage these operations to capitalize on expected trends and opportunities in all energy supply and demand cycles to provide value added services to the company’s customers; maintain a diversified portfolio of midstream energy assets and expand this asset base through growth capital projects and accretive acquisitions of complementary assets that enhance the company’s overall value chain; and share risks through business ventures or alliances with strategic partners, including those that provide incremental volumes on the company’s systems. Business Segments The company’s operations are reported under four business segments: NGL Pipelines & Services, Crude Oil Pipelines & Services, Natural Gas Pipelines & Services and Petrochemical & Refined Products Services. NGL Pipelines & Services segment This business segment includes the company’s natural gas processing and related NGL marketing activities, NGL pipelines, NGL fractionation facilities, NGL and related product storage facilities, and NGL marine terminals. Natural Gas Processing and Related NGL Marketing Activities At the core of the company’s natural gas processing business are processing facilities located in Colorado, Louisiana, Mississippi, New Mexico, Texas and Wyoming. In its raw form, natural gas produced at the wellhead (especially in association with crude oil production) contains varying amounts of NGLs, such as ethane and propane. Natural gas streams containing NGLs and other impurities are usually not acceptable for transportation in downstream natural gas transmission pipelines or for commercial use as fuel; therefore, the unprocessed natural gas stream must be transported to a natural gas processing facility to remove the NGLs and other impurities. Once the natural gas is processed and the NGLs and impurities are removed, the residue natural gas meets downstream natural gas pipeline and commercial quality specifications. In general, on an energy-equivalent basis, NGLs have greater economic value as feedstock for petrochemical and motor gasoline production than as components of a natural gas stream. Typical uses of NGLs include the following: Ethane is primarily used in the petrochemical industry as a feedstock in the production of ethylene, one of the basic building blocks for a wide range of plastics and other chemical products. Propane is used for heating, as an engine and industrial fuel, and as a petrochemical feedstock in the production of ethylene and propylene. Normal butane is used as a petrochemical feedstock in the production of ethylene and butadiene (a key ingredient of synthetic rubber), as a blendstock for motor gasoline, and to produce isobutane through isomerization. Isobutane is fractionated from mixed butane (a mixed stream of normal butane and isobutane) or produced from normal butane through the process of isomerization, and is used in refinery alkylation to enhance the octane content of motor gasoline, in the production of isooctane and other octane additives, and in the production of propylene oxide. Natural gasoline, a mixture of pentanes and heavier hydrocarbons, is primarily used as a blendstock for motor gasoline, diluent in crude oil to aid in transportation, and as a petrochemical feedstock. The results of operations from natural gas processing are primarily dependent on the difference between the revenues the company earns from extracting NGLs (in terms of cash processing fees and/or the value of any retained NGLs) and the cost of natural gas and other operating costs incurred in connection with such extraction activities. Natural gas processing utilizes service contracts that are either fee-based, commodity-based or a combination of the two. The company’s commodity-based contracts include keepwhole, margin-band, percent-of-liquids, percent-of-proceeds and contracts featuring a combination of commodity and fee-based terms. To the extent the company retains all or a portion of the extracted NGLs as consideration for the company’s processing services, the company refers to such volumes as its ‘equity NGL-equivalent production’. The company’s NGL marketing activities entail spot and term sales of NGLs that it takes title to through the company’s natural gas processing activities (i.e., the company’s equity NGL-equivalent production) and open market and contract purchases. The company operates all of its natural gas processing facilities except for the Venice plant. Midland Basin Natural Gas Processing Facility: The Midland Basin natural gas processing facility consists of five natural gas processing plants, which includes four natural gas processing plants (Newberry I, Newberry II, Trident and Taylor) that the company acquired as part of its acquisition of Navitas Midstream Partners, LLC (‘Navitas Midstream’) in February 2022 and a fifth natural gas processing plant (Leiker), which the company completed construction of and placed into service in March 2022. During 2022, the company announced plans to construct two new natural gas processing plants in the Midland Basin, Poseidon and Leonidas, which are expected to be placed into service in the third quarter of 2023 and first quarter of 2024, respectively. Each of these plants will have the capacity to process 300 MMcf/d of natural gas and extract over 40 MBPD of NGLs and are supported by long-term acreage dedication agreements. Once the Poseidon and Leonidas plants are completed and placed into service, the company expects to have an aggregate 1.6 Bcf/d of natural gas processing capacity and more than 220 MBPD of NGL production capacity from the company’s natural gas processing facility in the Midland Basin. Delaware Basin Natural Gas Processing Facility: During 2022, the company announced plans to construct two additional natural gas processing plants in the Delaware Basin, the Mentone II and III plants, which are expected to be placed into service in the fourth quarter of 2023 and first quarter of 2024, respectively. Each of these plants will have the capacity to process 300 MMcf/d of natural gas and extract 40 MBPD of NGLs and are supported by long-term capacity agreements. When the Mentone II and III plants are completed and placed into service, the company expects to have an aggregate 2.2 Bcf/d of natural gas processing capacity and more than 300 MBPD of NGL production capacity from the company’s natural gas processing facility in the Delaware Basin. The company’s NGL marketing activities utilize a fleet of approximately 480 railcars, the majority of which are leased from third parties. These railcars are used to deliver feedstocks to the company’s facilities and to distribute NGLs throughout the U.S. and parts of Canada. The company has rail loading and unloading capabilities at certain of the company’s terminal facilities in Arizona, Kansas, Louisiana, Minnesota, Mississippi, New York, North Carolina and Texas. These facilities service both the company’s rail shipments and those of its customers. The company’s NGL marketing activities also utilize a fleet of approximately 180 tractor-trailer tank trucks that are used to transport LPG for the company and on behalf of third parties. The company leases and operates the majority of these trucks and trailers. NGL Pipelines The company’s NGL pipelines transport mixed NGLs from natural gas processing facilities, refineries and marine terminals to downstream fractionation plants and storage facilities; gather and distribute purity NGL products to and from fractionation plants, storage and terminal facilities, petrochemical plants, refineries and export facilities; and deliver propane and ethane to destinations along the company’s pipeline systems. The results of operations from the company’s NGL pipelines are primarily dependent upon the volume of NGLs transported (or capacity reserved) and the associated fees the company charge for such transportation services. Transportation fees charged to shippers are based on either tariffs regulated by governmental agencies, including the Federal Energy Regulatory Commission (‘FERC’), or contractual arrangements. The company operates its NGL pipelines with the exception of the Texas Express Gathering System. The following information describes the company’s principal NGL pipelines: The Mid-America Pipeline System is an NGL pipeline system consisting of the 3,119-mile Rocky Mountain pipeline, the 2,023-mile Conway North pipeline, the 632-mile Ethane-Propane (‘EP’) Mix pipeline, and the 2,088-mile Conway South pipeline. The Rocky Mountain pipeline transports mixed NGLs from production fields located in the Rocky Mountain Overthrust and San Juan Basin to the Hobbs NGL hub located on the Texas-New Mexico border. The Conway North segment links the NGL hub at Conway, Kansas to refineries, petrochemical plants and propane markets in the upper Midwest. NGL hubs provide buyers and sellers with a centralized location for the storage and pricing of products, while also providing connections to intrastate and/or interstate pipelines. The EP Mix segment transports EP mix from the Conway hub to petrochemical plants in Iowa and Illinois. The Conway South pipeline connects the Conway hub with Kansas refineries and provides bi-directional transportation of NGLs between the Conway and Hobbs hubs. At the Hobbs NGL hub, the Mid-America Pipeline System interconnects with the company’s Seminole NGL Pipeline and Hobbs NGL fractionation and storage facility. The Mid-America Pipeline System is also connected to 18 non-regulated NGL terminals that the company owns and operates. The South Texas NGL Pipeline System is a network of NGL gathering and transportation pipelines located in South Texas that gather and transport mixed NGLs from natural gas processing facilities (owned by either the company or third parties) to the company’s NGL fractionators located in South Texas and in Chambers County, Texas. In addition, this system transports purity NGL products from the company’s South Texas NGL fractionators to refineries and petrochemical plants located between Corpus Christi, Texas and Houston, Texas and within the Texas City-Houston area, as well as to interconnects with other NGL pipelines and to the company’s Chambers County storage complex. The South Texas NGL Pipeline System extends the company’s ethane header system from Chambers County, Texas to Corpus Christi, Texas. The Dixie Pipeline transports propane and other NGLs from locations in southeast Texas, south Louisiana and Mississippi to markets in the southeastern U.S. The Dixie Pipeline operates in seven states: Alabama, Georgia, Louisiana, Mississippi, North Carolina, South Carolina and Texas; and is connected to eight non-regulated propane terminals that the company owns and operates. The Appalachia-to-Texas Express, or ATEX, pipeline transports ethane in southbound service from third-party owned NGL fractionation plants located in Ohio, Pennsylvania and West Virginia to the company’s Chambers County storage complex. Ethane originating at these fractionation facilities is sourced from the Marcellus and Utica Shale production areas. ATEX operates in nine states: Arkansas, Illinois, Indiana, Louisiana, Missouri, Ohio, Pennsylvania, Texas and West Virginia. The Chaparral NGL System transports mixed NGLs from natural gas processing facilities located in West Texas and New Mexico to Chambers County, Texas. This system consists of the 906-mile Chaparral pipeline and the 179-mile Quanah pipeline. Interstate and intrastate transportation services provided by the Chaparral pipeline are regulated; however, transportation services provided by the Quanah pipeline are not. The Louisiana Pipeline System is a network of NGL pipelines that transport NGLs originating in Louisiana and Texas to refineries and petrochemical plants located along the Mississippi River corridor in southern Louisiana. This system also provides transportation services for the company’s natural gas processing facilities, NGL fractionators and other assets located in Louisiana. The Seminole NGL Pipeline transports NGLs from the Hobbs hub and the Permian Basin to markets in southeast Texas, including the company’s Chambers County NGL fractionation complex. NGLs originating on the Mid-America Pipeline System are a significant source of throughput for the Seminole NGL Pipeline. The Shin Oak NGL Pipeline transports NGL production from Orla, Texas in the Permian Basin to the company’s Chambers County NGL fractionation and storage complex. In August 2022, the company announced plans to expand its Shin Oak NGL Pipeline transportation capacity by up to 275 MBPD to approximately 825 MBPD. The company anticipates that this expansion project will be completed in the first half of 2025. The Texas Express Pipeline extends from Skellytown, Texas to the company’s Chambers County NGL fractionation and storage complex. Mixed NGLs from production fields located in the Rocky Mountains, Permian Basin and Mid-Continent regions are delivered to the Texas Express Pipeline via an interconnect with the company’s Mid-America Pipeline System near Skellytown. In addition, the Texas Express Pipeline transports mixed NGLs gathered by the Texas Express Gathering System. Also, mixed NGLs originating from the Denver-Julesburg (‘DJ’) Basin in Colorado are transported to the Texas Express Pipeline using the Front Range Pipeline. The Skelly-Belvieu Pipeline transports mixed NGLs from Skellytown, Texas to Chambers County, Texas. The Skelly-Belvieu Pipeline receives a significant quantity of NGLs through an interconnect with the company’s Mid-America Pipeline System at Skellytown. The Front Range Pipeline transports mixed NGLs from natural gas processing facilities located in the DJ Basin in Colorado to an interconnect with the company’s Texas Express Pipeline, Mid-America Pipeline System and other third-party facilities located at Skellytown, Texas. The Houston Ship Channel Pipeline System connects the company’s Chambers County, Texas assets to its marine terminals on the Houston Ship Channel and to area petrochemical plants, refineries and other pipelines. The Panola Pipeline transports mixed NGLs from injection points near Carthage, Texas to Chambers County, Texas and supports the Haynesville and Cotton Valley crude oil and natural gas production areas. The Rio Grande Pipeline transports mixed NGLs from near Odessa, Texas to a pipeline interconnect at the Mexican border south of El Paso, Texas. The Aegis Ethane Pipeline (‘Aegis’) delivers purity ethane to petrochemical facilities located along the southeast Texas and Louisiana Gulf Coast. Aegis, when combined with the company’s Enterprise Ethane Pipeline and a portion of its South Texas NGL Pipeline System, forms an ethane header system stretching from Corpus Christi, Texas to the Mississippi River in Louisiana. The Lou-Tex NGL Pipeline transports mixed NGLs, purity NGL products and refinery grade propylene (‘RGP’) between the Louisiana and Texas markets. NGL Fractionation and Related Facilities The company’s NGL fractionators separate mixed NGLs into purity NGL products for third-party customers and the company’s NGL marketing activities. Mixed NGLs extracted by domestic natural gas processing facilities represent the largest source of volumes processed at the company’s NGL fractionators. The results of operations from the company’s NGL fractionation business are generally dependent upon the volume of mixed NGLs fractionated and either the level of fractionation fees charged (under fee-based contracts) or the value of NGLs received (under percent-of-liquids arrangements). Under fee-based fractionation contracts, customers retain title to the NGLs that the company processes for them. Under percent-of-liquids fractionation contracts, the company retains a portion of the purity NGLs the company separates for customers and are exposed to commodity price risk through fluctuations in NGL prices. The following information describes the company’s principal NGL fractionators, all of which the company operates: The company owns and operates NGL fractionators located in Chambers County, Texas. These fractionators process mixed NGLs from several major NGL supply basins in North America, including the Permian Basin, Rocky Mountains, Eagle Ford Shale, Mid-Continent and San Juan Basin. The company’s Chambers County NGL fractionators are connected to the company’s network of NGL supply and distribution pipelines, approximately 130 MMBbls of underground salt dome storage capacity, along with access to international markets through the company’s marine terminals located on the Houston Ship Channel. In April 2022, the company announced plans to construct a twelfth NGL fractionator (‘Frac XII’) in Chambers County, Texas. Frac XII is expected to be capable of processing 150 MBPD of NGLs and enter service in the third quarter of 2023. Completion of this fractionator is expected to increase the company’s total Chambers County NGL fractionation capacity to approximately 1.2 MMBPD. The Shoup and Armstrong NGL fractionators in South Texas process mixed NGLs supplied by regional natural gas processing facilities. Purity NGL products from these fractionators are transported to local markets in the Corpus Christi area and also to Chambers County, Texas using the company’s South Texas NGL Pipeline System. The Hobbs NGL fractionator serves NGL producers in West Texas, New Mexico, Colorado and Wyoming. This fractionator receives mixed NGLs from several major supply basins, including the Mid-Continent, Permian Basin, San Juan Basin and Rocky Mountains. The facility is located at the interconnect of the company’s Mid-America Pipeline System and Seminole NGL Pipeline, thus providing customers access to the Conway hub and Chambers County, Texas. The Norco NGL fractionator receives mixed NGLs from refineries and natural gas processing facilities located in southern Louisiana and along the Mississippi and Alabama Gulf Coast, including the company’s Pascagoula and Venice facilities. The company also owns and operates a 60 MBPD natural gasoline hydrotreater facility at the company’s Chambers County complex along with related storage and pipeline infrastructure, which is designed to lower the sulfur content of natural gasoline. NGL and Related Product Storage Facilities The company utilizes underground salt dome storage caverns and above-ground storage tanks to store mixed and purity NGLs, petrochemicals and related products that are owned by the company and its customers. The results of operations from the company’s storage facilities are dependent upon the level of storage capacity reserved by customers, the volume of product delivered into and withdrawn from storage, and the fees associated with each activity. The company operates substantially all of the company’s NGL and related product storage facilities. The company’s largest underground storage facility is located in Chambers County, Texas. This facility consists of 38 underground salt dome caverns used to store and redeliver mixed and purity NGLs, petrochemicals and related products. This facility has an aggregate usable storage capacity of 129.8 MMBbls, a brine system with approximately 36 MMBbls of above-ground brine storage capacity and five wells used in brine production. NGL Marine Terminals and Related Operations The company owns and operates marine terminals (export and import) that handle NGLs. The results of operations from the company’s NGL marine terminals, all of which are located on the Houston Ship Channel, are primarily dependent upon the level of volumes handled (loading and unloading) and the associated fees the company charges for such services. The following information describes the company’s Houston Ship Channel terminals: The Enterprise Hydrocarbons Terminal (‘EHT’) provides terminaling services to exporters, marketers, distributors, chemical companies and major integrated oil companies. EHT has extensive waterfront access consisting of eight deep-water ship docks and a barge dock. The terminal can accommodate vessels with up to a 45 foot draft, including Suezmax tankers, which are the largest tankers that can navigate the Houston Ship Channel. The company’s location on the Houston Ship Channel enables the company to handle larger vessels than the company’s competitors because the company’s waterfront has fewer draft and beam (width) restrictions. The size and structure of the company’s waterfront allows the company to receive and unload products for the company’s customers and provide terminaling services. EHT can load refrigerated cargoes of low-ethane propane and/or butane (collectively referred to as LPG) onto multiple tanker vessels simultaneously. The company’s LPG export services continue to benefit from increased NGL supplies produced from domestic shale plays, international demand for propane as a feedstock in ethylene and propylene production, and for power generation and heating purposes. The estimated maximum loading capacity for LPG at EHT is approximately 835 MBPD. EHT has the capability to load up to six Very Large Gas Carrier (‘VLGC’) vessels simultaneously, while maintaining the option to switch between loading propane and butane. The primary customer of EHT is the company’s NGL marketing group, which uses the terminal to meet the needs of export customers. NGL marketing transacts with these customers using long-term sales contracts with take-or-pay provisions and/or exchange agreements. EHT also includes an NGL import terminal. This import terminal can offload NGLs from tanker vessels at rates up to 8,000 barrels per hour depending on the product. The company’s NGL import volumes for the last three years were minimal. EHT also provides terminaling services involving crude oil, propylene and refined products. EHT’s assets and activities associated with crude oil terminaling and storage are a component of the company’s Crude Oil Pipelines & Services business segment. EHT’s activities involving propylene and refined products are a component of the company’s Petrochemical & Refined Products Services business segment. The Morgan’s Point Ethane Export Terminal, located on the Houston Ship Channel, has a nameplate loading capacity of approximately 10,000 barrels per hour of fully refrigerated ethane and is the largest of its kind in the world. The terminal supports domestic production of the U.S. ethane from shale plays by providing the global petrochemical industry with access to a feedstock option and opportunities for supply diversification. Ethane volumes handled by the terminal are sourced from the company’s Chambers County NGL fractionation and storage complex. Ethane loading volumes at the terminal averaged 168 MBPD during the year ended December 31, 2022. In April 2022, the company announced plans to build a new Ethane Export Terminal, which will be located in Orange County, Texas. The project is expected to be completed in 2025. Crude Oil Pipelines & Services segment This business segment includes the company’s crude oil pipelines, crude oil storage and marine terminals, and related crude oil marketing activities. Crude oil Pipelines The company has crude oil gathering and transportation pipelines located in Oklahoma, New Mexico and Texas. The results of operations from the company’s crude oil pipelines are primarily dependent upon the volume of crude oil transported (or capacity reserved) and the associated fees the company charge for such transportation services. Transportation fees charged to shippers are based on either tariffs regulated by governmental agencies, including the FERC, or contractual arrangements. The company operates its crude oil pipelines with the exception of the Basin Pipeline, Eagle Ford Crude Oil Pipeline System and Midland-to-ECHO 3 Pipeline. The following information describes the company’s principal crude oil pipelines: The Midland-to-ECHO System supports Permian Basin crude oil production by providing producers and other shippers with transportation solutions that are both cost-efficient and operationally flexible. After aggregating crude at the company’s Midland terminal, the system has the capability to transport multiple grades of crude oil, including West Texas Intermediate (‘WTI’), WTI light sweet crude oil (‘West Texas Light’), West Texas Sour, and condensate, to the company’s Enterprise Crude Houston (‘ECHO’) storage terminal (using batched shipments to safeguard crude quality) for further delivery to markets along the Gulf Coast. Using the ECHO terminal, shippers on the Midland-to-ECHO System have access to every refinery in Houston, Texas City, Beaumont and Port Arthur, Texas, as well as the company’s crude oil export terminal facilities. The Midland-to-ECHO 1 Pipeline originates at the company’s Midland terminal and extends 418 miles to its Sealy storage terminal. Volumes arriving at Sealy are then transported to the company’s ECHO terminal using the Rancho II pipeline, which is a component of the company’s South Texas Crude Oil Pipeline System. The Midland-to-ECHO 1 Pipeline has an approximate maximum transportation capacity of up to 620 MBPD, depending on certain operational variables. The Midland-to-ECHO 2 Pipeline originates at the company’s Midland terminal and extends 444 miles to the company’s Sealy terminal, with crude oil volumes arriving at Sealy transported to the company’s ECHO terminal using the Rancho II pipeline. The Midland-to-ECHO 2 Pipeline was created by converting the Midland-to-Sealy segment of one of the company’s two Seminole NGL pipelines from NGL service to crude oil service. The company retains the flexibility to convert this pipeline back to NGL service should future market conditions support the need for additional NGL transportation capacity out of the Permian Basin. The Midland-to-ECHO 2 Pipeline has an approximate maximum transportation capacity of up to 225 MBPD, depending on certain operational variables. The Midland-to-ECHO 3 Pipeline is consisted of a 36-inch pipeline extending from Midland, Texas to the company’s ECHO terminal, and further from ECHO to a third-party terminal in Webster, Texas (collectively, the ‘Midland-to-Webster pipeline’). The maximum transportation capacity on the Midland-to-Webster pipeline is approximately 450 MBPD. The Seaway Pipeline connects the Cushing, Oklahoma crude oil hub with markets in southeast Texas. The Seaway Pipeline is consisted of the Longhaul System, the Freeport System and the Texas City System. The Cushing hub is an industry trading hub and price settlement point for WTI crude oil on the New York Mercantile Exchange (‘NYMEX’). The Longhaul System consists of two approximately 500-mile, 30-inch diameter pipelines (Seaway I and the Seaway Loop) that provide north-to-south transportation of crude oil from the Cushing hub to Seaway’s Jones Creek terminal located near Freeport, Texas. The aggregate transportation capacity of the Longhaul System is approximately 950 MBPD, depending on the type and mix of crude oil being transported and other variables. The Jones Creek terminal is connected by pipeline to the company’s ECHO terminal, which enables Seaway to serve a variety of customers along the upper Texas Gulf Coast, including the Beaumont/Port Arthur area. The Freeport System consists of a marine terminal that facilitates both crude oil imports and exports, along with pipelines that transport crude oil to and from Freeport, Texas and the Jones Creek terminal. The Texas City System consists of a marine terminal and storage tanks, various pipelines and related infrastructure used to transport crude oil to refineries in the Texas City, Texas area and to and from terminals in the Galena Park, Texas area, the company’s ECHO terminal and locations along the Houston Ship Channel. The Texas City System also receives production from certain offshore Gulf of Mexico developments. The intrastate pipeline transportation capacity of the Freeport System and Texas City System is approximately 480 MBPD and 800 MBPD, respectively. Seaway’s Texas City marine terminal features two docks, a 45-foot draft, an overall length of 1,125 feet, a 200-foot beam (width) and the capacity to load crude oil at a rate of 35,000 barrels per hour. The company has used Seaway’s Texas City terminal to partially load Very Large Crude Carrier (‘VLCC’) tankers, with the remaining volumes subsequently loaded on such vessels using lightering operations in the Gulf of Mexico. The West Texas System connects crude oil gathering systems in West Texas and southeast New Mexico to the company’s terminal facility located in Midland, Texas. The West Texas System, including the Loving County pipeline, is a key part of the company’s strategic crude oil aggregation program designed to support Permian Basin producers with a transport capacity over 600 MBPD. At Midland, shippers have access to storage and terminal services, as well as connectivity to multiple transportation alternatives, such as trucking and pipeline infrastructure that offer access to various downstream markets, including the Gulf Coast. The Basin Pipeline transports crude oil from the Permian Basin in West Texas and southern New Mexico to the Cushing hub. The EFS Midstream System serves producers in the Eagle Ford Shale by providing condensate gathering and processing services, as well as gathering, treating and compression services for associated natural gas. The EFS Midstream System includes 500 miles of gathering pipelines, 11 central gathering plants having a combined condensate storage capacity of 0.3 MMBbls, 201 MBPD of condensate stabilization capacity and 1.0 Bcf/d of associated natural gas treating capacity. The South Texas Crude Oil Pipeline System has the capacity to transport approximately 450 MBPD of crude oil and condensate originating in South Texas to customers in the Houston area. This system includes storage terminal assets located at Lyssy, Milton, Marshall and Sealy, Texas. The South Texas Crude Oil Pipeline System also includes the company’s Rancho II pipeline, which extends 89-miles from the Sealy terminal to the company’s ECHO terminal. From ECHO, the company has connectivity to refinery customers and the company’s marine terminals along the Texas Gulf Coast. The Eagle Ford Crude Oil Pipeline System transports crude oil and condensate for producers in South Texas. The system, which is effectively looped and has a capacity to transport over 600 MBPD of light and medium grades of crude oil, consists of 390 miles of crude oil and condensate pipelines originating in Gardendale, Texas and extending to Corpus Christi, Texas. The system interconnects with the company’s South Texas Crude Oil Pipeline System in Wilson County, Texas and the company’s Corpus Christi marine terminal. Crude Oil Terminals In addition to the operational storage capacity associated with the company’s crude oil pipelines, the company owns and operates crude oil terminals located in Houston, Midland and Beaumont, Texas and Cushing, Oklahoma that are used to store crude oil for the company and its customers. In conjunction with other aspects of the company’s midstream network, its crude oil terminals provide Gulf Coast refiners with an integrated system featuring supply diversification, significant storage capabilities and a high capacity pipeline distribution system. The company’s system has access to an aggregate refining capacity of approximately 8 MMBPD. The following information describes the company’s principal crude oil terminals, all of which the company operates with the exception of the Corpus Christi terminal. The EHT marine terminal located on the Houston Ship Channel includes export assets capable of loading up to 2.0 MMBPD, or 62 MMBbls per month, of crude oil. The crude oil terminal at EHT represents one of the largest such facilities on the Gulf Coast. As noted previously, EHT can accommodate vessels with up to a 45-foot draft, including Suezmax tankers, which are the largest tankers that can navigate the Houston Ship Channel. The ECHO terminal is located in Houston, Texas and provides storage customers with access to major refineries located in the Houston, Texas City and Beaumont/Port Arthur areas. Beginning in March 2022, the ECHO terminal became one of two physical delivery points for the Midland WTI American Gulf Coast futures contract (‘HOU’) traded on the Intercontinental Exchange (‘ICE’). ECHO also has connections to marine terminals, including EHT, that provide access to any refinery on the U.S. Gulf Coast and international markets. The Beaumont Marine West terminal is located on the Neches River near Beaumont, Texas. This terminal includes three deep-water docks and one barge dock that facilitate the exporting and importing of crude oil and related products. The Cushing terminal is located at the Cushing hub in Oklahoma and provides crude oil storage, pumpover and trade documentation services. This terminal is one of the origination points for the company’s Seaway Pipeline. The Midland terminal provides crude oil storage, pumpover and trade documentation services. The Midland terminal is the origination point for the company’s Midland-to-ECHO pipelines. The Corpus Christi terminal, located in Corpus Christi, Texas, is capable of loading ocean-going vessels with either crude oil or condensate. The terminal includes one deep-water ship dock and serves Eagle Ford Shale and Permian Basin producers through a connection with the company’s Eagle Ford Crude Oil Pipeline System. Sea Port Oil Terminal: In January 2019, the company filed its application for regulatory permitting of the company’s Sea Port Oil Terminal (‘SPOT’) in the Gulf of Mexico with the Department of Transportation’s Maritime Administration. SPOT would consist of proposed onshore and offshore facilities, including a fixed platform located approximately 30 nautical miles off the Texas coast in approximately 115 feet of water. SPOT is designed to load VLCCs and other crude oil tankers at rates of approximately 85,000 barrels per hour. The platform would be connected to an onshore storage facility with approximately 4.8 MMBbls of capacity in Brazoria County, Texas, by two 36-inch, bi-directional pipelines. The SPOT project includes state-of-the-art pipeline control, vapor recovery and leak detection systems that are designed to minimize emissions. SPOT would provide customers with an integrated export solution that leverages the company’s extensive supply, storage and distribution network along the Gulf Coast. In November 2022, the company received a favorable Record of Decision (‘ROD’) from the Department of Transportation’s Maritime Administration in accordance with the provisions of the Deepwater Port Act of 1974. The receipt of the ROD is a significant milestone in the process to obtain a license for SPOT under the Deepwater Port Act. Remaining conditions that the company must address and satisfy to obtain approval for the license issuance include routine construction, operating and decommissioning guarantees, submission of public outreach, wetland restoration and volatile organic compound (‘VOC’) monitoring plans, and other state approvals. The company expects to satisfy these remaining conditions in 2023; however, the company can give no assurance as to when or whether the project will ultimately be authorized to begin construction or operation. The company continues to commercialize this project in order to support a final investment decision, which is subject to the execution of long-term customer contracts and receiving a license to construct and operate the facility. Crude Oil Marketing Activities The company’s crude oil marketing activities generate revenues from the sale and delivery of crude oil and condensate purchased either directly from producers or from others on the open market. The company’s Crude Oil Pipelines & Services segment also includes a fleet of approximately 245 tractor-trailer tank trucks, the majority of which the company owns and operates, that are used to transport crude oil. Natural Gas Pipelines & Services segment This business segment includes the company’s natural gas pipeline systems that provide for the gathering, treating and transportation of natural gas. This segment also includes the company’s natural gas marketing activities. Natural Gas Pipelines and Related Storage Assets The company’s natural gas gathering pipelines gather, treat and transport natural gas from production developments to regional natural gas plants for further processing. The company’s natural gas transmission pipelines transport natural gas from regional processing facilities to downstream electric generation plants, local gas distribution companies, industrial and municipal customers, storage facilities or other connecting pipelines. The company operates its natural gas pipelines and storage facilities with the exception of the White River Hub, Old Ocean Pipeline and certain segments of the Texas Intrastate System. The following information describes the company’s principal natural gas pipelines: The Texas Intrastate System is consisted of the 6,161-mile Enterprise Texas pipeline system and the 609-mile Channel pipeline system. The Texas Intrastate System gathers, transports and stores natural gas from supply basins in Texas, including the Permian Basin and Eagle Ford and Barnett Shales for delivery to local gas distribution companies, electric utility plants and industrial and municipal consumers. The system is also connected to regional natural gas processing facilities and other intrastate and interstate pipelines. The Texas Intrastate System serves a number of commercial markets in Texas, including Corpus Christi, San Antonio/Austin, Beaumont/Orange and Houston, including the Houston Ship Channel industrial market. The Acadian Gas System transports, stores and markets natural gas in Louisiana. The Acadian Gas System is consisted of the 582-mile Cypress pipeline, 424-mile Acadian pipeline, 275-mile Haynesville Extension pipeline, 83-mile Gillis Lateral pipeline and 28-mile Enterprise Pelican pipeline. The Acadian Gas System links natural gas supplies from Louisiana (e.g., from the Haynesville Shale supply basin) and offshore Gulf of Mexico developments with local gas distribution companies, electric utility plants and industrial customers located primarily in the Baton Rouge/New Orleans/Mississippi River corridor. Additionally, the Acadian Gas System delivers natural gas production from the Haynesville Shale to the liquefied natural gas (‘LNG’) markets in South Louisiana via the Gillis Lateral pipeline. In April 2022, the company announced plans for an additional 400 MMcf/d expansion of the company’s Acadian Gas System. The expansion is expected to be completed in the second quarter of 2023. The Jonah Gathering System is located in the Greater Green River Basin of southwest Wyoming. This system gathers natural gas from the Jonah and Pinedale supply fields for delivery to regional natural gas processing facilities, including the company’s Pioneer facility. The Piceance Basin Gathering System gathers natural gas produced from the Piceance Basin in northwestern Colorado to the company’s Meeker natural gas processing facility. The Midland Basin Gathering System, which is located in West Texas, gathers natural gas from the Midland Basin for delivery to the company’s Midland Basin processing facility. The company acquired this system, along with its Midland Basin processing facility, as part of the company’s acquisition of Navitas Midstream in February 2022. The Delaware Basin Gathering System is consisted of the 1,124-mile Carlsbad pipeline system, the 582-mile Waha pipeline system, the 34-mile Orla pipeline system and the 23-mile Mentone pipeline system. The Delaware Basin Gathering System gathers natural gas from the Delaware Basin for delivery to regional natural gas processing facilities, including the company’s Delaware Basin natural gas processing facility, and delivers residue and treated natural gas into the company’s Texas Intrastate System and third-party pipelines. The White River Hub is a natural gas hub facility serving producers in the Piceance Basin. The facility enables producers to access six interstate natural gas pipelines and has a gross throughput capacity of 3 Bcf/d of natural gas. The BTA Gathering System, which is located in East Texas, gathers and treats natural gas from the Haynesville Shale and Bossier, Cotton Valley and Travis Peak formations. This system includes the company’s Fairplay Gathering System. The Haynesville Gathering System gathers and treats natural gas produced from the Haynesville and Bossier Shale supply basins and the Cotton Valley and Taylor Sand formations in Louisiana and eastern Texas for delivery to regional markets, including (through an interconnect with the Haynesville Extension pipeline) markets served by the company’s Acadian Gas System. The San Juan Gathering System gathers and treats natural gas produced from the San Juan Basin in northern New Mexico and southern Colorado and delivers the natural gas either directly into interstate pipelines or to regional natural gas plants, including the company’s Chaco facility, for processing prior to being transported on interstate pipelines. The Indian Springs Gathering System, along with the Big Thicket Gathering System, gather natural gas from the Woodbine, Wilcox and Yegua production areas in East Texas. The Delmita Gathering System gathers natural gas from the Frio-Vicksburg formation in South Texas for delivery to the company’s South Texas natural gas processing facilities. The South Texas Gathering System gathers natural gas from the Olmos and Wilcox formations for delivery to the company’s South Texas natural gas processing facilities. The Old Ocean Pipeline transports natural gas from an injection point on the company’s Texas Intrastate System near Maypearl, Texas for delivery to a pipeline interconnect at Sweeny, Texas. A third party serves as operator of the pipeline, which has a gross natural gas transportation capacity of 160 MMcf/d. The Central Treating Facility is located in Rio Blanco County, Colorado and serves producers in the Piceance Basin. Natural gas delivered to the treating facility is treated to remove impurities and transported to the company’s Meeker gas plant for further processing. Natural Gas Marketing Activities The company’s natural gas marketing activities generate revenues from the sale and delivery of natural gas purchased from producers, regional natural gas processing facilities and on the open market. The company’s natural gas marketing customers include local gas distribution companies and electric utility plants. In addition, the company purchases and resells natural gas for certain producers that use the company’s San Juan, Piceance, Midland Basin, Delaware Basin and Jonah Gathering Systems and certain segments of the company’s Acadian Gas and Texas Intrastate Systems. Petrochemical & Refined Products Services segment This business segment includes the company’s propylene production facilities, which include propylene fractionation units and a PDH facility, and related pipelines and marketing activities; butane isomerization complex and related deisobutanizer (‘DIB’) operations; octane enhancement, iBDH and HPIB production facilities; refined products pipelines, terminals and related marketing activities; an ethylene export terminal and related operations; and marine transportation business. Propylene Production Facilities and Related Operations The company’s propylene production facilities and related operations include propylene fractionation (or splitter) units, a PDH facility, propylene pipelines, propylene export assets and related petrochemical marketing activities. Propylene production and related marketing activities. Propylene is a key feedstock used by the petrochemical industry. There are three grades of propylene: polymer grade propylene (‘PGP’), with a minimum purity of 99.5%; chemical grade propylene (‘CGP’), with a minimum purity of approximately 93-94%; and refinery grade propylene (‘RGP’), with a purity of approximately 70%. Propylene fractionation units separate RGP, which is a mixture of propane and propylene, into either PGP or CGP. The company’s PDH facility produces PGP using propane feedstocks. The demand for PGP primarily relates to the manufacture of polypropylene, which has a variety of end uses, including packaging film, fiber for carpets and upholstery, molded plastic parts for appliances, and automotive, houseware and medical products. CGP is a basic petrochemical used in the manufacturing of plastics, synthetic fibers and foams. To the extent the company fractionates RGP for customers, the company enters into toll processing arrangements. In the company’s petrochemical marketing activities, the company purchases RGP on the open market for fractionation at the company’s splitter units and sell the resulting PGP to customers at market-based prices. The company’s petrochemical marketing activities also include the purchase of propane for the company’s PDH facility to process into PGP, which is then sold to customers under long-term sales contracts (take-or-pay arrangements). The company produces PGP at its Chambers County facilities and CGP at the company’s BRPC facility. In November 2022, the company reached a settlement related to legal proceedings involving the former general contractor for PDH 1. For additional information regarding this litigation, see Note 17 of the Notes to Consolidated Financial Statements included under Part II, Item 8 of this annual report. PDH 2: In September 2019, the company announced the execution of long-term, fee-based contracts with affiliates of LyondellBasell Industries N.V. that support construction of the company’s second PDH facility (referred to as ‘PDH 2’). In June 2020, the company executed additional long-term PGP sales agreements with Marubeni Corporation in the support of PDH 2. Like PDH 1, PDH 2 is expected to have the capacity to upgrade up to 35 MBPD of propane and produce up to 1.65 billion pounds per year of PGP. PDH 2 is also located in Chambers County, Texas and is scheduled to begin service in the second quarter of 2023. Once PDH 2 is placed into service and integrated with PDH 1 and the company’s other propylene production facilities, the company will have the capability to produce 11 billion pounds of propylene per year. Propylene Pipelines: The results of operations from the company’s petrochemical pipelines are primarily dependent upon the volume of products transported and the associated fees the company charge for such transportation services. Total net throughput volumes were 163 MBPD during the year ended December 31, 2022. With the exception of the Lake Charles PGP Pipeline in Louisiana, the company operates all of its propylene production assets and related pipelines. Propylene Export Assets: The company’s EHT marine terminal located on the Houston Ship Channel includes export assets capable of loading up to 3,000 barrels per hour, or 72 MBPD, of semi-refrigerated propylene. Isomerization and Related Operations The company owns and operates three isomerization units located in Chambers County, Texas having an aggregate processing capacity of 116 MBPD that comprise the largest commercial isomerization facility in the U.S. The company also owns and operates an 83-mile pipeline system used to transport high-purity isobutane from Chambers County, Texas to Port Neches, Texas and to Channelview, Texas. DIB units, of which the company owns and operates ten located at the company’s Chambers County complex, then separate the isobutane from the normal butane. Any remaining unconverted (or residual) normal butane generated by the DIB process is then recirculated through the isomerization process until it has been converted into varying grades of isobutane, including high-purity isobutane. The primary uses of isobutane are for the production of propylene oxide, isooctane, isobutylene and alkylate for motor gasoline. The company also uses certain of its DIB units to fractionate mixed butanes originating from NGL fractionation activities, imports and other sources into isobutane and normal butane. The operating flexibility provided by the company’s multiple standalone DIBs enables the company to capture market opportunities resulting from fluctuations in demand and prices for different types of butanes. The results of operations from the company’s isomerization business are generally dependent on the volume of normal and mixed butanes processed and the level of toll processing fees charged to customers. The company’s isomerization assets provide processing services to meet the needs of third-party customers and the company’s other businesses, including the company’s NGL marketing activities and octane enhancement production facility. Octane Enhancement and Related Operations The company owns and operates an octane enhancement production facility located in Chambers County, Texas that is designed to produce isobutylene and either isooctane or methyl tertiary butyl ether (‘MTBE’). The products produced by this facility are used by refiners to increase octane values in reformulated motor gasoline blends. The high-purity isobutane feedstocks consumed in the production of these products are supplied by the company’s isomerization units. The company sells its octane enhancement products at market-based prices. To the extent that the company produces MTBE, it is sold exclusively into the export market. The company also owns and operates a facility located on the Houston Ship Channel that produces up to 4 MBPD of HPIB and includes an associated storage facility with 0.6 MMBbls of related product storage capacity. The primary feedstock for this plant, an isobutane/isobutylene mix, is produced by the company’s octane enhancement and iBDH facilities. HPIB is used in the production of polyisobutylene, which is used in the manufacture of lubricants and rubber. In general, the company sells HPIB at market-based prices with a cost-based floor. Isobutane Dehydrogenation Unit: The company owns and operates an iBDH facility located in Chambers County, Texas that is capable of processing approximately 25 MBPD of butane into nearly 1 billion pounds per year of isobutylene. Production from the iBDH plant enables the company to optimize the company’s MTBE and high purity isobutylene assets and meet growing market demand for isobutylene. Steam crackers and refineries have historically been the major source of propane and butane olefins for downstream use; however, with the increased use of light-end feedstocks, such as ethane, the need for ‘on purpose’ olefins production has increased. Like the company’s PDH facility, the iBDH plant helps meet market demand where traditional supplies have been reduced. The iBDH plant increases the company’s production of high purity and low purity isobutylene, both of which are used as feedstocks to manufacture lubricants, rubber products and fuel additives. Refined Products Services The company’s refined products services business includes refined products pipelines, terminals and associated marketing activities. Refined Products Pipelines: The company owns and operates the TE Products Pipeline, which is a 3,041-mile pipeline system consisted of 2,923 miles of regulated interstate pipelines and 118 miles of unregulated intrastate Texas pipelines. The system primarily transports refined products from the upper Texas Gulf Coast to Seymour, Indiana. From Seymour, segments of the TE Products Pipeline extend to Chicago, Illinois; Lima, Ohio; Selkirk, New York; and a location near Philadelphia, Pennsylvania. East of Seymour, Indiana, the TE Products Pipeline is primarily dedicated to NGL transportation service. The refined products transported by the TE Products Pipeline are produced by refineries and include motor gasoline and distillates. The TE Products Pipeline system includes five non-regulated refined products truck terminals and 20.9 MMBbls of aggregate storage capacity. In April 2022, the company announced plans for its Texas Western Products System, created by repurposing a portion of the company’s Mid-America Pipeline System’s Rocky Mountain segment and adding westbound service to the company’s Chaparral Pipeline business to transport refined products from the U.S. Gulf Coast to markets in West Texas, New Mexico, Colorado and Utah. The system is expected to be completed in phases beginning in the fourth quarter of 2023. Refined Products Marine Terminals: The company owns and operates marine terminals located on the Neches River near Beaumont, Texas that handle refined products along with crude oil. The company’s Beaumont facilities include five deep-water ship docks, three barge docks and access to approximately 10.4 MMBbls of aggregate refined products storage capacity. The company also handles refined products at EHT on the Houston Ship Channel. In addition to providing vessel loading and unloading services for refined products, EHT’s refined products operations include 2.4 MMBbls of aggregate storage capacity through the use of 20 above-ground storage tanks. Refined Products Marketing Activities: The company’s refined products marketing activities generate revenues from the sale and delivery of refined products obtained on the open market. Ethylene Export Terminal and Related Operations The company’s ethylene export terminal located at the company’s Morgan’s Point facility on the Houston Ship Channel features two docks with a combined nameplate capacity to load 1 million tons of ethylene per year and a refrigerated storage tank capable of handling 66 million pounds of ethylene. Ethylene is the primary feedstock for a wide variety of consumer products, including cell phones and computer parts, food packaging, apparel, textiles and personal protective equipment. The company owns a 50% member interest in Enterprise Navigator Ethylene Terminal LLC, which owns the export facility. In April 2022, the company announced plans to expand the ethylene export capacity of the company’s Morgan’s Point facility. The expansion project, which will be completed in two phases, will expand the company’s existing capacity by 50% during 2024 and to more than double the company’s current capacity by 2025. The company’s ethylene system serves as an open market storage and trading hub for the ethylene industry by incorporating storage capacity, connections to multiple ethylene pipelines, and high-volume export capabilities. In the support of the company’s ethylene business, the company’s Chambers County storage complex includes a high-capacity underground ethylene storage well having a storage capacity of 600 million pounds of ethylene. The storage well is connected to the company’s Morgan’s Point ethylene export terminal and further to Bayport, Texas through a 58-mile pipeline system. The company also operates the Baymark ethylene pipeline in South Texas, which is a leading growth area for new ethylene crackers and related facilities. The Baymark pipeline, which is supported by long-term customer commitments, originates in Bayport and extends 92 miles to Markham, Texas. The company owns a 70% consolidated interest in the Baymark pipeline through the company’s majority owned subsidiary, Baymark Pipeline LLC. Customers using the Baymark pipeline have pipeline access to the company’s high-capacity ethylene storage well in Chambers County and the company’s export terminal at Morgan’s Point. Marine Transportation The company’s marine transportation business consists of 64 tow boats and 157 tank barges used to transport refined products, crude oil, asphalt, condensate, heavy fuel oil, LPG and other petroleum products on key U.S. inland and intracoastal waterway systems. The company operates its marine transportation assets that serve refinery and storage terminal customers along the Mississippi River, the intracoastal waterway between Texas and Florida, and the Tennessee-Tombigbee waterway system. The company owns and operates shipyard and repair facilities located in Houma and Morgan City, Louisiana and marine fleeting facilities located in Bourg, Louisiana and Channelview, Texas. The company’s marine transportation business is subject to regulation, including by the U.S. Department of Transportation (‘DOT’), Department of Homeland Security, the U.S. Department of Commerce and the U.S. Coast Guard (‘USCG’). Regulatory Matters Certain of the company’s facilities are subject to general industry requirements of the Federal Occupational Safety and Health Act, as amended (‘OSHA’), and comparable state statutes. Certain of the company’s facilities are also subject to OSHA Process Safety Management (‘PSM’) regulations, which are designed to prevent or minimize the consequences of catastrophic releases of toxic, reactive, flammable or explosive chemicals. These regulations apply to any process involving certain chemicals, flammable gases or liquids at or above a specified threshold (as defined in the regulations). In addition, the company is subject to Risk Management Plan regulations of the U.S. Environmental Protection Agency (‘EPA’) at certain facilities. These regulations are intended to complement the OSHA PSM regulations. These EPA regulations require the company to develop and implement a risk management program that includes a five-year accident history report, an offsite consequence analysis process, a prevention program and an emergency response program. The company is operating in material compliance with the OSHA PSM regulations and the EPA’s Risk Management Plan requirements. The OSHA hazard communication standard, the community right-to-know regulations under Title III of the federal Superfund Amendments and Reauthorization Act, and comparable state statutes require the company to organize and disclose information about the hazardous materials used in the company’s operations. Certain parts of this information must be reported to federal, state and local governmental authorities and local citizens upon request. These laws and provisions of the Comprehensive Environmental Response, Compensation, and Liability Act (‘CERCLA’) require the company to report spills and releases of hazardous chemicals in certain situations. The company is subject to extensive regulation by the DOT as authorized under various provisions of Title 49 of the United States Code and comparable state statutes relating to the design, installation, testing, construction, operation, replacement and management of the company’s pipelines and associated facilities, including breakout tanks and gas storage facilities. These statutes require companies that own or operate pipelines and associated facilities to comply with such regulations, permit access to and copying of pertinent records, file certain reports, and provide information as required by the U.S. Secretary of Transportation. The DOT regulates natural gas and hazardous liquids pipelines through its Pipeline and Hazardous Materials Safety Administration (‘PHMSA’), and in many cases, enforcement authority is delegated to state agencies. Noncompliance with these requirements can result in substantial penalties. The company is in material compliance with DOT regulations. The company’s operations are subject to various environmental and safety requirements and potential liabilities under extensive federal, state and local laws and regulations. These include, without limitation: CERCLA; the Resource Conservation and Recovery Act (‘RCRA’); the Federal Clean Air Act (‘CAA’); the Clean Water Act (‘CWA’); the Oil Pollution Act of 1990 (‘OPA’); the OSHA; the Emergency Planning and Community Right-to-Know Act; the National Historic Preservation Act; and comparable or analogous state and local laws and regulations. The company is subject to the CAA and comparable state laws and regulations, including state air quality implementation plans. These laws and regulations regulate emissions of air pollutants from various industrial sources, including certain of the company’s facilities, and also impose various monitoring and reporting requirements. The EPA has also adopted regulations that require the company to have permits in order to discharge regulated storm water run-off. In the company’s normal operations, the company generates hazardous and non-hazardous solid wastes that are subject to requirements of the federal RCRA and comparable state statutes, which impose detailed requirements for the handling, storage, treatment and disposal of solid waste. Certain of the company’s NGL, refined products and crude oil pipeline systems provide interstate common carrier movements subject to regulation by the FERC under the Interstate Commerce Act (‘ICA’). Pipelines providing such movements (referred to as ‘interstate liquids pipelines’) include, but are not limited to, the following: ATEX, Aegis, Dixie Pipeline, TE Products Pipeline, Front Range Pipeline, Mid-America Pipeline System, Seaway Pipeline, Seminole NGL Pipeline and Texas Express Pipeline. These pipelines are owned by legal entities whose movements are subject to FERC regulation, including periodic reporting requirements. For example, ATEX, Aegis and the TE Products Pipeline are owned by Enterprise TE Products Pipeline Company LLC (‘Enterprise TE’), which provides certain FERC-regulated movements. Certain of the company’s pipelines have been granted market-based rate authority by the FERC, including Seaway. The transportation rates charged by the company’s interstate liquids pipelines are in accordance with the ICA and applicable FERC regulations. Certain of the company’s intrastate natural gas pipelines, including the Texas Intrastate System and Acadian Gas System, are subject to regulation by the FERC under the Natural Gas Policy Act of 1978 (‘NGPA’), in connection with the transportation and storage services they provide pursuant to Section 311 of the NGPA. The transportation rates charged and the services performed by the company’s natural gas pipelines are all in accordance with the applicable requirements of the NGPA and FERC regulations. The company is subject to the Jones Act and other federal laws that restrict maritime transportation between the U.S. departure and destination points to vessels built and registered in the U.S. and owned and manned by the U.S. citizens. The company’s marine operations are also subject to the Merchant Marine Act of 1936, which under certain conditions would allow the U.S. government to requisition the company’s marine assets in the event of a national emergency. Seasonality Although the majority of the company’s businesses are not materially affected by seasonality, certain aspects of the company’s operations are impacted by seasonal changes, such as tropical weather events, energy demand in connection with heating and cooling requirements and for the summer driving season. Examples include: Residential demand for natural gas typically peaks during the winter months in connection with heating needs and during the summer months for power generation for air conditioning. These seasonal trends affect throughput volumes on the company’s natural gas pipelines and associated natural gas storage levels and marketing results. Due to increased demand for fuel additives used in the production of motor gasoline, the company’s isomerization and octane enhancement businesses experience higher levels of demand during the summer driving season, which typically occurs in the spring and summer months. History Enterprise Products Partners L.P. was founded in 1968. The company was incorporated in 1998.