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Table of Contents
Index to Financial Statements
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
https://cdn.kscope.io/2e53191b9d722eba5d21c654dff19489-etlogoa05.jpg
FORM 10-K
ý ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended DECEMBER 31, 2023
or
¨ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
Commission file number 1-32740
https://cdn.kscope.io/2e53191b9d722eba5d21c654dff19489-etlogoa05.jpg
ENERGY TRANSFER LP
(Exact name of registrant as specified in its charter)
Delaware30-0108820
(State or other jurisdiction of incorporation or organization)(I.R.S. Employer Identification No.)
8111 Westchester Drive, Suite 600, Dallas, Texas 75225
(Address of principal executive offices) (zip code)
Registrant’s telephone number, including area code: (214981-0700
Securities registered pursuant to Section 12(b) of the Act:
Title of each classTrading Symbol(s)Name of each exchange on which registered
Common UnitsETNew York Stock Exchange
7.375% Series C Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred UnitsETprCNew York Stock Exchange
7.625% Series D Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred UnitsETprDNew York Stock Exchange
7.600% Series E Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred UnitsETprENew York Stock Exchange
9.250% Series I Fixed Rate Perpetual Preferred UnitsETprINew York Stock Exchange
Securities registered pursuant to section 12(g) of the Act: None
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes  ý    No  ¨
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes  ¨    No  ý
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes  ý    No  ¨
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes  ý    No  ¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer  ý    Accelerated filer  ¨    Non-accelerated filer  ¨    Smaller reporting company   Emerging growth company  
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨
Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report.  ý
If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect the correction of an error to previously issued financial statements. ¨
Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based compensation received by any of the registrant’s executive officers during the relevant recovery period pursuant to §240.10D-1(b). ¨
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes    No  ý
The aggregate market value as of June 30, 2023, of the registrant’s Common Units held by non-affiliates of the registrant, based on the reported closing price of such Common Units on the New York Stock Exchange on such date, was $35.67 billion.
As of February 9, 2024, the registrant had 3,367,757,556 Common Units outstanding.
DOCUMENTS INCORPORATED BY REFERENCE
None


Table of Contents
Index to Financial Statements
FORM 10-K
ENERGY TRANSFER LP AND SUBSIDIARIES
TABLE OF CONTENTS
2

Table of Contents
Index to Financial Statements
Definitions
The following is a list of certain acronyms and terms used throughout this document: 
/dper day
Adjusted EBITDA
a non-GAAP measure defined as earnings before interest, taxes, depreciation, depletion, amortization and other non-cash items, as further described in “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Results of Operations”
AOCIaccumulated other comprehensive income
AROsasset retirement obligations
BBtubillion British thermal units
Bcfbillion cubic feet
BtuBritish thermal unit, an energy measurement used by gas companies to convert the volume of gas used to its heat equivalent, and thus calculate the actual energy content
Capacitycapacity of a pipeline, processing plant or storage facility refers to the maximum capacity under normal operating conditions and, with respect to pipeline transportation capacity, is subject to multiple factors (including natural gas injections and withdrawals at various delivery points along the pipeline and the utilization of compression) which may reduce the throughput capacity from specified capacity levels
CitrusCitrus, LLC, a 50/50 joint venture which owns FGT
CrestwoodCrestwood Equity Partners LP
Dakota AccessDakota Access, LLC, a non-wholly owned subsidiary of Energy Transfer
DOEUnited States Department of Energy
DOJUnited States Department of Justice
DOTUnited States Department of Transportation
EnableEnable Midstream Partners, LP
Energy Transfer CanadaEnergy Transfer Canada ULC, a non-wholly owned subsidiary of Energy Transfer until its sale in August 2022
Energy Transfer GC NGLEnergy Transfer GC NGLs LLC, formerly Lone Star NGL LLC, a wholly owned subsidiary of Energy Transfer
Energy Transfer Preferred UnitsCollectively, the Series A Preferred Units, Series B Preferred Units, Series C Preferred Units, Series D Preferred Units, Series E Preferred Units, Series F Preferred Units, Series G Preferred Units, Series H Preferred Units and Series I Preferred Units
Energy Transfer R&MEnergy Transfer (R&M), LLC (formerly Sunoco (R&M), LLC)
EPAUnited States Environmental Protection Agency
ETC SunocoETC Sunoco Holdings LLC (formerly Sunoco, Inc.), a wholly owned subsidiary of Energy Transfer
ETOEnergy Transfer Operating, L.P., formerly a non-wholly owned subsidiary of Energy Transfer until its merger into the Partnership in April 2021
ETP HoldcoETP Holdco Corporation, a wholly owned subsidiary of Energy Transfer
Exchange ActSecurities Exchange Act of 1934, as amended
ExplorerExplorer Pipeline and/or Explorer Pipeline Company
FEPFayetteville Express Pipeline LLC
FERCUnited States Federal Energy Regulatory Commission
FGTFlorida Gas Transmission Pipeline and/or Florida Gas Transmission Company, LLC, a wholly owned subsidiary of Citrus
GAAPaccounting principles generally accepted in the United States of America
General PartnerLE GP, LLC, the general partner of Energy Transfer
HFOTCOHFOTCO LLC, a wholly owned subsidiary of Energy Transfer, which owns the Houston Terminal
IDRsincentive distribution rights
IFERCInside FERC’s Gas Market Report
IRS
United States Internal Revenue Service
Lake Charles LNGLake Charles LNG Company, LLC, a wholly owned subsidiary of Energy Transfer
Lake Charles LNG ExportLake Charles LNG Export Company, LLC, a wholly owned subsidiary of Energy Transfer
LIBORLondon Interbank Offered Rate
3

Table of Contents
Index to Financial Statements
LNGliquefied natural gas
Lotus MidstreamLotus Midstream Operations, LLC
MBblsthousand barrels
MEPMidcontinent Express Pipeline LLC
Mid ValleyMid Valley Pipeline Company LLC, a wholly owned subsidiary of Energy Transfer
MMBblsmillion barrels
MMcfmillion cubic feet
MTBEmethyl tertiary butyl ether
NGANatural Gas Act of 1938
NGLnatural gas liquid, such as propane, butane and natural gasoline
NGPANatural Gas Policy Act of 1978
NuStarNuStar Energy L.P.
NYMEXNew York Mercantile Exchange
NYSENew York Stock Exchange
ORSOhio River System LLC, a non-wholly owned subsidiary of Energy Transfer
OSHAFederal Occupational Safety and Health Act
OTCover-the-counter
PanhandlePanhandle Eastern Pipe Line Company, LP, a wholly owned subsidiary of Energy Transfer
Partnership AgreementEnergy Transfer’s Fourth Amended and Restated Agreement of Limited Partnership, as amended to date
PCBspolychlorinated biphenyls
PEPPermian Express Partners LLC, a non-wholly owned subsidiary of Energy Transfer
PHMSAPipeline Hazardous Materials Safety Administration
Preferred UnitholdersUnitholders of the Series A Preferred Units, Series B Preferred Units, Series C Preferred Units, Series D Preferred Units, Series E Preferred Units, Series F Preferred Units, Series G Preferred Units, Series H Preferred Units and Series I Preferred Units, collectively
RoverRover Pipeline and/or Rover Pipeline LLC, a non-wholly owned subsidiary of Energy Transfer
SCOOPSouth Central Oklahoma Oil Province
Sea RobinSea Robin Pipeline and/or Sea Robin Pipeline Company, LLC, a wholly owned subsidiary of Energy Transfer
SECUnited States Securities and Exchange Commission
Series A Preferred UnitsSeries A Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units
Series B Preferred UnitsSeries B Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units
Series C Preferred UnitsSeries C Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units
Series D Preferred UnitsSeries D Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units
Series E Preferred UnitsSeries E Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units
Series F Preferred UnitsSeries F Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Units
Series G Preferred UnitsSeries G Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Units
Series H Preferred UnitsSeries H Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Units
Series I Preferred UnitsSeries I Fixed-Rate Perpetual Preferred Units
SESHSoutheast Supply Header Pipeline and/or Southeast Supply Header, LLC, a non-wholly owned subsidiary of Energy Transfer
SOFRSecured overnight financing rate
Southwest GasPan Gas Storage, LLC (d.b.a. Southwest Gas Storage Company), a wholly owned subsidiary of Energy Transfer
SPLPSunoco Pipeline L.P., a wholly owned subsidiary of Energy Transfer
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TigerTiger Pipeline and/or ETC Tiger Pipeline, LLC, a wholly owned subsidiary of Energy Transfer
TranswesternTranswestern Pipeline and/or Transwestern Pipeline Company, LLC, a wholly owned subsidiary of Energy Transfer
TRRCTexas Railroad Commission
TrunklineTrunkline Pipeline and/or Trunkline Gas Company, LLC, a wholly owned subsidiary of Energy Transfer
UnitholdersPreferred Unitholders and holders of Energy Transfer LP common units
USACUSA Compression Partners, LP, a publicly traded partnership and consolidated subsidiary of Energy Transfer
White CliffsWhite Cliffs Pipeline, L.L.C.
Forward-Looking Statements
Certain matters discussed in this annual report, excluding historical information, as well as some statements by Energy Transfer LP (the “Partnership” or “Energy Transfer”) in periodic press releases and some oral statements of the Partnership’s officials during presentations about the Partnership, include forward-looking statements. These forward-looking statements are identified as any statement that does not relate strictly to historical or current facts. Statements using words such as “anticipate,” “project,” “expect,” “plan,” “goal,” “forecast,” “estimate,” “intend,” “continue,” “could,” “believe,” “may,” “will” or similar expressions help identify forward-looking statements. Although the Partnership and its General Partner believe such forward-looking statements are based on reasonable assumptions and current expectations and projections about future events, no assurance can be given that such assumptions, expectations or projections will prove to be correct. Forward-looking statements are subject to a variety of risks, uncertainties and assumptions. If one or more of these risks or uncertainties materialize, or if underlying assumptions prove incorrect, the Partnership’s actual results may vary materially from those anticipated, estimated, projected, forecasted, expressed or expected in forward-looking statements since many of the factors that determine these results are subject to uncertainties and risks that are difficult to predict and beyond management’s control. For additional discussion of risks, uncertainties and assumptions, see “Item 1A. Risk Factors” included in this annual report.
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PART I
ITEM 1. BUSINESS
Overview
Energy Transfer LP is a Delaware limited partnership with common units publicly traded on the NYSE under the ticker symbol “ET.”
Unless the context requires otherwise, references to “we,” “us,” “our,” the “Partnership” and “Energy Transfer” mean Energy Transfer LP and its consolidated subsidiaries, which include Sunoco LP and USAC.
The primary activities in which we are engaged, which are located in the United States, are as follows:
natural gas operations, including the following:
natural gas midstream and intrastate transportation and storage;
interstate natural gas transportation and storage; and
crude oil, NGL and refined products transportation, terminalling and acquisition and marketing activities as well as NGL storage and fractionation services.
In addition, we own investments in other businesses, including Sunoco LP and USAC, both of which are master limited partnerships.
Energy Transfer derives cash flows from distributions related to its investment in its subsidiaries, including Sunoco LP and USAC. The amount of cash that our subsidiaries distribute to us is based on earnings from their respective business activities and the amount of available cash. Energy Transfer’s primary cash requirements are for distributions to its partners, general and administrative expenses and debt service requirements. Energy Transfer distributes its available cash remaining after satisfaction of the aforementioned cash requirements to its Unitholders on a quarterly basis.
We expect our subsidiaries to utilize their resources, along with cash from their operations, to fund their announced growth capital expenditures and working capital needs; however, Energy Transfer may issue debt or equity securities from time to time as we deem prudent to provide liquidity for new capital projects of our subsidiaries or for other partnership purposes.
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The following chart summarizes our organizational structure as of February 9, 2024. For simplicity, certain entities and ownership interests have not been depicted.
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Significant Achievements in 2023
Strategic Transactions
In November, the Partnership completed its acquisition of Crestwood, which owns gathering and processing assets located in the Williston, Delaware and Powder River basins.
In May, the Partnership acquired Lotus Midstream, which owns an integrated crude midstream platform located in the Permian Basin.
Organic Growth Projects
In August, the Partnership’s eighth fractionator was placed in service at the Mont Belvieu NGL Complex, which brings fractionation capacity at Mont Belvieu to approximately 1.15 MMBbls/d.
In June, the Partnership’s 200 MMcf/d Bear cryogenic processing plant was placed in service in the Permian Basin.
Segment Overview
See Note 16 to our consolidated financial statements included in “Item 8. Financial Statements and Supplementary Data” for additional financial information about our segments.
Intrastate Transportation and Storage Segment
Intrastate natural gas transportation pipelines receive natural gas from other mainline transportation pipelines, storage facilities and gathering systems, and deliver the natural gas to industrial end-users, storage facilities, utilities, power generators and other third-party pipelines. Through our intrastate transportation and storage segment, we own and operate (through wholly owned subsidiaries or through joint venture interests) approximately 12,200 miles of intrastate natural gas transportation pipelines with approximately 24 Bcf/d of transportation capacity, three natural gas storage facilities located in Texas and two natural gas storage facilities located in Oklahoma.
Energy Transfer operates one of the largest intrastate pipeline systems in the United States, which provides energy logistics to major trading hubs and industrial consumption areas throughout the country. In Texas, our intrastate transportation and storage segment provides transportation of natural gas to major markets from various prolific natural gas producing areas in Texas and Louisiana (Permian Basin and Barnett, Haynesville and Eagle Ford shales) through our Oasis Pipeline, ETC Katy Pipeline, Lobo Pipeline, RIGS and Pelico Pipeline as well as our two natural gas pipeline and storage systems: ET Fuel and HPL. In Oklahoma, we operate Oklahoma Intrastate Transmission, which delivers natural gas from various shale plays in the Anadarko and Arkoma basins, as further described in “Asset Overview.”
We also own a 70% interest in Red Bluff Express Pipeline, which owns a pipeline in the Delaware Basin, and 16% membership interests in Comanche Trail Pipeline and Trans-Pecos Pipeline, which own pipelines delivering natural gas from the Waha Hub to the United States/Mexico border.
Our intrastate transportation and storage segment’s results are determined primarily by the amount of capacity our customers reserve as well as the actual volume of natural gas that flows through the transportation pipelines. Under transportation contracts, our customers are charged (i) a demand fee, which is a fixed fee for the reservation of an agreed amount of capacity on the transportation pipeline for a specified period of time and which obligates the customer to pay a fee even if the customer does not transport natural gas on the respective pipeline, (ii) a transportation fee, which is based on the actual throughput of natural gas by the customer, (iii) fuel retention based on a percentage of gas transported on the pipeline or (iv) a combination of the three, generally payable monthly.
We also generate revenues and margin from the sale of natural gas to electric utilities, independent power plants, local distribution companies, industrial end-users and marketing companies. Generally, we purchase natural gas from either the market (including purchases from our marketing operations) or from producers at the wellhead. To the extent the natural gas comes from producers, it is primarily purchased at a discount to a specified market price and typically resold to customers based on an index price. In addition, our intrastate transportation and storage segment generates revenues from fees charged for storing customers’ working natural gas in our storage facilities and from managing natural gas for our own account.
Interstate Transportation and Storage Segment
Interstate natural gas transportation pipelines receive natural gas from supply sources including other transportation pipelines, storage facilities and gathering systems, and deliver the natural gas to industrial end-users and other pipelines. Through our interstate transportation and storage segment, we directly own and operate approximately 20,090 miles of interstate natural gas
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pipelines with approximately 20.1 Bcf/d of transportation capacity and another approximately 7,085 miles and 12.3 Bcf/d of transportation capacity through joint venture interests.
Our vast interstate natural gas network spans the United States from Florida to California and Texas to Michigan, offering a comprehensive array of pipeline and storage services. Our pipelines have the capability to transport natural gas from nearly all Lower 48 onshore and offshore supply basins to customers in the Gulf Coast, Southeast, Southwest, Midwest and Northeast United States as well as Canada. Through numerous interconnections with other pipelines, our interstate systems can access virtually any supply or market in the country. As discussed further herein, our interstate transportation and storage segment’s operations are regulated by the FERC, which has broad regulatory authority over the business and operations of interstate natural gas pipelines.
Lake Charles LNG, our wholly owned subsidiary, owns an LNG import terminal and regasification facility located on Louisiana’s Gulf Coast near Lake Charles, Louisiana. The import terminal has approximately 9.0 Bcf of above ground storage capacity and the regasification facility has a send-out capacity of 1.8 Bcf/d. Lake Charles LNG derives all of its revenue from a series of long-term contracts with a wholly owned subsidiary of Royal Dutch Shell plc (“Shell”).
Lake Charles LNG Export, our wholly owned subsidiary, is developing a natural gas liquefaction project at the site of our Lake Charles LNG import terminal and regasification facility. The project would utilize existing dock and storage facilities owned by Lake Charles LNG located on the Lake Charles site. Lake Charles LNG Export entered into a prior development agreement with Shell in March 2019; however, Shell withdrew from the project in March 2020 due to adverse market factors affecting Shell’s business following the onset of the COVID-19 pandemic. The project will benefit from the infrastructure related to the existing regasification facility at the same site, including four LNG storage tanks, two deep water docks and other assets.
During 2022, Lake Charles LNG Export executed six LNG off-take agreements, for an aggregate of nearly 8 million tonnes per annum, including a 20-year LNG agreement with Shell NA LNG LLC. The agreements allow either party to terminate the agreement if Lake Charles LNG Export has not satisfied specified conditions by a specified date. One of those conditions relates to Lake Charles LNG Export making a “final investment decision” to proceed with the construction of the liquefaction facility. To date, the specified dates for satisfying these conditions have been extended by mutual agreement of the parties to the agreements. We have also signed nonbinding letter agreements with several customers for LNG offtake, and we are in discussions with several parties for potential long-term LNG offtake and potential equity investments in the project.
The results from our interstate transportation and storage segment are primarily derived from the fees we earn from natural gas transportation and storage services.
Midstream Segment
The midstream industry consists of natural gas gathering, compression, treating, processing, storage and transportation, and is generally characterized by regional competition based on the proximity of gathering systems and processing plants to natural gas producing wells and the proximity of storage facilities to production areas and end-use markets. Gathering systems generally consist of a network of small diameter pipelines and, if necessary, compression systems, that collect natural gas from points near producing wells and transports it to larger pipelines for further transportation.
Treating plants remove carbon dioxide and hydrogen sulfide from natural gas that is higher in carbon dioxide, hydrogen sulfide or certain other contaminants, to ensure that it meets pipeline quality specifications. Natural gas processing involves the separation of natural gas into pipeline quality natural gas, or residue gas, and a mixed NGL stream. Some natural gas produced by a well does not meet the pipeline quality specifications established by downstream pipelines or is not suitable for commercial use and must be processed to remove the mixed NGL stream. In addition, some natural gas can be processed to take advantage of favorable margins for NGLs extracted from the gas stream.
Through our midstream segment, we own and operate (through wholly owned subsidiaries or joint venture interests) natural gas gathering pipelines, natural gas processing plants, natural gas treating facilities and natural gas conditioning facilities with an aggregate processing capacity of approximately 11.4 Bcf/d. Our midstream segment focuses on the gathering, compression, treating, blending and processing of natural gas, and our operations are currently concentrated in major producing basins and shales in Texas, New Mexico, West Virginia, Pennsylvania, Ohio, Oklahoma, Arkansas, Kansas, Louisiana, Montana, North Dakota and Wyoming. Many of our midstream assets are integrated with our intrastate transportation and storage assets as well as our NGL assets.
Our midstream segment’s results are derived primarily from margins we earn from natural gas volumes that are gathered, transported, purchased and sold through our pipeline systems and the natural gas and NGL volumes processed at our processing and treating facilities.
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NGL and Refined Products Transportation and Services Segment
Our NGL and refined products operations transport, store and execute acquisition and marketing activities utilizing a complementary network of pipelines, storage and blending facilities as well as strategic offtake locations that provide access to multiple markets.
Our NGL and refined products transportation and services segment includes:
approximately 5,700 miles of NGL pipelines;
our Nederland Terminal and connecting pipelines which provide transportation of ethane, propane, butane and natural gasoline from our Mont Belvieu NGL Complex to our Nederland Terminal where these products can be exported;
our Marcus Hook Terminal which includes fractionation, storage and exporting assets. This facility is connected to our Mariner East Pipeline System, which provides for the transportation of ethane and liquefied petroleum gas (“LPG”) products from western Pennsylvania, West Virginia and eastern Ohio to our Marcus Hook Terminal where these component products can be exported, processed or locally distributed;
NGL fractionation facilities at our Mont Belvieu NGL Complex with an aggregate capacity of 1.15 MMBbls/d;
NGL storage facilities at our Mont Belvieu NGL Complex with a working storage capacity of approximately 60 MMBbls; and
other NGL storage assets with an aggregate storage capacity of approximately 35 MMBbls, including LPG storage assets acquired in connection with the Crestwood acquisition in 2023.
Our NGL pipelines primarily transport NGLs from the Permian Basin, the Barnett and Eagle Ford shales to Mont Belvieu, Texas. In the Northeast, our NGL pipelines transport from the Marcellus and Utica shales to our Marcus Hook Terminal, to customer facilities in Marysville, Michigan and to delivery points on the Canadian border.
In addition to providing storage capacity, our NGL terminalling services also support our liquids blending activities, including the use of our patented butane blending technology. Refined products operations provide transportation and terminalling services through the use of approximately 3,760 miles of refined products pipelines and 37 active refined products marketing terminals. Our refined product marketing terminals are located primarily in the Northeast, Midwest and Southwest United States, with approximately 8 MMBbls of refined products storage capacity. Our refined products operations utilize our integrated pipeline and terminalling assets, as well as acquisition and marketing activities, to service refined products markets in several regions throughout the United States. The mix of products delivered through our refined products pipelines varies seasonally, with gasoline demand peaking during the summer months, and demand for heating oil and other distillate fuels peaking in the winter. The products transported in these pipelines include multiple grades of gasoline and middle distillates, such as heating oil, diesel and jet fuel. Rates for shipments on these product pipelines are regulated by the FERC and other state regulatory agencies, as applicable.
Revenues in this segment are principally generated from fees charged to customers under dedicated contracts or take-or-pay contracts. Under a dedicated contract, the customer agrees to deliver the total output from particular processing plants that are connected to the NGL pipeline. Take-or-pay contracts have minimum throughput commitments requiring the customer to pay regardless of whether a fixed volume is transported. Fees are market-based, negotiated with customers and competitive with regional regulated pipelines and fractionators. Storage revenues are derived from base storage and throughput fees. This segment also derives revenues from fee-based export activities, the marketing of NGLs as well as processing and fractionating refinery off-gas.
Crude Oil Transportation and Services Segment
Our crude oil operations provide transportation (via pipeline and trucking), terminalling as well as acquisition and marketing services to crude oil markets throughout the Southwest, Midwest and Northeast United States. Through our crude oil transportation and services segment, we own and operate (through wholly owned subsidiaries or joint venture interests) approximately 14,500 miles of crude oil trunk and gathering pipelines in the Southwest, Midcontinent and Midwest United States. This segment includes equity ownership interests in seven crude oil pipeline systems: the Bakken Pipeline, Bayou Bridge Pipeline, White Cliffs Pipeline, Maurepas Pipeline, the Permian Express pipelines, Enable South Central Pipeline and the Wink to Webster Pipeline. Our crude oil terminalling services operate with an aggregate storage capacity of approximately 65 MMBbls, including approximately 30 MMBbls at our Gulf Coast terminal in Nederland, Texas, approximately 18.2 MMBbls at our Gulf Coast terminal on the Houston Ship Channel and approximately 9.5 MMBbls at our Cushing Terminal in Cushing, Oklahoma, among others. Our crude oil acquisition and marketing activities utilize our pipeline and terminal assets,
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our proprietary fleet of crude oil tractor trailers and truck unloading facilities, as well as third-party assets to service crude oil markets principally in the Midcontinent United States.
Revenues throughout our crude oil pipeline systems are generated from tariffs paid by shippers utilizing our transportation services. These tariffs are filed with the FERC and other state regulatory agencies, as applicable.
Our crude oil acquisition and marketing activities include the gathering, purchasing, marketing and selling of crude oil. Specifically, the crude oil acquisition and marketing activities include:
purchasing crude oil at both the wellhead from producers and in bulk from aggregators at major pipeline interconnections and trading locations;
storing inventory during contango market conditions (when the price of crude oil for future delivery is higher than current prices);
buying and selling crude oil of different grades at different locations in order to maximize value;
transporting crude oil using our pipelines, terminals and trucks or, when necessary or cost effective, pipelines, terminals or trucks owned and operated by third parties; and
marketing crude oil to major integrated oil companies, independent refiners and resellers through various types of sale and exchange transactions.
Investment in Sunoco LP
Sunoco LP is primarily engaged in the distribution of motor fuels to independent dealers, distributors, and other commercial customers and the distribution of motor fuels to end-user customers at retail sites operated by commission agents. Additionally, it receives rental income through the leasing or subleasing of real estate used in the retail distribution of motor fuel. Sunoco LP also operates 75 retail stores located in Hawaii and New Jersey.
Sunoco LP is a distributor of motor fuels and other petroleum products which Sunoco LP supplies to third-party dealers and distributors, to independent operators of commission agent locations and other commercial consumers of motor fuel. Also included in the wholesale operations are transmix processing plants and refined products terminals. Transmix is the mixture of various refined products (primarily gasoline and diesel) created in the supply chain (primarily in pipelines and terminals) when various products interface with each other. Transmix processing plants separate this mixture and return it to salable products of gasoline and diesel.
Sunoco LP is the exclusive wholesale supplier of the Sunoco-branded and EcoMaxx-branded motor fuels, supplying an extensive distribution network of approximately 5,534 company and third-party operated locations throughout the United States and Puerto Rico. In addition to distributing motor fuels, Sunoco LP also distributes other petroleum products such as propane and lubricating oil, and Sunoco LP receives rental income from real estate that it leases or subleases.
Investment in USAC
USAC provides natural gas compression services throughout the United States, including the Utica, Marcellus, Permian Basin, Eagle Ford, Mississippi Lime, Granite Wash, Woodford, Barnett, Haynesville, Niobrara and Fayetteville shales. USAC provides compression services to its customers primarily in connection with infrastructure applications, including both allowing for the processing and transportation of natural gas through the domestic pipeline system and enhancing crude oil production through artificial lift processes. As such, USAC’s compression services play a critical role in the production, processing and transportation of both natural gas and crude oil. As of December 31, 2023, USAC had 3.8 million horsepower in its fleet.
USAC operates a modern fleet of compression units, with an average age of approximately 11 years. USAC’s standard new-build compression units are generally configured for multiple compression stages allowing USAC to operate its units across a broad range of operating conditions. As part of USAC’s services, it engineers, designs, operates, services and repairs its compression units and maintains related support inventory and equipment.
USAC provides compression services to its customers under fixed-fee contracts with initial contract terms typically between six months to five years, depending on the application and location of the compression unit. USAC typically continues to provide compression services at a specific location beyond the initial contract term, either through contract renewal or on a month-to-month or longer basis. USAC primarily enters into fixed-fee contracts whereby its customers are required to pay a monthly fee even during periods of limited or disrupted throughput, which enhances the stability and predictability of its cash flows. USAC is not directly exposed to commodity price risk because it does not take title to the natural gas or crude oil involved in its services and because the natural gas used as fuel by its compression units is supplied by its customers without cost to USAC.
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USAC’s assets and operations are all located and conducted in the United States.
All Other Segment
Our “All Other” segment includes:
our gas marketing activities, which optimize basis pricing differentials by purchasing and transporting natural gas, primarily on company owned pipelines, and selling that gas primarily to industrial end-users or to other marketers;
our commodity marketing company, which focuses primarily on wholesale power trading activities;
our natural gas compression equipment business, which has operations in Arkansas, California, Colorado, Louisiana, New Mexico, Oklahoma, Pennsylvania and Texas;
our wholly owned subsidiary, Dual Drive Technologies, Ltd., which provides compression services to customers engaged in the transportation of natural gas, including our other segments; and
subsidiaries involved in the management of coal and natural resources properties and the related collection of royalties. We also earn revenues from other land management activities, such as selling standing timber, leasing coal-related infrastructure facilities, and collecting oil and gas royalties. These operations also include end-user coal handling facilities.
Asset Overview
The following descriptions include summaries of significant assets within the Partnership’s reportable segments. Amounts, such as capacities, volumes and miles included in the following descriptions are approximate and are based on information currently available; such amounts are subject to change based on future events or additional information.
The map below depicts the major assets of our core businesses, excluding the assets of Sunoco LP, USAC and the businesses in our all other segment. The map below and the maps included within the segment asset descriptions include certain non-wholly owned joint ventures and exclude corporate and field offices and certain assets that are less significant to the Partnership on a consolidated basis.
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Intrastate Transportation and Storage
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The following details our pipelines and storage facilities in the intrastate transportation and storage segment:
Description of AssetsOwnership InterestMiles of Natural Gas PipelinePipeline Throughput Capacity
(Bcf/d)
Working Storage Capacity
(Bcf)
ET Fuel System (1)
100 %3,150 5.2 11.2 
Oasis Pipeline (1)
100 %750 2.0 — 
Houston Pipeline (“HPL”) System 100 %3,920 5.3 52.5 
ETC Katy Pipeline100 %460 2.9 — 
Regency Intrastate Gas System (“RIGS”)100 %450 2.1 — 
Oklahoma Intrastate Transmission (“OIT”) (1)
100 %2,200 2.4 24.0 
Comanche Trail Pipeline16 %195 1.1 — 
Trans-Pecos Pipeline16 %140 1.4 — 
Red Bluff Express Pipeline70 %120 1.4 — 
(1)Includes bi-directional capabilities
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The following information describes our principal intrastate transportation and storage assets:
The ET Fuel System serves some of the most prolific production areas in the United States and is comprised of intrastate natural gas pipelines and related natural gas storage facilities. The ET Fuel System has bi-directional capabilities and has many interconnections with pipelines providing direct access to power plants and other intrastate and interstate pipelines. It is strategically located near high-growth production areas and provides access to the three major natural gas trading centers in Texas: the Waha Hub near Pecos, Texas, the Maypearl Hub in Central Texas and the Carthage Hub in East Texas.
The ET Fuel System also includes our Bethel natural gas storage facility, with a working capacity of 6.0 Bcf, an average withdrawal capacity of 300 MMcf/d and an injection capacity of 75 MMcf/d, and our Bryson natural gas storage facility, with a working capacity of 5.2 Bcf, an average withdrawal capacity of 120 MMcf/d and an average injection capacity of 96 MMcf/d.
In addition, the ET Fuel System is integrated with our Godley processing plant which gives us the ability to bypass the plant when processing margins are unfavorable by blending the untreated natural gas from our gas gathering system known as the North Texas System with natural gas on the ET Fuel System while continuing to meet pipeline quality specifications.
The Oasis Pipeline is primarily a 36-inch natural gas pipeline. It has bi-directional capabilities with approximately 1.3 Bcf/d of throughput capacity moving west-to-east and greater than 750 MMcf/d of throughput capacity moving east-to-west. The Oasis Pipeline connects to the Waha and Katy market hubs and has many interconnections with other pipelines, power plants, processing facilities, municipalities and producers.
The Oasis Pipeline is integrated with our gathering system known as the Southeast Texas System and is an important component to maximizing our Southeast Texas System’s profitability. The Oasis Pipeline enhances the Southeast Texas System by (i) providing access for natural gas gathered on the Southeast Texas System to third-party supply and market points and interconnecting pipelines and (ii) allowing us to bypass our processing plants and treating facilities on the Southeast Texas System when processing margins are unfavorable by blending untreated natural gas from the Southeast Texas System with gas on the Oasis pipeline while continuing to meet pipeline quality specifications.
The HPL System is an extensive network of intrastate natural gas pipelines, the underground Bammel storage reservoir and related transportation assets. The system has access to multiple sources of historically significant natural gas supply reserves from South Texas, the Gulf Coast of Texas, East Texas and the western Gulf of Mexico, and is directly connected to major gas distribution, electric and industrial load centers in Houston, Corpus Christi, Texas City, Beaumont and other cities located along the Gulf Coast of Texas. The HPL System is well situated to gather and transport gas in many of the major gas producing areas in Texas including a strong presence in the key Houston Ship Channel and Katy Hub markets, allowing us to play an important role in the Texas natural gas markets. The HPL System also offers its shippers off-system opportunities due to its numerous interconnections with other pipeline systems, its direct access to multiple market hubs at Katy, the Houston Ship Channel, Carthage and Agua Dulce as well as our Bammel storage facility.
The Bammel storage facility has a total working gas capacity of approximately 52.5 Bcf, a peak withdrawal rate of 1.3 Bcf/d and a peak injection rate of 0.6 Bcf/d. The Bammel storage facility is located near the Houston Ship Channel market area and the Katy Hub, and is ideally suited to provide a physical backup for on-system and off-system customers. As of December 31, 2023, we had approximately 17.2 Bcf committed under fee-based arrangements with third parties and approximately 37.0 Bcf stored in the facility for our own account.
The ETC Katy Pipeline connects three treating facilities, one of which we own, with our gathering system known as Southeast Texas System. The ETC Katy Pipeline serves producers in East and North Central Texas and provides access to the Katy Hub. The ETC Katy Pipeline expansions include the 36-inch East Texas extension to connect our Reed compressor station in Freestone County to our Grimes County compressor station, the 36-inch Katy expansion connecting Grimes to the Katy Hub and the 42-inch Southeast Bossier pipeline connecting our Cleburne to Carthage pipeline to the HPL System.
RIGS is a 450-mile intrastate pipeline that delivers natural gas from northwest Louisiana to downstream pipelines and markets.
OIT is a 2,200-mile pipeline system that provides natural gas transportation and storage services to customers in Oklahoma. OIT is a web-like configuration with multidirectional flow capabilities between numerous receipt points and delivery points. OIT delivers natural gas from the Anadarko and Arkoma basins, including the SCOOP, STACK, Cana Woodford, Granite Wash, Cleveland, Tonkawa and Mississippi Lime Shale plays in western Oklahoma to utilities and industrial end-users connected to OIT and to interstate and intrastate pipelines interconnected with OIT. OIT also has two underground natural gas storage facilities in Oklahoma, which operate at a combined capacity of 24 Bcf with a peak withdrawal rate of 0.60 Bcf/d.
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Comanche Trail Pipeline is a 195-mile intrastate pipeline that delivers natural gas from the Waha Hub near Pecos, Texas to the United States/Mexico border near San Elizario, Texas. The Partnership owns a 16% membership interest in and operates Comanche Trail Pipeline.
Trans-Pecos Pipeline is a 143-mile intrastate pipeline that delivers natural gas from the Waha Hub near Pecos, Texas to the United States/Mexico border near Presidio, Texas. The Partnership owns a 16% membership interest in and operates Trans-Pecos Pipeline.
The Red Bluff Express Pipeline is an approximately 120-mile intrastate pipeline that runs through the heart of the Delaware Basin and connects certain of our plants as well as third-party plants to the Waha Oasis Header. The Partnership owns a 70% membership interest in and operates Red Bluff Express Pipeline.
Other intrastate natural gas pipelines include our 630-mile Pelico Pipeline in northern Louisiana and our 167-mile Lobo Pipeline in South Texas.
Interstate Transportation and Storage
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The following details our pipelines in the interstate transportation and storage segment:
Description of AssetsOwnership InterestMiles of Natural Gas PipelinePipeline Throughput Capacity
(Bcf/d)
Working Storage Capacity
(Bcf)
Florida Gas Transmission (“FGT”)50 %5,380 4.0 — 
Transwestern Pipeline100 %2,590 2.1 — 
Panhandle Eastern Pipe Line (1)
100 %6,300 2.8 73.0 
Trunkline100 %2,190 0.9 13.0 
Tiger 100 %200 2.4 — 
Fayetteville Express Pipeline50 %185 2.0 — 
Sea Robin Pipeline100 %765 2.0 — 
Stingray Pipeline100 %335 0.4 — 
Rover Pipeline32.6 %720 3.4 — 
Midcontinent Express Pipeline50 %510 1.8 — 
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Enable Gas Transmission (“EGT”)100 %5,700 4.8 29.3 
Mississippi River Transmission (“MRT”)100 %1,675 1.7 48.9 
Southeast Supply Header (“SESH”)50 %290 1.1 — 
Gulf Run Pipeline100 %3353.0— 
(1)Storage capacity figure includes storage leased from Southwest Gas and third-party companies.
The following information describes our principal interstate transportation and storage assets:
FGT extends from South Texas through the Gulf Coast region of the United States to South Florida. FGT is the principal transporter of natural gas to the Florida energy market, delivering approximately 60% of the natural gas consumed in the state. In addition, FGT’s numerous intrastate and interstate pipeline interconnections with major interstate and intrastate natural gas pipelines provide access to diverse natural gas supply sources. FGT’s customers include electric utilities, independent power producers, industrial end-users and local distribution companies. FGT is owned by Citrus, a 50/50 joint venture with Kinder Morgan, Inc.
Transwestern Pipeline transports natural gas supply from the Permian Basin, the San Juan Basin and the Anadarko Basin. The system has bi-directional capabilities and can access Texas and Midcontinent natural gas market hubs as well as major western markets in Arizona, Nevada and California. Transwestern’s customers include local distribution companies, producers, marketers, electric power generators and industrial end-users.
Panhandle Eastern Pipe Line’s transmission system consists of four large diameter mainline pipelines with bi-directional capabilities, extending approximately 1,300 miles from producing areas in the Anadarko Basin of Texas, Oklahoma and Kansas through Missouri, Illinois, Indiana, Ohio and into Michigan. Panhandle contracts for over 73 Bcf of natural gas storage.
Trunkline’s transmission system consists of one large diameter mainline pipeline with bi-directional capabilities, extending approximately 1,400 miles from the Gulf Coast areas of Texas and Louisiana through Arkansas, Mississippi, Tennessee, Kentucky, Illinois, Indiana and Michigan. Trunkline has one natural gas storage field located in Louisiana.
Tiger is a bi-directional system that extends through the heart of the Haynesville Shale and ends near Delhi, Louisiana, interconnecting with multiple interstate pipelines.
Fayetteville Express Pipeline originates near Conway County, Arkansas and continues eastward to Panola County, Mississippi with multiple pipeline interconnections along the route. Fayetteville Express Pipeline is owned by a 50/50 joint venture with Kinder Morgan, Inc.
Sea Robin Pipeline’s system consists of two offshore Louisiana natural gas supply pipelines extending 120 miles into the Gulf of Mexico.
Stingray Pipeline is an interstate natural gas pipeline system with assets located in the western Gulf of Mexico and Johnson Bayou, Louisiana.
Rover Pipeline is a large diameter pipeline which transports natural gas from processing plants in West Virginia, eastern Ohio and western Pennsylvania for delivery to other pipeline interconnects in Ohio and Michigan, where the gas is delivered for distribution to markets across the United States and to Ontario, Canada.
Midcontinent Express Pipeline originates near Bennington, Oklahoma and traverses northern Louisiana and central Mississippi to an interconnect with the Transcontinental Gas Pipeline system in Butler, Alabama. The Midcontinent Express Pipeline is owned by a 50/50 joint venture with Kinder Morgan, Inc., the operator of the system.
EGT provides natural gas transportation and storage services to customers in Oklahoma, Texas, Arkansas, Louisiana, Missouri and Kansas. EGT has two underground storage facilities in Oklahoma and one underground natural gas storage facility in Louisiana. Through numerous pipeline interconnections along the system and at the Perryville Hub, EGT customers have access to Midwest and Northeast markets as well as most of the major natural gas consuming markets east of the Mississippi River.
MRT provides natural gas transportation and storage services in Texas, Arkansas, Louisiana, Missouri and Illinois. MRT has underground natural gas storage facilities in Louisiana and Illinois. MRT receives natural gas from a variety of interstate and intrastate pipelines through its interconnections and delivers natural gas primarily to the St. Louis market.
SESH, a 50/50 joint venture with Enbridge Inc., provides transportation services in Louisiana, Mississippi and Alabama. SESH transports natural gas from the Perryville Hub in Louisiana to its endpoint in Mobile County, Alabama. SESH has interconnections with third party natural gas pipelines and provides access to major Southeast and Northeast markets and
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transports directly to generating facilities in Mississippi and Alabama and to interconnecting pipelines that supply companies generating electricity for the Florida power market.
Gulf Run Pipeline is a large diameter pipeline that runs from the heart of the Haynesville Shale in East Texas and northern Louisiana to the Carthage and Perryville natural gas hubs and other key markets along the Gulf Coast.
Regasification Facility
Lake Charles LNG, our wholly owned subsidiary, owns an LNG import terminal and regasification facility located on Louisiana’s Gulf Coast near Lake Charles, Louisiana. The import terminal has approximately 9.0 Bcf of above ground LNG storage capacity and the regasification facility has a send out capacity of 1.8 Bcf/d. Lake Charles LNG derives all of its revenue from a series of long-term contracts with a wholly owned subsidiary of Royal Dutch Shell plc (“Shell”).
Liquefaction Project
Lake Charles LNG Export, our wholly owned subsidiary, is developing a natural gas liquefaction project at the site of our Lake Charles LNG import terminal and regasification facility. The project would utilize existing dock and storage facilities owned by Lake Charles LNG located on the Lake Charles site. Lake Charles LNG Export entered into a prior development agreement with Shell in March 2019; however, Shell withdrew from the project in March 2020 due to adverse market factors affecting Shell’s business following the onset of the COVID-19 pandemic. The project will benefit from the infrastructure related to the existing regasification facility at the same site, including four LNG storage tanks, two deep water docks and other assets. The construction of the liquefaction facility has been approved by FERC. In addition, Lake Charles LNG Export received its wetlands permits from the USACE to perform wetlands mitigation work and to perform modification and dredging work for the temporary and permanent dock facilities at the Lake Charles LNG facilities.
The export of LNG produced by any liquefaction facility in the United States requires export authorization from the DOE. The NGA requires the DOE to approve applications for LNG exports unless such approval would be “inconsistent with the public interest.” In March 2013, Lake Charles LNG Export obtained a DOE authorization to export LNG to countries with which the United States has or will have Free Trade Agreements (“FTA”) for trade in natural gas (the “FTA Authorization”). In July 2016, Lake Charles LNG Export also obtained a conditional DOE authorization to export LNG to countries that do not have an FTA for trade in natural gas (the “Non-FTA Authorization”) subject to commencement of exports no later than December 2020. Lake Charles LNG Export applied for an extension of the deadline to commence exports under the Non-FTA Authorization to December 2025 and the DOE approved such extension request in October 2020. Lake Charles LNG Export applied for a second extension of the deadline to commence exports and in April 2023 the DOE denied this request in connection with a new DOE policy related to extension requests. In light of this new policy, in August 2023, Lake Charles LNG Export applied for a new Non-FTA Authorization which, if approved, would provide for a new deadline to commence exports to Non-FTA countries, which deadline would be seven years from the date of such approval. In January 2024, the Biden administration announced a moratorium on the approval of LNG export authorizations by the DOE and instructed the DOE to conduct studies related to the cumulative impact of LNG exports on domestic natural gas prices, climate change and other matters. The Biden administration stated that these studies were necessary to enable the DOE to make determinations related to the statutory “public interest” standard. The DOE has stated that these studies will take several months to complete, after which a draft policy statement will be made available for public comment prior to finalizing the policy statement. This process is not expected to be completed prior to the U.S. Presidential election in November 2024.
During 2022, Lake Charles LNG Export executed six LNG offtake agreements, for an aggregate of nearly 8 million tonnes per annum, including a 20-year LNG agreement with Shell NA LNG LLC. The agreements allow either party to terminate the agreement if Lake Charles LNG Export has not satisfied specified conditions by a specified date. One of those conditions relates to Lake Charles LNG Export making a “final investment decision” to proceed with the construction of the liquefaction facility. To date, the specified dates for satisfying these conditions have been extended by mutual agreement of the parties to the agreements. We have also signed nonbinding letter agreements with several customers for LNG offtake, and we are in discussions with several parties for potential long-term LNG offtake and potential equity investments in the project.
During the moratorium imposed by the Biden administration on the approvals of LNG export authorizations by the DOE, Lake Charles LNG Export intends to continue to engage with existing and prospective LNG offtake customers and potential equity investors in the project.
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Midstream
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The following details our assets in the midstream segment:
Description of AssetsNet Gas Processing Capacity
(MMcf/d)
South Texas2,430 
Ark-La-Tex922 
North Central Texas700 
Permian Basin3,428 
Midcontinent2,925 
Williston Basin430 
Powder River Basin345 
Eastern200 
The following information describes our principal midstream assets:
South Texas:
Our South Texas assets, which include the Southeast Texas System and the Eagle Ford System, are an integrated system that gathers, compresses, treats, processes, dehydrates and transports natural gas from the Austin Chalk trend and the Eagle Ford Shale.
The assets in our Southeast Texas System include a large natural gas gathering system that covers thirteen counties between Austin and Houston, Texas and connects to the Katy Hub through the ETC Katy Pipeline and is also connected to the Oasis Pipeline. This system also includes three natural gas processing plants (La Grange, Alamo and Brookeland) with
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an aggregate capacity of 510 MMcf/d. These plants process the rich gas that flows through our gathering system to produce residue gas and NGLs. Residue gas is delivered into our intrastate pipelines and NGLs are delivered into our NGL pipelines.
Our treating facilities remove carbon dioxide and hydrogen sulfide from natural gas gathered into our system before the natural gas is introduced to transportation pipelines to ensure that the gas meets pipeline quality specifications.
The assets in our Eagle Ford System consist of 30-inch and 42-inch natural gas gathering pipelines originating in Dimmitt County, Texas, and extending to both our King Ranch gas plant in Kleberg County, Texas and Jackson plant in Jackson County, Texas. These assets also include four processing plants (Chisholm, Kenedy, Jackson and King Ranch) with an aggregate capacity of 1.9 Bcf/d. Our Chisholm, Kenedy, Jackson and King Ranch processing plants are connected to our intrastate transportation pipeline systems for deliveries of residue gas and are also connected with our NGL pipelines.
We own a 60% interest in Edwards Lime Gathering, LLC, which operates natural gas gathering, compression and treating facilities as well as an oil pipeline and oil stabilization facility in South Texas.
Ark-La-Tex:
Our Ark-La-Tex assets are comprised of several gathering systems in the Haynesville Shale with access to multiple markets through interconnects with several pipelines, including our Tiger pipeline. Our northern Louisiana assets include the Bistineau, Creedence, Tristate, Logansport, Magnolia, Olympia, Amoruso, and Lumberjack systems, which collectively include 11 natural gas treating facilities, with aggregate capacity of 3.1 Bcf/d.
The Ark-La-Tex assets gather, compress, treat and dehydrate natural gas in several parishes in northwest Louisiana and several counties in East Texas. These assets also include cryogenic natural gas processing facilities, a refrigeration plant, a conditioning plant, amine treating plants, a residue gas pipeline that provides market access for natural gas from our processing plants, including connections with pipelines that provide access to the Perryville Hub and other markets in the Gulf Coast region, and an NGL pipeline that connects to a third party that provides access to the Mont Belvieu market for NGLs produced from our processing plants. Collectively, the six natural gas processing facilities (Dubach, Lincoln, Rosewood, Mt. Olive, Sligo and Waskom) have an aggregate capacity of 0.9 Bcf/d.
Through the gathering and processing systems described above and their interconnections with our intrastate transportation pipelines, we offer producers wellhead-to-market services, including natural gas gathering, compression, processing, treating and transportation.
North Central Texas:
The North Central Texas System is an integrated system located in four counties in North Central Texas that gathers, compresses, treats, processes and transports natural gas from the Barnett and Woodford shales. Our North Central Texas assets include our Godley plant, which processes rich gas produced from the Barnett Shale and STACK play, with an aggregate capacity of 700 MMcf/d. The Godley plant is integrated with the ET Fuel System.
Permian Basin:
The Permian Basin Gathering System offers wellhead-to-market services to producers in 11 counties in West Texas and two counties in New Mexico which surround the Waha Hub, one of Texas’s developing NGL-rich natural gas market areas. As a result of the proximity of our system to the Waha Hub, the Waha Gathering System has a variety of market outlets for the natural gas that we gather and process, including several major interstate and intrastate pipelines serving California, the Midcontinent and Texas natural gas markets. The NGL market outlets includes our NGL pipeline system. The Permian Basin Gathering System includes 13 processing facilities (Waha, Red Bluff, Halley, Keystone, Tippet, Panther, Rebel, Grey Wolf, Bear, Arrowhead, Carlsbad, Orla I and Orla II) with an aggregate processing capacity of 3.2 Bcf/d and one natural gas conditioning facility with an aggregate capacity of 200 MMcf/d.
In addition, we own a 50% membership interest in Mi Vida JV LLC, a joint venture which owns a 200 MMcf/d cryogenic processing plant in West Texas. We operate the plant and related facilities on behalf of the joint venture. We also own a 50% equity interest in Crestwood Permian Basin LLC, a joint venture which owns the Nautilus natural gas gathering system in West Texas. We operate the gathering system on behalf of the joint venture.
Midcontinent:
The Midcontinent Systems are located in three large natural gas producing regions in the United States: the Hugoton Basin in southwest Kansas, the Anadarko Basin in the Texas Panhandle and Oklahoma, including the STACK and SCOOP plays, and the Arkoma Basin in eastern Oklahoma and Arkansas. These mature basins have continued to provide generally long-lived, predictable production volumes. Our Midcontinent assets are extensive systems that gather, compress and dehydrate low-pressure gas. The Midcontinent Systems include 17 natural gas processing facilities (Mocane, Beaver, Wheeler I,
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Sunray, Spearman, Rose Valley, Hopeton, Bradley, McClure, Wheeler II, South Canadian, Clinton, Roger Mills, Canute, Cox City, Wetumka and Grady) with an aggregate capacity of approximately 2.9 Bcf/d.
We operate our Midcontinent Systems at low pressures to maximize the total throughput volumes from the connected wells. Wellhead pressures are therefore adequate to allow for flow of natural gas into the gathering lines without the cost of wellhead compression.
We own the Hugoton Gathering System that has 1,900 miles of pipeline extending across parts of southwest Kansas and northwest Oklahoma. This system is operated by a third party.
We own a 50% membership interest in Atoka Midstream LLC, which owns a natural gas gathering system in Oklahoma.
Williston Basin:
We own and operate the Arrow and Rough Rider systems which include natural gas gathering systems and processing facilities (Bear Den and Wild Basin). These processing facilities have an aggregate capacity of 430 MMcf/d. The Arrow and Rough Rider systems are in the core of the Bakken Shale primarily in McKenzie and Dunn Counties, North Dakota, with the Arrow system primarily located on the Fort Berthold Indian Reservation.
Powder River Basin:
We own and operate the Jackalope rich natural gas gathering system, the Continental Express high-pressure pipeline and the Bucking Horse gas processing facility in Converse County, Wyoming. The Bucking Horse gas processing facility has an aggregate processing capacity of 345 MMcf/d.
Eastern:
The Eastern region assets are located in eleven counties in Pennsylvania, four counties in Ohio and three counties in West Virginia, which gather natural gas from the Marcellus and Utica shales. Our Eastern region assets include approximately 600 miles of natural gas gathering pipelines, natural gas trunklines and fresh-water pipelines, nine gathering and processing systems and the 200 MMcf/d Revolution processing plant, which feeds into our Mariner East and Rover pipeline systems.
We also own a 51% membership interest in Aqua – ETC Water Solutions LLC, a joint venture that transports and supplies fresh water to natural gas producers drilling in the Marcellus Shale in Pennsylvania.
We own a 75% membership interest in ORS. On behalf of ORS, we operate its Ohio Utica River System, which consists of 47 miles of 36-inch, 13 miles of 30-inch and 3 miles of 24-inch gathering trunklines, and which delivers up to 3.6 Bcf/d to Rockies Express Pipeline, Texas Eastern Transmission, Leach Xpress, Rover and DEO TPL-18.
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NGL and Refined Products Transportation and Services
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The following details the assets in our NGL and refined products transportation and services segment:
Description of AssetsMiles of Liquids PipelineNGL Fractionation / Processing Capacity
(MBbls/d)
Working Storage Capacity
(MBbls)
Liquids Pipelines:
Gulf Coast NGL Express900 — — 
West Texas Gateway510 — — 
Other Permian Basin NGL1,600 — — 
Mariner East680 — — 
Mariner West450 — — 
Mont Belvieu to Nederland270 — — 
White Cliffs(1)
540 — — 
Other NGL 750 — — 
Liquids Fractionation and Storage Facilities:
Mont Belvieu NGL Complex— 1,150 60,000 
Spindletop— — 8,000 
Crestwood— — 10,000 
ET Geismar Olefins(2)
— 35 — 
Hattiesburg — — 5,200 
Cedar Bayou— — 1,600 
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NGL Terminals:
Nederland— — 1,900 
Orbit Gulf Coast — — 1,200 
Marcus Hook— — 6,000 
Inkster— — 860 
Refined Products Pipelines:
Eastern region1,580 — — 
Midcontinent region 480 — — 
Southwest region 590 — — 
Inland 610 — — 
J.C. Nolan Pipeline500 — — 
Refined Products Terminals:
Eagle Point— — 6,700 
Marcus Hook Terminal— — 930 
Marcus Hook Tank Farm— — 1,900 
Marketing Terminals— — 7,700 
J.C. Nolan Terminal— — 130 
(1)The White Cliffs Pipeline consists of two parallel, 12-inch common carrier pipelines: one crude oil pipeline and one NGL pipeline.
(2)Additionally, the ET Geismar Olefins off-gas processing facility has inlet volume capacity of 54 MMcf/d.
The following information describes our principal NGL and refined products transportation and services assets:
Gulf Coast NGL Express is an interstate NGL pipeline consisting of 24-inch and 30-inch long-haul transportation pipelines, with throughput capacity of approximately 900 MBbls/d, that delivers mixed NGLs from processing plants in the Permian Basin, the Barnett Shale and from East Texas to our Mont Belvieu NGL Complex.
West Texas Gateway transports mixed NGLs produced in the Permian Basin and the Eagle Ford Shale to Mont Belvieu, Texas and has a throughput capacity of approximately 240 MBbls/d.
The Mariner East Pipeline System, consisting of Mariner East 2 and Mariner East 2x, has an aggregate capacity of 350 to 375 MBbls/d and transports NGLs from the Marcellus and Utica shales in western Pennsylvania, West Virginia and eastern Ohio to destinations in Pennsylvania, including our Marcus Hook Terminal on the Delaware River, where they are processed, stored and distributed to local, domestic and waterborne markets.
The Mariner West Pipeline provides transportation of ethane from the Marcellus Shale processing and fractionating areas in Houston, Pennsylvania to Marysville, Michigan and the Canadian border and has a throughput capacity of approximately 50 MBbls/d.
The Mont Belvieu to Nederland Pipeline System consists of four pipelines, which deliver export-grade propane, butane, ethane and natural gasoline from our Mont Belvieu NGL Complex to our Nederland Terminal, having a total throughput capacity of approximately 730 MBbls/d. The ethane pipeline is part of the Orbit Gulf Coast joint venture, as described below.
The White Cliffs NGL pipeline, in which we have 51% ownership interest, transports mixed NGLs produced in the DJ Basin to Cushing, Oklahoma where it interconnects with the Southern Hills Pipeline to move NGLs to Mont Belvieu, Texas and has a throughput capacity of approximately 90 MBbls/d.
Other NGL pipelines include the 127-mile Justice pipeline, 63-mile Blue Ridge pipeline, the 45-mile Freedom pipeline, the 20-mile Spirit pipeline and a 50% interest in the 87 mile Liberty pipeline. Through our recent acquisition of Crestwood, we also own an undivided interest in 80 MBbls/d of capacity in a segment of the EPIC Y-Grade Pipeline, LP (EPIC) pipeline from Orla, Texas to Benedum, Texas.
Our Mont Belvieu NGL Complex is an integrated liquids storage and fractionation facility. The storage facility has approximately 60 MMBbls of salt dome capacity providing 100% fee-based cash flows. The storage facility has access to multiple NGL and refined products pipelines, the Houston Ship Channel trading hub, numerous chemical plants, refineries and fractionators.
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The fractionation facility includes eight fractionators, which process NGLs delivered from several sources, including our Gulf Coast NGL Express, West Texas Gateway and Justice pipelines.
Our Spindletop storage facilities, located in Beaumont, Texas, have 8 MMBbls of salt dome capacity.
Acquired in 2023, Crestwood’s NGL storage assets include 13 LPG terminals which offer 10 MMBbls of storage capacity located in Pennsylvania, South Carolina, Mississippi, Michigan, New York and Indiana, with receipts and deliveries that are supported by both rail cars and third-party pipelines.
Other Crestwood assets include a fleet of rail and rolling stock with approximately 1.6 MMBbls/d of NGL pipeline, terminal and transportation capacity, which also includes rail-to-truck terminals located in Michigan, Indiana, Ohio, New Hampshire, Pennsylvania, New Jersey, New York, Rhode Island, North Carolina, South Carolina and Mississippi.
ET Geismar Olefins consists of a refinery off-gas processing unit and an o-grade NGL fractionation / Refinery-Grade Propylene (“RGP”) splitting complex located along the Mississippi River refinery corridor in southern Louisiana. The off-gas processing unit cryogenically processes refinery off-gas, and the fractionation / RGP splitting complex fractionates the streams into higher value components. The o-grade fractionator and RGP splitting complex, located in Geismar, Louisiana, is connected by approximately 100 miles of pipeline to the Chalmette processing plant, which has a processing capacity of 54 MMcf/d.
The Hattiesburg storage facility is an integrated liquids