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UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 10-K
(Mark One)
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2021
OR
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from                      to                     
Commission file number 1-4174
The Williams Companies, Inc.
(Exact Name of Registrant as Specified in Its Charter)
Delaware 73-0569878
(State or Other Jurisdiction of
Incorporation or Organization)
 (IRS Employer
Identification No.)
One Williams Center
TulsaOklahoma 74172
(Address of Principal Executive Offices) (Zip Code)
918-573-2000
(Registrant’s Telephone Number, Including Area Code)
Securities registered pursuant to Section 12(b) of the Act:
Title of Each ClassTrading Symbol(s)Name of Each Exchange on Which Registered
Common Stock, $1.00 par valueWMBNew 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     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  
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      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 (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).    Yes      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 filerAccelerated filerNon-accelerated filerSmaller reporting companyEmerging 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.
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act).    Yes      No  
The aggregate market value of the voting and non-voting common equity held by non-affiliates computed by reference to the price at which the common equity was last sold as of the last business day of the registrant’s most recently completed second quarter was approximately $31,296,220,520.
The number of shares outstanding of the registrant’s common stock outstanding at February 18, 2022 was 1,215,592,791.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the Registrant’s Definitive Proxy Statement for the Registrant’s Annual Meeting of Stockholders to be held on April 26, 2022, are incorporated into Part III, as specifically set forth in Part III.



THE WILLIAMS COMPANIES, INC.
FORM 10-K

TABLE OF CONTENTS
 Page
PART I
Item 1.
Item 1A.
Item 1B.
Item 2.
Item 3.
Item 4.
PART II
Item 5.
Item 7.
Item 7A.
Item 8.
Item 9.
Item 9A.
Item 9B.
Item 9C.
PART III
Item 10.
Item 11.
Item 12.
Item 13.
Item 14.
PART IV
Item 15.
Item 16.

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DEFINITIONS
The following is a listing of certain abbreviations, acronyms, and other industry terminology that may be used throughout this Annual Report.
Measurements:
Barrel: One barrel of petroleum products that equals 42 U.S. gallons
Mbbls/d: One thousand barrels per day
Bcf : One billion cubic feet of natural gas
Bcf/d: One billion cubic feet of natural gas per day
MMcf/d: One million cubic feet per day
British Thermal Unit (Btu): A unit of energy needed to raise the temperature of one pound of water by one degree Fahrenheit
MMbtu: One million British thermal units
Tbtu: One trillion British thermal units
Dekatherms (Dth): A unit of energy equal to one million British thermal units
Mdth/d: One thousand dekatherms per day
MMdth: One million dekatherms or approximately one trillion British thermal units
MMdth/d: One million dekatherms per day
Consolidated Entities:
BRMH: Blue Racer Midstream Holdings, LLC (previously named Caiman Energy II, LLC) a former equity-method investment, which is a consolidated entity following our acquisition of a controlling interest in November 2020 and the remaining interest in September 2021, whose primary asset is a 50 percent interest in Blue Racer accounted for as an equity-method investment
Cardinal: Cardinal Gas Services, L.L.C.
Gulfstar One: Gulfstar One LLC
Northeast JV: Ohio Valley Midstream LLC
Northwest Pipeline: Northwest Pipeline LLC
Transco: Transcontinental Gas Pipe Line Company, LLC
UEOM: Utica East Ohio Midstream LLC
Partially Owned Entities: Entities in which we do not own a 100 percent ownership interest and which, as of December 31, 2021, we account for as equity-method investments, including principally the following:
Aux Sable: Aux Sable Liquid Products LP
Blue Racer: Blue Racer Midstream LLC
Constitution: Constitution Pipeline Company, LLC
Discovery: Discovery Producer Services LLC
Gulfstream: Gulfstream Natural Gas System, L.L.C.
Jackalope: Jackalope Gas Gathering Services, L.L.C., which was sold in April 2019
Laurel Mountain: Laurel Mountain Midstream, LLC
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OPPL: Overland Pass Pipeline Company LLC
RMM: Rocky Mountain Midstream Holdings LLC
Targa Train 7: Targa Train 7 LLC
Government and Regulatory:
EPA: Environmental Protection Agency
Exchange Act, the: Securities and Exchange Act of 1934, as amended
FERC: Federal Energy Regulatory Commission
IRS: Internal Revenue Service
SEC: Securities and Exchange Commission
Other:
EBITDA: Earnings before interest, taxes, depreciation, and amortization
Fractionation: The process by which a mixed stream of natural gas liquids is separated into constituent products, such as ethane, propane, and butane
GAAP: U.S. generally accepted accounting principles
LNG: Liquefied natural gas; natural gas which has been liquefied at cryogenic temperatures
MVC: Minimum volume commitments
NGLs: Natural gas liquids; natural gas liquids result from natural gas processing and crude oil refining and are used as petrochemical feedstocks, heating fuels, and gasoline additives, among other applications
NGL margins: NGL revenues less Btu replacement cost, plant fuel, transportation, and fractionation
Sequent Acquisition: The July 1, 2021, acquisition of 100 percent of Sequent Energy Management, L.P. and Sequent Energy Canada, Corp.
The statements in this Annual Report that are not historical information, including statements concerning plans and objectives of management for future operations, economic performance or related assumptions, are forward-looking statements. Forward-looking statements may be identified by various forms of words such as “anticipates,” “believes,” “seeks,” “could,” “may,” “should,” “continues,” “estimates,” “expects,” “forecasts,” “intends,” “might,” “goals,” “objectives,” “targets,” “planned,” “potential,” “projects,” “scheduled,” “will,” “assumes,” “guidance,” “outlook,” “in-service date,” or other similar expressions and other words and terms of similar meaning. Although we believe that our expectations regarding future events are based on reasonable assumptions, we can give no assurance that such expectations or assumptions will be achieved. Additional information regarding forward-looking statements and important factors that could cause actual results to differ materially from those in the forward-looking statements are described under Part I, Item 1A in this Annual Report.


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PART I

Item 1. Business
In this report, Williams (which includes The Williams Companies, Inc. and, unless the context otherwise indicates, all of our subsidiaries) is at times referred to in the first person as “we,” “us,” or “our.” We also sometimes refer to Williams as the “Company.”
GENERAL
We are an energy company committed to being the leader in providing infrastructure that safely delivers natural gas products to reliably fuel the clean energy economy. We have operations in 14 supply areas that provide natural gas gathering, processing, and transmission services, NGLs fractionation, transportation, and storage services, and marketing services to more than 600 customers. We own an interest in and operate over 30,000 miles of pipelines, 29 processing facilities, 7 fractionation facilities, and approximately 23 million barrels of NGL storage capacity, and deliver natural gas that is used every day for clean-power generation, heating, and industrial use.
wmb-20211231_g1.jpg
We were founded in 1908, originally incorporated under the laws of the state of Nevada in 1949 and reincorporated under the laws of the state of Delaware in 1987. Our common stock trades on the New York Stock Exchange under the symbol “WMB.” Our operations are located in the United States. Williams’ headquarters are located in Tulsa, Oklahoma, with other major offices in Salt Lake City, Utah; Houston, Texas; and Pittsburgh, Pennsylvania. Our telephone number is 918-573-2000.


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wmb-20211231_g2.jpg
Service Assets, Customers, and Contracts
Key variables for our businesses will continue to be:
Obstacles to our expansion efforts, including delays or denials of necessary permits and opposition to hydrocarbon-based energy development;
Producer drilling activities impacting natural gas supplies supporting our gathering and processing volumes;
Retaining and attracting customers by continuing to provide reliable services;
Revenue growth associated with additional infrastructure either completed or currently under construction;
Prices impacting our commodity-based activities;
Disciplined growth in our service areas.
Interstate Natural Gas Pipeline Assets
Our interstate natural gas pipelines, which are presented in our Transmission & Gulf of Mexico segment as described under the heading “Business Segments,” are subject to regulation by the FERC and as such, our rates and charges for the transportation of natural gas in interstate commerce are subject to regulation. The rates are established primarily through the FERC’s ratemaking process, but we also may negotiate rates with our customers pursuant to the terms of our tariffs and FERC policy.
Our interstate natural gas pipelines transport and store natural gas for a broad mix of customers, including local natural gas distribution companies, public utilities, municipalities, direct industrial users, electric power generators, and natural gas marketers and producers. Our interstate natural gas transmission businesses are fully contracted under long-term firm reservation contracts with high credit quality customers. These contracts have various expiration dates and account for the major portion of our regulated businesses. Additionally, we offer storage
5


services and interruptible transportation services under shorter-term agreements. Transco’s and Northwest Pipeline’s three largest customers in 2021 accounted for approximately 26 percent and 52 percent, respectively, of their total operating revenues.
Gathering, Processing, and Treating Assets
Our gathering, processing, and treating operations are presented within our Transmission & Gulf of Mexico, Northeast G&P, and West reporting segments as described under the heading “Business Segments.”
Our gathering systems receive natural gas from producers’ crude oil and natural gas wells and gather these volumes to gas processing, treating, or redelivery facilities. Typically, natural gas, in its raw form, is not acceptable for transportation in major interstate natural gas pipelines or for commercial use as a fuel. Our treating facilities remove water vapor, carbon dioxide, and other contaminants, and collect condensate. We are generally paid a fee based on the volume of natural gas gathered and/or treated, generally measured in the Btu heating value.

In addition, natural gas contains various amounts of NGLs, which generally have a higher value when separated from the natural gas stream. Our processing plants extract the NGLs, which include ethane, primarily used in the petrochemical industry; propane, used for heating, fuel, and also in the petrochemical industry; and, normal butane, isobutane, and natural gasoline, primarily used by the refining industry.
Our gas processing services generate revenues primarily from the following types of contracts:
Fee-based: We are paid a fee based on the volume of natural gas processed, generally measured in the Btu heating value. A portion of our fee-based processing revenue includes a share of the margins on the NGLs produced. For the year ended December 31, 2021, approximately 90 percent of our NGL production volumes were under fee-based contracts.
Noncash commodity-based: We also process gas under two types of commodity-based contracts, keep-whole and percent-of-liquids, where we receive consideration for our services in the form of NGLs. For a keep-whole arrangement we replace the Btu content of the retained NGLs with natural gas purchases, also known as shrink replacement gas. For a percent-of-liquids arrangement, we deliver an agreed-upon percentage of the extracted NGLs and retain the remainder. Retained NGLs are referred to as our equity NGL production. Per-unit NGL margins are calculated based on sales of our own equity volumes at the processing plants. For the year ended December 31, 2021, approximately 10 percent of our NGL production volumes were under noncash commodity-based contracts.
Generally, our gathering and processing agreements are long-term agreements, with terms ranging from month-to-month to the life of the producing lease. Certain contracts include cost of service mechanisms that are designed to support a return on invested capital and allow our gathering rates to be adjusted, subject to specified caps in certain cases, to account for variability in volume, capital expenditures, commodity price fluctuations, compression, and other expenses. We also have certain gas gathering and processing agreements with MVC, whereby the customer is obligated to pay a contractually determined fee based on any shortfall between the actual gathered and processed volumes and the MVC for a stated period.
Demand for gas gathering and processing services is dependent on producers’ drilling activities, which is impacted by the strength of the economy, commodity prices, and the resulting demand for natural gas by manufacturing and industrial companies and consumers. Our gathering, processing, and treating businesses do not have direct exposure to crude oil prices. Our on-shore natural gas gathering and processing businesses are substantially focused on gas-directed drilling basins rather than crude oil, with a broad diversity of basins and customers served. Declines in crude oil drilling would be expected to result in less associated natural gas production, which could drive more demand for natural gas produced from gas-directed basins we serve.
During 2021, our facilities gathered and processed gas and crude oil for approximately 220 customers. Our top ten customers accounted for approximately 75 percent of our gathering and processing fee revenues and NGL margins from our noncash commodity-based agreements. We believe counterparty credit concerns in our gathering
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and processing businesses are significantly mitigated by the physical nature of our services, where we gather at the wellhead and are therefore critical to a producer’s ability to move product to market.
Gas and NGL Marketing
Prior to the organizational realignment described under the heading “Business Segments,” certain of our commodity marketing activities were presented within our West reporting segment, while those acquired in 2021 as part of our Sequent Acquisition, which includes the operations of Sequent Energy Management, L.P. and Sequent Energy Canada, Corp. acquired on July 1, 2021 (Sequent Acquisition), were reported within the Sequent segment. Beginning in January 2022, our NGL and natural gas marketing services are now presented primarily within our Gas & NGL Marketing Services segment. We market natural gas and NGL products to a wide range of users in the energy and petrochemical industries. In 2021, our three largest natural gas marketing customers accounted for approximately 13 percent of our gross natural gas marketing sales, and our three largest NGL marketing customers accounted for approximately 46 percent of our NGL marketing sales.
Our gas marketing business markets natural gas from the production at our upstream properties and provides asset management and the wholesale marketing, trading, storage, and transportation of natural gas for a diverse set of natural gas utilities, municipalities, power generators, and producers, and moves gas to markets through transportation and storage agreements on strategically positioned assets. Our pipeline agreements connect with multiple pipelines that provide our customers with access to diverse sources of supply and various natural gas markets. The southeastern market served by our Gas & NGL Marketing Services segment is the fastest growing natural gas demand region in the United States and expands our natural gas marketing activities, as well as optimizes our pipeline and storage capabilities with expansions into new markets.
We purchase natural gas for storage when the current market price paid to buy and transport natural gas plus the cost to store and finance the natural gas is less than an estimated, forward market price that can be received in the future, resulting in positive net product sales. Commodity-based exchange-traded futures contracts and over-the-counter (OTC) contracts are used to sell natural gas at that future price to substantially protect the natural gas revenues that will ultimately be realized when the stored natural gas is sold. Additionally, we enter into transactions to secure transportation capacity between delivery points in order to serve our customers and various markets. Commodity-based exchange-traded futures contracts and OTC contracts are used to capture the price differential or spread between the locations served by the capacity in order to substantially protect the natural gas revenues that will ultimately be realized when the physical flow of natural gas between receipt and delivery points occurs.
Monthly demand charges incurred for the contracted storage and transportation capacity and payments associated with asset management agreements are substantially indirectly reimbursed by our customers. As we are acting as an agent, our natural gas marketing revenues are presented net of the related costs of those activities. In addition, all of our Sequent’s derivative activities qualify as held for trading purposes, which requires net presentation in the Consolidated Statement of Income. Prior to the integration in 2022 of our historical gas marketing business with the acquired Sequent gas marketing business, natural gas marketing revenues and costs for our historical business were reported on a gross basis. Following the integration in 2022, the entire natural gas marketing portfolio is considered held for trading purposes, and the related revenues are therefore presented net of the related costs of those activities in 2022.
Our NGL marketing business transports and markets our equity NGLs from the production at our processing plants, NGLs from the production at our upstream properties, and also NGLs on behalf of third-party NGL producers, including some of our fee-based processing customers, as well as the NGL volumes owned by RMM and Discovery. The NGL marketing business bears the risk of price changes in these NGL volumes while they are being transported to final sales delivery points. In order to meet sales contract obligations, we may purchase products in the spot market for resale.
We are exposed to commodity price risk. To manage this volatility, we use various contracts in our marketing and trading activities that generally meet the definition of derivatives. We enter into commodity-related derivatives to hedge exposures to natural gas and NGLs and retain exposure to price changes that can, in a volatile energy market, be material and can adversely affect our results of operations.
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We experience significant earnings volatility from the fair value accounting required for the derivatives used to hedge a portion of the economic value of the underlying transportation and storage portfolio. However, the unrealized fair value measurement gains and losses are generally offset by valuation changes in the economic value of the underlying transportation and storage portfolio, which is not recognized until the underlying transportation and storage transaction occurs.
Crude Oil Transportation and Production Handling Assets
Our crude oil transportation operations, which are presented in our Transmission & Gulf of Mexico segment as described under the heading “Business Segments,” earn revenues primarily from a combination of fixed-monthly fees, contractual fixed or variable fees applied to production volumes, and contributions in aid of construction (CIAC) arrangements. Generally, fixed-monthly fees associated with production handling and export revenues are recognized on a units-of-production basis utilizing either contractually determined maximum daily quantities or expected remaining production. CIAC arrangements are recognized based on a units of production basis, utilizing expected remaining production. Our crude oil transportation business is supported mostly by major oil producers with long-cycle perspectives.
BUSINESS SEGMENTS
Consistent with the manner in which our chief operating decision maker evaluates performance and allocates resources, our operations are conducted, managed, and presented in Part I of this Annual Report within the following reportable segments: Transmission & Gulf of Mexico, Northeast G&P, West, and Gas & NGL Marketing Services. Effective January 1, 2022, following an organizational realignment, our NGL and natural gas marketing services, previously reported within the West and former Sequent segments, are now all managed within the Gas & NGL Marketing Services segment.
Our reportable segments are comprised of the following business activities:
Transmission & Gulf of Mexico is comprised of our interstate natural gas pipelines, Transco and Northwest Pipeline, as well as natural gas gathering and processing and crude oil production handling and transportation assets in the Gulf Coast region, including a 51 percent interest in Gulfstar One (a consolidated variable interest entity), which is a proprietary floating production system, a 50 percent equity-method investment in Gulfstream, and a 60 percent equity-method investment in Discovery.
Northeast G&P is comprised of our midstream gathering, processing, and fractionation businesses in the Marcellus Shale region primarily in Pennsylvania and New York, and the Utica Shale region of eastern Ohio, as well as a 65 percent interest in our Northeast JV (a consolidated variable interest entity) which operates in West Virginia, Ohio, and Pennsylvania, a 66 percent interest in Cardinal (a consolidated variable interest entity) which operates in Ohio, a 69 percent equity-method investment in Laurel Mountain, a 50 percent equity-method investment in Blue Racer, and Appalachia Midstream Investments, a wholly owned subsidiary that owns equity-method investments with an approximate average 66 percent interest in multiple gas gathering systems in the Marcellus Shale region.
West is comprised of our gas gathering, processing, and treating operations in the Rocky Mountain region of Colorado and Wyoming, the Barnett Shale region of north-central Texas, the Eagle Ford Shale region of south Texas, the Haynesville Shale region of northwest Louisiana, and the Mid-Continent region which includes the Anadarko and Permian basins. This segment also includes our NGL storage facilities, an undivided 50 percent interest in an NGL fractionator near Conway, Kansas, a 50 percent equity-method investment in OPPL, a 50 percent equity-method investment in RMM, and a 20 percent equity-method investment in Targa Train 7.
Gas & NGL Marketing Services includes our NGL and natural gas marketing services previously reported within the West segment prior to January 1, 2022, as well as the operations acquired on July 1, 2021 through our Sequent Acquisition.
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Other includes our upstream operations and minor business activities that are not reportable segments, as well as corporate operations.
Detailed discussion of each of our reportable segments follows. For a discussion of our ongoing expansion projects, see Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations, which along with Item 8. Financial Statements and Supplementary Data, continues to present our segments as they were historically defined before the organizational realignment on January 1, 2022.
Transmission & Gulf of Mexico
This segment includes the Transco interstate natural gas pipeline that extends from the Gulf of Mexico to the eastern seaboard, the Northwest Pipeline interstate natural gas pipeline, as well as natural gas gathering, processing and treating, crude oil production handling, and NGL fractionation assets within the onshore, offshore shelf, and deepwater areas in and around the Gulf Coast states of Texas, Louisiana, Mississippi, and Alabama. This segment also includes various petrochemical and feedstock pipelines in the Gulf Coast region.
Transco
Transco is an interstate natural gas transmission company that owns and operates a 9,800-mile natural gas pipeline system, which is regulated by the FERC, extending from Texas, Louisiana, Mississippi, and the Gulf of Mexico through Alabama, Georgia, South Carolina, North Carolina, Virginia, Maryland, Delaware, Pennsylvania, and New Jersey to the New York City metropolitan area. The system serves customers in Texas and 12 southeast and Atlantic seaboard states, including major metropolitan areas in Georgia, North Carolina, Washington, D.C., Maryland, New York, New Jersey, and Pennsylvania.
At December 31, 2021, Transco’s system had a system-wide delivery capacity totaling approximately 18.6 MMdth/d. During 2021, Transco completed two fully-contracted expansions, which added more than 0.5 MMdth/d interim firm transportation capacity to the pipeline. In addition, we added more than 0.1 MMdth/d of interim firm transportation capacity to our pipeline which will continue until the Regional Energy Access expansion project is placed in service, please refer to Part II, Item 7 “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Company Outlook.” Transco’s system includes 59 compressor stations, four underground storage fields, and one LNG storage facility. Compression facilities at sea level-rated capacity total approximately 2.4 million horsepower.
Transco has natural gas storage capacity in four underground storage fields located on or near its pipeline system or market areas and operates two of these storage fields. Transco also has storage capacity in an LNG storage facility that it owns and operates. The total usable gas storage capacity available to Transco and its customers in such underground storage fields and LNG storage facility and through storage service contracts is approximately 194 MMdth of natural gas. At December 31, 2021, Transco’s customers had stored in its facilities approximately 140 MMdth of natural gas. Storage capacity permits our customers to inject gas into storage during the summer and off-peak periods for delivery during peak winter demand periods.
Northwest Pipeline
Northwest Pipeline is an interstate natural gas transmission company that owns and operates a 3,900-mile natural gas pipeline system, which is regulated by the FERC, extending from the San Juan basin in northwestern New Mexico and southwestern Colorado through Colorado, Utah, Wyoming, Idaho, Oregon, and Washington to a point on the Canadian border near Sumas, Washington. Northwest Pipeline provides services for markets in Washington, Oregon, Idaho, Wyoming, Nevada, Utah, Colorado, New Mexico, California, and Arizona, either directly or indirectly through interconnections with other pipelines.
At December 31, 2021, Northwest Pipeline’s system had long-term firm transportation and storage redelivery agreements with aggregate capacity reservations of approximately 3.8 MMdth/d. Northwest Pipeline’s system includes 42 transmission compressor stations having a combined sea level-rated capacity of approximately 473,000 horsepower.
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Northwest Pipeline owns a one-third undivided interest in the Jackson Prairie underground storage facility in Washington and contracts with a third party for natural gas storage services in an underground storage reservoir in the Clay Basin field in Utah. Northwest Pipeline also owns and operates a LNG storage facility in Washington. These storage facilities have an aggregate working natural gas storage capacity of 14.2 MMdth, which is substantially utilized for third-party natural gas. These natural gas storage facilities enable Northwest Pipeline to balance daily receipts and deliveries and provide storage services to customers.
Gas Transportation, Processing, and Treating Assets
The following tables summarize the significant operated assets of this segment:
Offshore Natural Gas Pipelines
Inlet
PipelineCapacityOwnership
LocationMiles(Bcf/d)InterestSupply Basins
Consolidated:
Canyon Chief, including Blind Faith and Gulfstar extensionsDeepwater Gulf of Mexico1560.5100%Eastern Gulf of Mexico
NorphletDeepwater Gulf of Mexico580.3100%Eastern Gulf of Mexico
Other Eastern GulfOffshore shelf and other460.2100%Eastern Gulf of Mexico
SeahawkDeepwater Gulf of Mexico1150.4100%Western Gulf of Mexico
Perdido NorteDeepwater Gulf of Mexico1050.3100%Western Gulf of Mexico
Other Western GulfOffshore shelf and other650.3100%Western Gulf of Mexico
Non-consolidated: (1)
Discovery
Central Gulf of Mexico5940.660%Central Gulf of Mexico
Natural Gas Processing Facilities
NGL
InletProduction
CapacityCapacityOwnership
Location(Bcf/d)(Mbbls/d)InterestSupply Basins
Consolidated:
Markham
Markham, TX0.545100%Western Gulf of Mexico
Mobile Bay
Coden, AL0.735100%Eastern Gulf of Mexico
Non-consolidated: (1)
DiscoveryLarose, LA0.63260%Central Gulf of Mexico
_____________
(1)Includes 100 percent of the statistics associated with operated equity-method investments.
Crude Oil Transportation and Production Handling Assets
In addition to our natural gas assets, we own and operate four deepwater crude oil pipelines and own production platforms serving the deepwater in the Gulf of Mexico. Our offshore floating production platforms provide centralized services to deepwater producers such as compression, separation, production handling, water removal, and pipeline landings.
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The following tables summarize the significant crude oil transportation pipelines and production handling platforms of this segment:
 Crude Oil Pipelines
 PipelineCapacityOwnership
 Miles(Mbbls/d)InterestSupply Basins
Consolidated:
Mountaineer, including Blind Faith and Gulfstar extensions
155150100%Eastern Gulf of Mexico
BANJO
5790100%Western Gulf of Mexico
Alpine
9685100%Western Gulf of Mexico
Perdido Norte
74150100%Western Gulf of Mexico

 Production Handling Platforms
Crude/NGL
Gas InletHandling
 CapacityCapacityOwnership
 (MMcf/d)(Mbbls/d)InterestSupply Basins
Consolidated:
Devils Tower
11060100%Eastern Gulf of Mexico
Gulfstar I FPS (1)
1728051%Eastern Gulf of Mexico
Non-consolidated: (2)
Discovery
751060%Central Gulf of Mexico
__________
(1)Statistics reflect 100 percent of the assets from our 51 percent interest in Gulfstar One.
(2)Includes 100 percent of the statistics associated with operated equity-method investments.

Transmission & Gulf of Mexico Operating Statistics
202120202019
(Annual Average Amounts)
Consolidated:
Interstate natural gas pipeline throughput (Tbtu/d)16.2 15.1 15.3 
Gathering volumes (Bcf/d) 0.28 0.25 0.25 
Plant inlet natural gas volumes (Bcf/d) 0.45 0.48 0.54 
NGL production (Mbbls/d)29 29 32 
NGL equity sales (Mbbls/d)
Crude oil transportation (Mbbls/d)134 121 136 
Non-consolidated: (1)
Interstate natural gas pipeline throughput (Tbtu/d)1.2 1.2 1.2 
Gathering volumes (Bcf/d)0.35 0.30 0.36 
Plant inlet natural gas volumes (Bcf/d)0.35 0.30 0.36 
NGL production (Mbbls/d)27 21 25 
NGL equity sales (Mbbls/d)
_____________
(1)Includes 100 percent of the volumes associated with operated equity-method investments.
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Certain Equity-Method Investments
Gulfstream
Gulfstream is a 745-mile interstate natural gas pipeline system extending from the Mobile Bay area in Alabama to markets in Florida, which has a capacity to transport 1.3 Bcf/d. We own, through a subsidiary, a 50 percent equity-method investment in Gulfstream. We share operating responsibilities for Gulfstream with the other 50 percent owner.
Discovery
We own a 60 percent interest in and operate the facilities of Discovery. Discovery’s assets include a 600 MMcf/d cryogenic natural gas processing plant near Larose, Louisiana, a 32 Mbbls/d NGL fractionator plant near Paradis, Louisiana, and a 594-mile offshore natural gas gathering and transportation system in the Gulf of Mexico. Discovery’s mainline has a gathering inlet capacity of 600 MMcf/d. Discovery’s assets also include a crude oil production handling platform with capacity of 10 Mbbls/d and gas handling and separation capacity of 75 MMcf/d.
Northeast G&P
This segment includes our natural gas gathering, compression, processing, and NGL fractionation businesses in the Marcellus and Utica Shale regions in Pennsylvania, West Virginia, New York, and Ohio.

The following tables summarize the significant operated assets of this segment:
 Natural Gas Gathering Assets
Inlet
 PipelineCapacityOwnership
 LocationMiles(Bcf/d)InterestSupply Basins
Consolidated:
Ohio Valley Midstream (1)Ohio, West Virginia, & Pennsylvania2160.865%Appalachian
Utica East Ohio Midstream (1) (2)Ohio530.565%Appalachian
Susquehanna Supply HubPennsylvania & New York4764.3100%Appalachian
Cardinal (1)Ohio3830.866%Appalachian
FlintOhio990.5100%Appalachian
Non-consolidated: (3)
Bradford Supply HubPennsylvania7504.066%Appalachian
Marcellus SouthPennsylvania & West Virginia2901.368%Appalachian
Laurel MountainPennsylvania1,1450.969%Appalachian
 Natural Gas Processing Facilities
NGL
InletProduction
 CapacityCapacityOwnership
 Location(Bcf/d)(Mbbls/d)InterestSupply Basins
Consolidated: (1)
Fort BeelerMarshall Co., WV0.56265%Appalachian
Oak GroveMarshall Co., WV0.67565%Appalachian
KensingtonColumbiana Co., OH0.66865%Appalachian
LeesvilleCarroll Co., OH0.21865%Appalachian
_____________
(1)Statistics reflect 100 percent of the assets from our 65 percent ownership in our Northeast JV and 66 percent ownership of Cardinal gathering system.
(2)UEOM inlet capacity consists of 1.3 Bcf/d of a high pressure gathering pipeline that delivers Cardinal gathering volumes to UEOM processing facilities. The listed inlet capacity of 0.5 Bcf/d is incremental capacity to the Cardinal gathering capacity of 0.8 Bcf/d.
(3)Includes 100 percent of the statistics associated with operated equity-method investments.
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Other NGL Operations
We own and operate a 43 Mbbls/d NGL fractionation facility at Moundsville, West Virginia, de-ethanization and condensate facilities at our Oak Grove processing plant, a condensate stabilization facility near our Moundsville fractionator, an ethane pipeline, and an NGL pipeline. Our Oak Grove de-ethanizer is capable of handling up to approximately 80 Mbbls/d of mixed NGLs to extract up to approximately 40 Mbbls/d of ethane. Our condensate stabilizers are capable of handling approximately 17 Mbbls/d of field condensate. We also own and operate 44 Mbbls/d of condensate stabilization capacity, a 135 Mbbls/d NGL fractionation facility, approximately 970,000 barrels of NGL storage capacity, and other ancillary assets, including loading and terminal facilities in Ohio.
NGLs are extracted from the natural gas stream in our Oak Grove and Fort Beeler cryogenic processing plants. Ethane produced at our de-ethanizer is transported to markets via our 50-mile ethane pipeline from Oak Grove to Houston, Pennsylvania. The remaining mixed NGL stream from the de-ethanizer is then transported via our 50-mile NGL pipeline and fractionated at either our Moundsville or Harrison County, Ohio, fractionation facility. The resulting products are then transported on truck or rail. Ohio Valley Midstream provides residue natural gas take away options for our customers with interconnections to three interstate transmission pipelines.
Northeast G&P Operating Statistics
202120202019
(Annual Average Amounts)
Consolidated:
Gathering volumes (Bcf/d)4.24 4.31 4.24 
Plant inlet natural gas volumes (Bcf/d)1.57 1.32 1.04 
NGL production (Mbbls/d) (1)115 103 76 
NGL equity sales (Mbbls/d)
Non-consolidated: (2)
Gathering volumes (Bcf/d)5.52 4.78 4.29 
__________
(1)    2020 amount has been updated to reflect revised NGL production.
(2)    Includes 100 percent of the volumes associated with operated equity-method investments, including the Laurel Mountain Midstream partnership; and the Bradford Supply Hub and the Marcellus South Supply Hub within Appalachia Midstream Investments.
Acquisition of UEOM and formation of Northeast JV
As of December 31, 2018, we owned a 62 percent interest in UEOM which we accounted for as an equity-method investment. On March 18, 2019, we signed and closed the acquisition of the remaining 38 percent interest in UEOM. As a result of acquiring this additional interest, we obtained control of and consolidated UEOM. (See Note 3 – Acquisitions of Notes to Consolidated Financial Statements).
In June 2019, we contributed our consolidated interests in UEOM and our Ohio Valley midstream business to a newly formed partnership, and we retained 65 percent ownership of, as well as operate and consolidate, the Northeast JV business.
Certain Equity-Method Investments
Appalachia Midstream Investments    
Through our Appalachia Midstream Investments, we operate 100 percent of and own an approximate average 66 percent interest in the Bradford Supply Hub gathering system and own an approximate average 68 percent interest in the Marcellus South gathering system, together which consist of approximately 1,040 miles of gathering pipeline in the Marcellus Shale region with the capacity to gather 5,330 MMcf/d of natural gas. The majority of our volumes in the region are gathered from northern Pennsylvania, southwestern Pennsylvania, and the northwestern
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panhandle of West Virginia in core areas of the Marcellus Shale. We operate the assets under long-term, 100 percent fixed-fee gathering agreements that include significant acreage dedications and, in the Bradford Supply Hub, a cost of service mechanism. Additionally, some Marcellus South agreements have MVCs.
Laurel Mountain
We own a 69 percent interest in a joint venture, Laurel Mountain, that includes a 1,145-mile gathering system that we operate in western Pennsylvania with the capacity to gather 0.9 Bcf/d of natural gas. Laurel Mountain has a long-term, dedicated, volumetric-based fee agreement, with exposure to natural gas prices, to gather the anchor customer’s production in the western Pennsylvania area of the Marcellus Shale.
Blue Racer
We own a 50 percent interest in Blue Racer which is operated by Blue Racer Midstream Holdings, LLC. Blue Racer is a joint venture to own, operate, develop, and acquire midstream assets in the Utica Shale and certain adjacent areas in the Marcellus Shale. Blue Racer’s assets include 723 miles of gathering pipelines, and the Natrium complex in Marshall County, West Virginia, with a cryogenic processing capacity of 800 MMcf/d and fractionation capacity of approximately 134 Mbbls/d. Blue Racer also owns the Berne complex in Monroe County, Ohio, with a cryogenic processing capacity of 400 MMcf/d, and NGL and condensate pipelines connecting Natrium to Berne. Blue Racer provides gathering, processing, and marketing services primarily under percent-of-liquids and fixed-fee agreements.
West
Gas Gathering, Processing, and Treating Assets
The following tables summarize the significant operated assets of this segment:
 Natural Gas Gathering Assets
 LocationPipeline MilesInlet Capacity (Bcf/d)Ownership InterestSupply Basins/Shale Formations
Consolidated:
WamsutterWyoming2,2650.7100%Wamsutter
Southwest WyomingWyoming1,6140.5100%Southwest Wyoming
PiceanceColorado3521.8100%Piceance
Barnett ShaleTexas8400.5100%Barnett Shale
Eagle Ford ShaleTexas1,2470.5100%Eagle Ford Shale
Haynesville ShaleLouisiana6481.8100%Haynesville Shale
PermianTexas1120.1100%Permian
Mid-ContinentOklahoma & Texas1,8050.3100%Miss-Lime, Granite Wash, Colony Wash
Non-consolidated: (1)
Rocky Mountain MidstreamColorado2080.650%Denver-Julesburg

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 Natural Gas Processing Facilities
NGL
InletProduction
 CapacityCapacityOwnership
 Location(Bcf/d)(Mbbls/d)InterestSupply Basins
Consolidated:
Echo SpringsEcho Springs, WY0.758100%Wamsutter
OpalOpal, WY1.1