10-K

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-K

(Mark One)

þ	ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the fiscal year ended December 31, 2016
	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, Tulsa, Oklahoma	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 Class	Name of Each Exchange on Which Registered
Common Stock, $1.00 par value	New 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 þ    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  þ

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  þ    No  ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).    Yes  þ    No  ¨

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§229.405 of this chapter) is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.  ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer þ	Accelerated filer ¨		Non-accelerated filer ¨	Smaller reporting company ¨
		(Do not check if a smaller reporting company)

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act).    Yes  ¨    No  þ

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 $16,207,908,251.

The number of shares outstanding of the registrant’s common stock outstanding at February 17, 2017 was 825,823,918.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the Registrant’s Definitive Proxy Statement for the Registrant’s Annual Meeting of Stockholders to be held on May 18, 2017, 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.	Business	4
	Website Access to Reports and Other Information	4
	General	4
	Financial Repositioning	4
	Sale of Our Canadian Operations	5
	Energy Transfer Merger Agreement	5
	Organizational Realignment	5
	Financial Information About Segments	5
	Business Segments	5
	Williams Partners	6
	Williams NGL & Petchem Services	16
	Additional Business Segment Information	16
	Regulatory Matters	16
	Environmental Matters	19
	Competition	19
	Employees	20
	Financial Information about Geographic Areas	20
Item 1A.	Risk Factors	21
Item 1B.	Unresolved Staff Comments	38
Item 2.	Properties	38
Item 3.	Legal Proceedings	38
Item 4.	Mine Safety Disclosures	39
	Executive Officers of the Registrant	40
PART II
Item 5.	Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	44
Item 6.	Selected Financial Data	45
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	46
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	76
Item 8.	Financial Statements and Supplementary Data	78
Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	155
Item 9A.	Controls and Procedures	155
Item 9B.	Other Information	158
PART III
Item 10.	Directors, Executive Officers and Corporate Governance	158
Item 11.	Executive Compensation	158
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	158
Item 13.	Certain Relationships and Related Transactions, and Director Independence	159
Item 14.	Principal Accountant Fees and Services	159
PART IV
Item 15.	Exhibits and Financial Statement Schedules	160

1

DEFINITIONS

The following is a listing of certain abbreviations, acronyms and other industry terminology used throughout this Annual Report.

Measurements:

Barrel: One barrel of petroleum products that equals 42 U.S. gallons

Bcf : One billion cubic feet of natural gas

Bcf/d: One billion cubic feet of natural gas per day

British Thermal Unit (Btu): A unit of energy needed to raise the temperature of one pound of water by one degree

Fahrenheit

Dekatherms (Dth): A unit of energy equal to one million British thermal units

Mbbls/d: One thousand barrels per day

Mdth/d: One thousand dekatherms per day

MMcf/d: One million cubic feet per day

MMdth: One million dekatherms or approximately one trillion British thermal units

MMdth/d: One million dekatherms per day

Tbtu: One trillion British thermal units

Consolidated Entities:

ACMP: Access Midstream Partners, L.P. prior to its merger with Pre-Merger WPZ

Cardinal: Cardinal Gas Services, L.L.C.

Constitution: Constitution Pipeline Company, LLC

Gulfstar One: Gulfstar One LLC

Jackalope: Jackalope Gas Gathering Services, L.L.C.

Northwest Pipeline: Northwest Pipeline LLC

Pre-merger WPZ: Williams Partners L.P. prior to its merger with ACMP

Transco: Transcontinental Gas Pipe Line Company, LLC

WPZ: Williams Partners L.P.

Partially Owned Entities: Entities in which we do not own a 100 percent ownership interest and which, as of December 31, 2016, we account for as an equity-method investment, including principally the following:

Aux Sable: Aux Sable Liquid Products LP

Bluegrass: Bluegrass Pipeline Company LLC

Caiman II: Caiman Energy II, LLC

Discovery: Discovery Producer Services LLC

Gulfstream: Gulfstream Natural Gas System, L.L.C.

Laurel Mountain: Laurel Mountain Midstream, LLC

Moss Lake: Moss Lake Fractionation LLC and Moss Lake LPG Terminal LLC

OPPL: Overland Pass Pipeline Company LLC

UEOM: Utica East Ohio Midstream LLC

2

Government and Regulatory:

EPA: Environmental Protection Agency

Exchange Act, the: Securities and Exchange Act of 1934, as amended

FERC: Federal Energy Regulatory Commission

GAAP: Generally accepted accounting principles

IRS: Internal Revenue Service

SEC: Securities and Exchange Commission

Other:

DRIP: Distribution reinvestment program

Energy Transfer: Energy Transfer Equity, L.P.

ETC: Energy Transfer Corp LP

ETC Merger: Merger wherein Williams would have been merged into ETC

Fractionation: The process by which a mixed stream of natural gas liquids is separated into its constituent products,

such as ethane, propane, and butane

IDR: Incentive distribution right

LNG: Liquefied natural gas; natural gas which has been liquefied at cryogenic temperatures

Merger Agreement: Merger Agreement and Plan of Merger of Williams with Energy Transfer and certain of its

affiliates

MVC: Minimum volume commitment

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

PDH facility:Propane dehydrogenation facility

RGP Splitter:Refinery grade propylene splitter

Throughput:The volume of product transported or passing through a pipeline, plant, terminal, or other facility

3

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.”

WEBSITE ACCESS TO REPORTS AND OTHER INFORMATION

We file our annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, proxy statements and other documents electronically with the SEC under the Exchange Act. You may read and copy any materials that we file with the SEC at the SEC’s Public Reference Room at 100 F Street, N.E., Washington, DC 20549. You may obtain information on the operation of the Public Reference Room by calling the SEC at 1-800-SEC-0330. You may also obtain such reports from the SEC’s Internet website at www.sec.gov.

Our Internet website is www.williams.com. We make available, free of charge, through the Investor tab of our Internet website our annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Exchange Act as soon as reasonably practicable after we electronically file such material with, or furnish it to, the SEC. Our Corporate Governance Guidelines, Code of Ethics for Senior Officers, Board committee charters, and the Williams Code of Business Conduct are also available on our Internet website. We will also provide, free of charge, a copy of any of our corporate documents listed above upon written request to our Corporate Secretary, One Williams Center, Suite 4700, Tulsa, Oklahoma 74172.

GENERAL

We are primarily an energy infrastructure company focused on connecting North America’s significant hydrocarbon resource plays to markets for natural gas, NGLs, and olefins. Our operations are located principally in the United States.

As of December 31, 2016, our interstate gas pipelines, midstream, and olefins production interests were largely held through our significant investment in Williams Partners L.P. (WPZ). We owned the general partner interest and a 58 percent limited-partner interest in WPZ. See the Financial Repositioning discussion below for recent changes to our interest in WPZ.

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. Williams’ headquarters are located in Tulsa, Oklahoma, with other major offices in Salt Lake City, Utah; Houston, Texas; Oklahoma City, Oklahoma; Pittsburgh, Pennsylvania; and the Four Corners Area. Our telephone number is 918-573-2000.

FINANCIAL REPOSITIONING

In January 2017, we announced agreements with WPZ, wherein we permanently waived the general partner’s incentive distribution rights and converted our 2 percent general partner interest in WPZ to a non-economic interest in exchange for 289 million newly issued WPZ common units. Pursuant to this agreement, we also purchased approximately 277 thousand WPZ common units for $10 million. Additionally, we purchased approximately 59 million common units of WPZ at a price of $36.08586 per unit in a private placement transaction, funded with proceeds from our equity offering (see Note 15 - Stockholders’ Equity of Notes to Consolidated Financial Statements). Following these transactions, we own a 74 percent limited partner interest in WPZ. It is anticipated that the combination of these measures will improve WPZ’s cost of capital, provide for debt reduction, and eliminate WPZ’s need to access the public equity markets for several years.

In addition to the previously announced Geismar monetization process, we have announced plans to monetize other select assets that are not core to our strategy. We expect to raise more than $2 billion in after-tax proceeds from the monetization process of Geismar and the other select assets.

4

SALE OF OUR CANADIAN OPERATIONS

In September 2016, we completed the sale of our Canadian operations. Consideration received to date totaled $1.020 billion, net of $31 million of cash divested and subject to customary working capital adjustments. We recognized an impairment charge of $747 million during the second quarter of 2016 related to these operations and an additional loss of $66 million upon completion of the sale. (See Note 3 – Divestiture of Notes to Consolidated Financial Statements.)

ENERGY TRANSFER MERGER AGREEMENT

On September 28, 2015, we publicly announced in a press release that we had entered into a Merger Agreement with Energy Transfer and certain of its affiliates. The Merger Agreement provided that, subject to the satisfaction of customary closing conditions, we would merge with and into the newly formed ETC, with ETC surviving the ETC Merger.

On June 29, 2016, Energy Transfer provided us written notice terminating the Merger Agreement, citing the alleged failure of certain conditions under the Merger Agreement.

ORGANIZATIONAL REALIGNMENT

In September 2016, we announced organizational changes aiming to simplify our structure, increase direct operational alignment to advance our natural gas-focused strategy, and drive continued focus on customer service and execution. Effective January 1, 2017, we implemented these changes, which combined the management of certain of our operations and reduced the overall number of operating areas managed within our business.

Information in this report has generally been prepared to be consistent with the reportable segment presentation in our consolidated financial statements in Part II, Item 8 of this document. These segments are discussed in further detail in the following sections.

FINANCIAL INFORMATION ABOUT SEGMENTS

See “Item 8 — Financial Statements and Supplementary Data — Notes to Consolidated Financial Statements — Note 19 – Segment Disclosures.”

BUSINESS SEGMENTS

Substantially all our operations are conducted through our subsidiaries. Our activities in 2016 were operated through the following reporting segments as presented in the accompanying financial statements and management’s discussion and analysis.

• Williams Partners — comprised of our consolidated master limited partnership, WPZ, which includes gas pipeline and midstream businesses. The gas pipeline business includes interstate natural gas pipelines and pipeline joint project investments. The midstream business provides natural gas gathering, treating, processing and compression services; NGL production, fractionation, storage, marketing and transportation; deepwater production handling and crude oil transportation services; an olefin production business and is comprised of several wholly owned and partially owned subsidiaries and joint project investments.

Prior to September 2016, this reporting segment also included our Canadian midstream operations comprised of an oil sands offgas processing plant near Fort McMurray, Alberta, an NGL/olefin fractionation facility, and the Boreal Pipeline which were subsequently sold.

• Williams NGL & Petchem Services — comprised of our Texas Belle pipeline and certain other domestic olefins pipeline assets. Prior to September 2016, this reporting segment also included certain Canadian growth projects under development, including a propane dehydrogenation facility and a recently completed liquids extraction plant which were subsequently sold.

• Other — primarily comprised of corporate operations and our Canadian construction services company.

5

As previously discussed, in September 2016 we announced organizational changes aiming to simplify our structure, increase direct operational alignment to advance our natural gas-focused strategy, and drive continued focus on customer service and execution. Effective January 1, 2017, we implemented these changes, which combined the management of certain of our operations and reduced the overall number of operating areas managed within our business. As a result of this realignment and the sale of our Canadian operations, the Williams NGL & Petchem Services reporting segment will be eliminated and the remaining assets will be reported with Other.

Detailed discussion of each of our reporting segments follows. For a discussion of our ongoing expansion projects, see Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

Williams Partners

Gas Pipeline Business

Williams Partners' gas pipeline businesses consist primarily of Transco and Northwest Pipeline. Our gas pipeline business also holds interests in joint venture interstate and intrastate natural gas pipeline systems including a 50 percent equity-method investment in Gulfstream and a 41 percent interest in Constitution (a consolidated entity), which is under development. Transco and Northwest Pipeline own and operate a combined total of approximately 13,600 miles of pipelines with a total annual throughput of approximately 4,230 TBtu of natural gas and peak-day delivery capacity of approximately 15.5 MMdth of natural gas.

Transco

Transco is an interstate natural gas transmission company that owns and operates a 9,700-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.

Pipeline system and customers

At December 31, 2016, Transco’s system had a mainline delivery capacity of approximately 6.6 MMdth of natural gas per day from its production areas to its primary markets, including delivery capacity from the mainline to locations on its Mobile Bay Lateral. Using its Leidy Line along with market-area storage and transportation capacity, Transco can deliver an additional 5.1 MMdth of natural gas per day for a system-wide delivery capacity total of approximately 11.7 MMdth of natural gas per day. Transco’s system includes 47 compressor stations, four underground storage fields, and an LNG storage facility. Compression facilities at sea level-rated capacity total approximately 1.8 million horsepower.

Transco’s major natural gas transportation customers are public utilities and municipalities that provide service to residential, commercial, industrial and electric generation end users. Shippers on Transco’s system include public utilities, municipalities, direct industrial users, electric power generators, and natural gas marketers and producers. Transco’s firm transportation agreements are generally long-term agreements with various expiration dates and account for the major portion of Transco’s business. Additionally, Transco offers interruptible transportation services under shorter-term agreements.

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 200 Bcf of natural gas. At December 31, 2016, Transco’s customers had stored in its facilities approximately 151 Bcf of natural gas. In addition, wholly owned subsidiaries of Transco operate and hold a 35 percent equity-method investment in Pine Needle LNG Company, LLC, an LNG storage facility with 4 Bcf of storage capacity. Storage capacity permits Transco’s customers to inject gas into storage during the summer and off-peak periods for delivery during peak winter demand periods.

6

Northwest Pipeline

Northwest Pipeline is an interstate natural gas transmission company that owns and operates a 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.

Pipeline system and customers

At December 31, 2016, Northwest Pipeline’s system, having long-term firm transportation and storage redelivery agreements with aggregate capacity reservations of approximately 3.8 MMdth/d, was composed of approximately 3,900 miles of mainline and lateral transmission pipeline and 41 transmission compressor stations having a combined sea level-rated capacity of approximately 472,000 horsepower.

Northwest Pipeline transports and stores 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. Northwest Pipeline’s firm transportation and storage redelivery contracts are generally long-term contracts with various expiration dates and account for the major portion of Northwest Pipeline’s business. Additionally, Northwest Pipeline offers interruptible and short-term firm transportation service.

Northwest Pipeline owns a one-third interest in the Jackson Prairie underground storage facility in Washington and contracts with a third party for natural gas storage services in the Clay basin underground field in Utah. Northwest Pipeline also owns and operates an LNG storage facility in Washington. These storage facilities have an aggregate working natural gas storage capacity of 14.2 MMdth of natural gas, 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.

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. Williams Partners owns, through a subsidiary, a 50 percent equity-method investment in Gulfstream. Williams Partners shares operating responsibilities for Gulfstream with the other 50 percent owner.

Midstream Business

Williams Partners’ midstream business, one of the nation’s largest natural gas gatherers and processors, has primary service areas concentrated in major producing basins in Arkansas, Colorado, New Mexico, Oklahoma, Texas, Wyoming, the Gulf of Mexico, Louisiana, Pennsylvania, West Virginia, New York, and Ohio. The primary businesses are: (1) natural gas gathering, treating, and processing; (2) NGL fractionation, storage and transportation; (3) crude oil transportation; and (4) olefins production. These fall within the middle of the process of taking raw natural gas and crude oil from the producing fields to the consumer. We also own and operate gas gathering and processing assets and pipelines primarily within the onshore, offshore shelf, and deepwater areas in and around the Gulf Coast states of Texas, Louisiana, Mississippi, and Alabama.

Key variables for this business will continue to be:

• Producer drilling activities impacting natural gas supplies supporting our gathering and processing volumes;

• Prices impacting commodity-based activities;

• Retaining and attracting customers by continuing to provide reliable services;

• Revenue growth associated with additional infrastructure either completed or currently under construction;

7

• Disciplined growth in core service areas and new step-out areas.

Gathering, Processing, and Treating

Williams Partners’ gathering systems receive natural gas from producers’ 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. Williams Partners’ treating facilities remove water vapor, carbon dioxide, and other contaminants and collect condensate, but do not extract NGLs. Williams Partners’ is 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 in addition to removing water vapor, carbon dioxide, and other contaminants. NGL products include:

• Ethane, primarily used in the petrochemical industry as a feedstock for ethylene production, one of the basic building blocks for plastics;

• Propane, used for heating, fuel and as a petrochemical feedstock in the production of ethylene and propylene, another building block for petrochemical-based products such as carpets, packing materials, and molded plastic parts;

• Normal butane, isobutane and natural gasoline, primarily used by the refining industry as blending stocks for motor gasoline or as a petrochemical feedstock.

Our gas processing services generate revenues primarily from the following three 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. Our customers are entitled to the NGLs produced in connection with this type of processing agreement. A portion of our fee-based processing revenues includes a share of the margins on the NGLs produced. For the year ended December 31, 2016, 69 percent of the domestic NGL production volumes were under fee-based contracts.

• Keep-whole: Under keep-whole contracts, we (1) process natural gas produced by customers, (2) retain some or all of the extracted NGLs as compensation for our services, (3) replace the Btu content of the retained NGLs that were extracted during processing with natural gas purchases, also known as shrink replacement gas, and (4) deliver an equivalent Btu content of natural gas for customers at the plant outlet. NGLs we retain in connection with this type of processing agreement are referred to as our equity NGL production. Under these agreements, we have commodity price exposure on the difference between NGL and natural gas prices. For the year ended December 31, 2016, 26 percent of the domestic NGL production volumes were under keep-whole contracts.

• Percent-of-Liquids: Under percent-of-liquids processing contracts, we (1) process natural gas produced by customers, (2) deliver to customers an agreed-upon percentage of the extracted NGLs, (3) retain a portion of the extracted NGLs as compensation for our services, and (4) deliver natural gas to customers at the plant outlet. Under this type of contract, we are not required to replace the Btu content of the retained NGLs that were extracted during processing, and are therefore only exposed to NGL price movements. NGLs we retain in connection with this type of processing agreement are also referred to as our equity NGL production. For the year ended December 31, 2016, 5 percent of the domestic NGL production volumes were under percent-of-liquids contracts.

Our gathering and processing agreements have terms ranging from month-to-month to the life of the producing lease. Generally, our gathering and processing agreements are long-term agreements. Some contracts have price escalators which annually increase our gathering rates. In addition, certain contracts include fee redetermination or cost of service mechanisms that are designed to support a return on invested capital and allow our gathering rates to be

8

adjusted, subject to specified caps in certain cases, to account for variability in volume, capital expenditures, commodity price fluctuations, compression and other expenses. Certain of our gas gathering agreements include MVCs. If the minimum annual or semi-annual volume commitment is not met, these customers are obligated to pay a fee equal to the applicable fee for each Mcf by which the applicable customer’s minimum annual or semi-annual volume commitment exceeds the actual volume gathered. The revenue associated with such shortfall fees is generally recognized in the fourth quarter of each year.

Demand for gas gathering and processing services is dependent on producers’ drilling activities, which is impacted by the strength of the economy, natural gas prices, and the resulting demand for natural gas by manufacturing and industrial companies and consumers. Williams Partners’ gas gathering and processing customers are generally natural gas producers who have proved and/or producing natural gas fields in the areas surrounding its infrastructure. During 2016, Williams Partners’ facilities gathered and processed gas for approximately 200 customers. Williams Partners’ top eight gathering and processing customers accounted for approximately 78 percent of our gathering and processing fee revenues and NGL margins from our keep-whole and percent-of-liquids agreements.

Demand for our equity NGLs is affected by economic conditions and the resulting demand from industries using these commodities to produce petrochemical-based products such as plastics, carpets, packing materials and blending stocks for motor gasoline and the demand from consumers using these commodities for heating and fuel. NGL products are currently the preferred feedstock for ethylene and propylene production, which has shifted away from the more expensive crude-based feedstocks.

Geographically, the midstream natural gas assets are positioned to maximize commercial and operational synergies with our other assets. For example, most of the offshore gathering and processing assets attach and process or condition natural gas supplies delivered to the Transco pipeline. Our San Juan basin, southwest Wyoming, and Piceance systems are capable of delivering residue gas volumes into Northwest Pipeline’s interstate system in addition to third-party interstate systems. Our gathering systems in Pennsylvania delivers residue gas volumes into Transco’s pipeline in addition to third-party interstate systems.

9

The following table summarizes our significant consolidated natural gas gathering assets:

	Natural Gas Gathering Assets
	Location	Pipeline Miles	Inlet Capacity (Bcf/d)	Ownership Interest	Supply Basins/Shale Formations
Northeast
Ohio Valley	West Virginia & Pennsylvania	210	0.8	100%	Appalachian
Susquehanna Supply Hub	Pennsylvania & New York	399	2.9	100%	Appalachian
Cardinal (1)	Ohio	352	1.0	66%	Appalachian
Flint	Ohio	33	0.2	100%	Appalachian
Marcellus South (2)	West Virginia & Pennsylvania	41	0.1	100%	Appalachian
Atlantic-Gulf
Canyon Chief, including Blind Faith and Gulfstar extensions	Deepwater Gulf of Mexico	156	0.5	100%	Eastern Gulf of Mexico
Other Eastern Gulf	Offshore shelf and other	46	0.2	100%	Eastern Gulf of Mexico
Seahawk	Deepwater Gulf of Mexico	115	0.4	100%	Western Gulf of Mexico
Perdido Norte	Deepwater Gulf of Mexico	105	0.3	100%	Western Gulf of Mexico
Other Western Gulf	Offshore shelf and other	120	0.9	100%	Western Gulf of Mexico
West
Four Corners	Colorado & New Mexico	3,743	1.8	100%	San Juan
Wamsutter	Wyoming	1,973	0.6	100%	Wamsutter
Southwest Wyoming	Wyoming	1,614	0.5	100%	Southwest Wyoming
Piceance	Colorado	336	1.5	(3)	Piceance
Niobrara	Wyoming	184	0.2	(4)	Powder River
Barnett Shale	Texas	858	0.9	100%	Barnett Shale
Eagle Ford Shale	Texas	1,010	0.7	100%	Eagle Ford Shale
Haynesville Shale	Louisiana	598	1.7	100%	Haynesville Shale
Permian	Texas	346	0.1	100%	Permian
Mid-Continent	Oklahoma & Kansas	2,112	0.9	100%	Miss-Lime, Granite Wash, Colony Wash

__________

(1) Statistics reflect 100 percent of the assets from our 66 percent ownership of Cardinal gathering system.

(2) Statistics reflect 100 percent of the Beaver Creek assets from our 67 percent ownership in the Marcellus South gathering system.

(3) Includes our 60 percent ownership of a gathering system in the Ryan Gulch area with 140 miles of pipeline and 0.2 Bcf/d of inlet capacity, and our 67 percent ownership of a gathering system at Allen Point with 8 miles of pipeline and 0.1 Bcf/d of inlet capacity. We operate both systems. We own and operate 100 percent of the balance of the Piceance gathering assets.

(4) Includes our 50 percent ownership of the Jackalope gathering system.

10

The following table summarizes our significant consolidated natural gas processing facilities:

	Natural Gas Processing Facilities
	Location	Inlet Capacity (Bcf/d)	NGL Production Capacity (Mbbls/d)	Ownership Interest	Supply Basins
Northeast
Fort Beeler	Marshall County, WV	0.5	62	100%	Appalachian
Oak Grove	Marshall County, WV	0.2	25	100%	Appalachian
Atlantic-Gulf
Markham	Markham, TX	0.5	45	100%	Western Gulf of Mexico
Mobile Bay	Coden, AL	0.7	30	100%	Eastern Gulf of Mexico
West
Echo Springs	Echo Springs, WY	0.7	58	100%	Wamsutter
Opal	Opal, WY	1.1	47	100%	Southwest Wyoming
Bucking Horse (1)	Converse County, WY	0.1	7	50%	Powder River
Willow Creek	Rio Blanco County, CO	0.5	30	100%	Piceance
Parachute	Garfield County, CO	1.1	6	100%	Piceance
Ignacio	Ignacio, CO	0.5	29	100%	San Juan
Kutz	Bloomfield, NM	0.2	12	100%	San Juan

__________

(1) Statistics reflect 100 percent of the assets from our 50 percent ownership of Bucking Horse gas processing facility.

In addition, we own and operate several natural gas treating facilities in New Mexico, Colorado, Texas, and Louisiana which bring natural gas to specifications allowable by major interstate pipelines.

We also own and operate fractionation facilities at Moundsville, de-ethanization and condensate facilities at our Oak Grove processing plant, another condensate stabilization facility near our Oak Grove plant, and an ethane transportation pipeline.  Our two condensate stabilizers are capable of handling 17 Mbbls/d of field condensate.  NGLs are extracted from the natural gas stream in our cryogenic processing plants. 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.  The remaining mixed NGL stream from the de-ethanizer is then transported and fractionated at our Moundsville facilities, which are capable of handling more than 42 Mbbls/d of mixed NGLs.  Ethane produced at our de-ethanizer is transported to markets via our 50-mile ethane pipeline from Oak Grove to Houston, Pennsylvania.

Our gathering business in the Northeast also provides multiple takeaway options to its customers. Ohio Valley Midstream makes customer deliveries with interconnections to two pipelines. Susquehanna Supply Hub makes deliveries for its customers with interconnections to Transco, as well as five other pipelines, while our Cardinal system utilizes interconnections with Blue Racer and UEOM. In addition, our NGL processing business utilizes connections with multiple pipelines, as well as truck and rail transportation to local and regional markets.

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 crude oil transportation revenues are typically volumetric-based fee arrangements. However, a portion of our marketing revenues are recognized from purchase and sale arrangements whereby the oil that we transport is purchased and sold as a function of the same index-based price. Our offshore floating production platforms provide centralized services to deepwater producers such as compression, separation, production handling, water removal, and pipeline landings. Revenue sources have historically included a combination of fixed-fee, volumetric-based fee and cost reimbursement arrangements. Fixed fees associated with the resident production at our Devils Tower facility are recognized on a units-of-production basis. Fixed fees associated with the resident production at our Gulfstar One facility are recognized as the guaranteed capacity is made available. 

11

The following tables summarize our significant crude oil transportation pipelines and production handling platforms:

	Crude Oil Pipelines
	Pipeline Miles	Capacity (Mbbls/d)	Ownership Interest	Supply Basins
Mountaineer, including Blind Faith and Gulfstar extensions	172	150	100%	Eastern Gulf of Mexico
BANJO	57	90	100%	Western Gulf of Mexico
Alpine	96	85	100%	Western Gulf of Mexico
Perdido Norte	74	150	100%	Western Gulf of Mexico

	Production Handling Platforms
	Gas Inlet Capacity (MMcf/d)	Crude/NGL Handling Capacity (Mbbls/d)	Ownership Interest	Supply Basins
Devils Tower	210	60	100%	Eastern Gulf of Mexico
Gulfstar I FPS (1)	172	80	51%	Eastern Gulf of Mexico

__________

(1) Statistics reflect 100 percent of the assets from our 51 percent interest in Gulfstar One.

Canadian Operations

Williams Partners completed the sale of its Canadian operations in September 2016. This business included an oil sands offgas processing plant located near Fort McMurray, Alberta, and an NGL/olefin fractionation facility located at Redwater, Alberta, which is near Edmonton, Alberta, and the Boreal Pipeline which transported NGLs and associated olefins from the Fort McMurray plant to the Redwater fractionation facility. This business allowed us to extract, fractionate, treat, store, terminal and sell the ethane/ethylene, propane, propylene, normal butane (butane), iso-butane, alky feedstock, and condensate recovered from a third-party oil sands bitumen upgrader. The commodity price exposure of this asset was the spread between the price for natural gas and the NGL and olefin products we produce. These products were sold within Canada and the United States.

Operating statistics

The following table summarizes our significant operating statistics:

	2016	2015	2014
Volumes:
Canadian propylene sales (millions of pounds)	87	161	143
Canadian NGL sales (millions of gallons)	141	284	218

Gulf Olefins

We have an 88.5 percent undivided interest and operatorship of an olefins production facility in Geismar, Louisiana, along with a refinery grade propylene splitter and pipelines in the Gulf region. Our olefins business also operates an ethylene storage hub at Mont Belvieu using leased third-party underground storage caverns.

In 2015, we placed in service an expansion of the olefins production facility that increased its ethylene production capacity by 600 million pounds per year, for a total production capacity of 1.95 billion pounds of ethylene and 114 million pounds of propylene per year. Our feedstocks for the cracker are ethane and propane; as a result, these assets are primarily exposed to the price spread between ethane and propane, and ethylene and propylene, respectively. Ethane and propane are available for purchase from third parties and from affiliates. Following an explosion and fire that occurred in 2013, the Geismar plant resumed consistent operations in late March 2015 and reached full production capacity in the third quarter of 2015.

12

Our refinery grade propylene splitter has a production capacity of approximately 500 million pounds per year of propylene. At our propylene splitter, we purchase refinery grade propylene and fractionate it into polymer grade propylene and propane; as a result, this asset is exposed to the price spread between those commodities.

We own 283 miles of pipeline systems in Louisiana and Texas that provide feedstock transportation to the Geismar olefins plant, the RPG Splitter, and other third-party crackers. These systems include the Bayou ethane pipeline, which provides ethane transportation from fractionation and storage facilities in Mont Belvieu, Texas, to the Geismar olefins plant in south Louisiana and serves customers along the way; as well as the Geismar ethane and propane systems in Louisiana, which provide feedstock transportation to the Geismar olefins plant and other customers. We also own a pipeline that has the capacity to supply 12 Mbbls/d of ethane from Discovery’s Paradis fractionator to the Geismar olefins plant.

As a merchant producer of ethylene and propylene, our product sales are to customers for use in making plastics and other downstream petrochemical products destined for both domestic and export markets. We are currently seeking to monetize our ownership interest in the Geismar, Louisiana, olefins plant and complex (see Overview within Management’s Discussion and Analysis of Financial Condition and Results of Operations).

Marketing Services

We market NGL products to a wide range of users in the energy and petrochemical industries. The NGL marketing business transports and markets our equity NGLs from the production at our processing plants, and also markets NGLs on behalf of third-party NGL producers, including some of our fee-based processing customers, and the NGL volumes owned by 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. Other than a long-term agreement to sell our equity NGLs transported on OPPL, the majority of sales are based on supply contracts of one year or less in duration.

In certain situations to facilitate our gas gathering and processing activities, we buy natural gas from our producer customers for resale.

We also market olefin products to a wide range of users in the energy and petrochemical industries. In order to meet sales contract obligations, we may purchase olefin products for resale.

Other NGL & Petchem Operations

We own interests in and/or operate NGL fractionation and storage assets in central Kansas near Conway. These assets include a 50 percent interest in an NGL fractionation facility with capacity of slightly more than 100 Mbbls/d and we own approximately 20 million barrels of NGL storage capacity.

We own 114 miles of pipelines in the Houston Ship Channel area which transport a variety of products including ethane, propane, ammonia, tertiary butyl alcohol, and other industrial products used in the petrochemical industry. We also own a tunnel crossing pipeline under the Houston Ship Channel.  A portion of these pipelines are leased to third parties.

WPZ Operating Areas

Effective January 1, 2017, WPZ organizes these businesses into the following operating areas:

Northeast G&P is comprised of natural gas gathering and processing, compression, and NGL fractionation businesses in the Marcellus Shale region primarily in Pennsylvania, New York, and West Virginia and the Utica Shale region of eastern Ohio, as well as a 66 percent interest in Cardinal (a consolidated entity), a 62 percent equity-method investment in UEOM, a 69 percent equity-method investment in Laurel Mountain, a 58 percent equity-method investment in Caiman II, and Appalachia Midstream Services, LLC, which owns an approximate average 41 percent equity-method investment in multiple gas gathering systems in the Marcellus Shale (Appalachia Midstream Investments).

13

Atlantic-Gulf is comprised of an interstate natural gas pipeline, Transco, and significant 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 entity) which is a proprietary floating production system, and various petrochemical and feedstock pipelines in the Gulf Coast region, as well as a 50 percent equity-method investment in Gulfstream, a 41 percent interest in Constitution (a consolidated entity) which is under development, and a 60 percent equity-method investment in Discovery.

West is comprised of an interstate natural gas pipeline, Northwest Pipeline, and natural gas gathering, processing, and treating operations in New Mexico, Colorado, and Wyoming, as well as 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, Arkoma, Delaware, and Permian basins. West also includes an NGL and natural gas marketing business, storage facilities, and an undivided 50 percent interest in an NGL fractionator near Conway, Kansas, as well as a 50 percent equity-method investment in the Delaware basin gas gathering system in the Permian basin, and a 50 percent equity-method investment in OPPL.

NGL & Petchem Services is comprised of our 88.5 percent undivided interest in an olefins production facility in Geismar, Louisiana, along with a refinery grade propylene splitter. Prior to September 2016, this operating area also included an oil sands offgas processing plant near Fort McMurray, Alberta, and an NGL/olefin fractionation facility which were subsequently sold.

Certain Equity-Method Investments

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 614-mile offshore natural gas gathering and transportation system in the Gulf of Mexico with an inlet capacity of 1,350 MMcf/d, including the Keathley Canyon Connector, a 209-mile deepwater lateral pipeline in the central deepwater Gulf of Mexico that contributes 400 MMcf/d of inlet capacity. Discovery’s assets also include a crude oil production handling platform with a crude oil/NGL handling capacity of 10 Mbbls/d and natural gas processing capacity of 75 MMcf/d.

Laurel Mountain

We own a 69 percent interest in a joint venture, Laurel Mountain, that includes a 2,053-mile gathering system that we operate in western Pennsylvania with the capacity to gather 0.7 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.

Caiman II

We own a 58 percent interest in Caiman II, which owns a 50 percent interest in Blue Racer, a joint project 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 688 miles of natural gas gathering pipelines, including 422 miles of large-diameter pipelines, and the Natrium complex in Marshall County, West Virginia, with a cryogenic processing capacity of 400 MMcf/d and fractionation capacity of approximately 123,000 Bbls/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.

Utica East Ohio Midstream

We own a 62 percent interest in UEOM, a joint project to develop infrastructure for the gathering, processing and fractionation of natural gas and NGLs in the Utica Shale play in eastern Ohio. We, along with other equity owners, operate the infrastructure complex which consists of natural gas gathering and compression facilities, four processing plants with a total capacity of 800 MMcf/d, 41 Mbbls/d of condensate stabilization capacity, a 135 Mbbls/d NGL fractionation facility, approximately 950,000 barrels of NGL storage capacity and other ancillary assets, including

14

loading and terminal facilities that are operated by our partner. These assets earn a fixed fee that escalates annually within a specified range.

Aux Sable

We own a 14.6 percent interest in Aux Sable and its Channahon, Illinois, gas processing and NGL fractionation facility near Chicago. The facility is capable of processing up to 2.1 Bcf/d of natural gas from the Alliance Pipeline system and fractionating approximately 107 Mbbls/d of extracted liquids into NGL products. Additionally, Aux Sable owns an 80 MMcf/d gas conditioning plant and a 12-inch, 83-mile gas pipeline infrastructure in North Dakota that provides additional NGLs to Channahon from the Bakken Shale in the Williston basin.

Appalachia Midstream Investments

Through our Appalachia Midstream Investments, we operate 100 percent of and own an approximate average 41 percent interest in multiple natural gas gathering systems that consist of approximately 979 miles of gathering pipeline in the Marcellus Shale region. The majority of our volumes in the region are gathered from northern Pennsylvania, southwestern Pennsylvania and the northwestern panhandle of West Virginia in core areas of the Marcellus Shale. Appalachia Midstream Investments operates the assets under long-term, 100 percent fixed-fee gathering agreements that include significant acreage dedications and cost of service mechanisms.

Delaware basin gas gathering system

We own a non-operated 50 percent interest in the Delaware basin gas gathering system (DBJV) in the Permian basin. The system is comprised of more than 450 miles of gathering pipeline, located in west Texas.

Acquisition of Additional Interests in Appalachia Midstream Investments

In February 2017, we announced agreements to acquire additional interests in two Marcellus Shale gathering systems within Appalachia Midstream Investments in exchange for equity-method investment interests in DBJV and the Ranch Westex gas processing plant.  We also expect to receive a total of $200 million in cash as part of the agreements, subject to customary closing conditions and purchase price adjustments.  The transactions are expected to close in late first-quarter or early second-quarter 2017.

Overland Pass Pipeline

We operate and own a 50 percent interest in OPPL. OPPL is capable of transporting 255 Mbbls/d and includes approximately 1,096 miles of NGL pipeline extending from Opal, Wyoming, to the Mid-Continent NGL market center near Conway, Kansas, along with extensions into the Piceance and Denver-Julesberg basins in Colorado and the Bakken Shale in the Williston basin in North Dakota. Our equity NGL volumes from two of our three Wyoming plants and our Willow Creek facility in Colorado are dedicated for transport on OPPL under a long-term transportation agreement.

Operating Statistics

The following table summarizes our significant operating statistics for Williams Partners’ domestic midstream business:

	2016	2015	2014
Volumes: (1)
Gathering (Bcf/d)	8.25	8.34	8.90
Plant inlet natural gas (Bcf/d)	3.50	3.52	3.82
NGL production (Mbbls/d) (2)	151	131	128
NGL equity sales (Mbbls/d) (2)	46	31	27
Crude oil transportation (Mbbls/d) (2)	113	126	105
Geismar ethylene sales (millions of pounds)	1,638	1,066	—

__________

(1) Excludes volumes associated with equity-method investments.

(2) Annual average Mbbls/d.

15

Williams NGL & Petchem Services

The Williams NGL & Petchem Services segment is comprised of our Texas Belle pipeline and certain other domestic olefins pipeline assets. Prior to its sale in September 2016, this reporting segment also included the Horizon liquids extraction plant which was placed in service in March 2016 and a propane dehydrogenation facility which was under development. As this segment is currently comprised primarily of projects under development, reported revenues to-date are nominal. Effective January 1, 2017, these assets will be reported in Other.

Additional Business Segment Information

Our ongoing business segments are presented as continuing operations in the accompanying financial statements and Notes to Consolidated Financial Statements included in Part II.

We perform certain management, legal, financial, tax, consultation, information technology, administrative and other services for our subsidiaries.

Our principal sources of cash are from dividends, distributions, and advances from our subsidiaries, investments, payments by subsidiaries for services rendered, and, if needed, external financings, and net proceeds from asset sales. The terms of certain subsidiaries’ borrowing arrangements may limit the transfer of funds to us under certain conditions.

We believe that we have adequate sources and availability of raw materials and commodities for existing and anticipated business needs. Our interstate pipeline systems are all regulated in various ways resulting in the financial return on the investments made in the systems being limited to standards permitted by the regulatory agencies. Each of the pipeline systems has ongoing capital requirements for efficiency and mandatory improvements, with expansion opportunities also necessitating periodic capital outlays.

Revenues by service within our Williams Partners segment that exceeded 10 percent of consolidated revenue include:

	Total
	(Millions)
2016
Service:
Regulated natural gas transportation and storage	$	2,001
Gathering, processing, and production handling	2,729
2015
Service:
Regulated natural gas transportation and storage	$	1,938
Gathering, processing, and production handling	2,804
2014
Service:
Regulated natural gas transportation and storage	$	1,781
Gathering, processing and production handling	1,838

We have one customer, Chesapeake Energy Corporation, and its affiliates, that accounts for 14 percent of our total revenue in 2016. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk of Notes to Consolidated Financial Statements for additional details.)

REGULATORY MATTERS

FERC

Our gas pipeline interstate transmission and storage activities are subject to FERC regulation under the Natural Gas Act of 1938 (NGA) and under the Natural Gas Policy Act of 1978, and, as such, our rates and charges for the transportation of natural gas in interstate commerce, accounting, and the extension, enlargement, or abandonment of

16

our jurisdictional facilities, among other things, are subject to regulation. Each gas pipeline company holds certificates of public convenience and necessity issued by the FERC authorizing ownership and operation of all pipelines, facilities, and properties for which certificates are required under the NGA. FERC Standards of Conduct govern how our interstate pipelines communicate and do business with gas marketing employees. Among other things, the Standards of Conduct require that interstate pipelines not operate their systems to preferentially benefit gas marketing functions.

FERC regulation requires all terms and conditions of service, including the rates charged, to be filed with and approved by the FERC before any changes can go into effect. Each of our interstate natural gas pipeline companies establishes its rates primarily through the FERC’s ratemaking process. Key determinants in the ratemaking process are:

• Costs of providing service, including depreciation expense;

• Allowed rate of return, including the equity component of the capital structure and related income taxes;

• Contract and volume throughput assumptions.

The allowed rate of return is determined in each rate case. Rate design and the allocation of costs between the reservation and commodity rates also impact profitability. As a result of these proceedings, certain revenues previously collected may be subject to refund.

We also own interests in and operate two offshore transmission pipelines that are regulated by the FERC because they are deemed to transport gas in interstate commerce. Black Marlin Pipeline Company provides transportation service for offshore Texas production in the High Island area and redelivers that gas to intrastate pipeline interconnects near Texas City. Discovery provides transportation service for offshore Louisiana production from the South Timbalier, Grand Isle, Ewing Bank, and Green Canyon (deepwater) areas to an onshore processing facility and downstream interconnect points with major interstate pipelines. In addition, Williams Partners owns a 50 percent equity-method investment in and is the operator of OPPL, which is an interstate natural gas liquids pipeline regulated by the FERC pursuant to the Interstate Commerce Act. OPPL provides transportation service pursuant to tariffs filed with the FERC.

Pipeline Safety

Our gas pipelines are subject to the Natural Gas Pipeline Safety Act of 1968, as amended, the Pipeline Safety Improvement Act of 2002, the Pipeline Safety, Regulatory Certainty, and Jobs Creation Act of 2011 (Pipeline Safety Act), and the Protecting Our Infrastructure of Pipelines and Enhancing Safety Act of 2016, which regulate safety requirements in the design, construction, operation, and maintenance of interstate natural gas transmission facilities. The United States Department of Transportation Pipeline and Hazardous Materials Safety Administration (PHMSA) administers federal pipeline safety laws.

Federal pipeline safety laws authorize PHMSA to establish minimum safety standards for pipeline facilities and persons engaged in the transportation of gas or hazardous liquids by pipeline. These safety standards apply to the design, construction, testing, operation, and maintenance of gas and hazardous liquids pipeline facilities affecting interstate or foreign commerce. PHMSA has also established reporting requirements for operators of gas and hazardous liquid pipeline facilities, as well as provisions for establishing the qualification of pipeline personnel and requirements for managing the integrity of gas transmission and distribution lines and certain hazardous liquid pipelines. To ensure compliance with these provisions, PHMSA performs pipeline safety inspections and has the authority to initiate enforcement actions.

Federal pipeline safety regulations contain an exemption that applies to gathering lines in certain rural locations. A substantial portion of our gathering lines qualify for that exemption and are currently not regulated under federal law. However, PHMSA is completing a congressionally-mandated review of the adequacy of the existing federal and state regulations for gathering lines and has indicated that it may apply additional safety standards to rural gas gathering lines in the future.

States are largely preempted by federal law from regulating pipeline safety for interstate pipelines but most are certified by PHMSA to assume responsibility for enforcing intrastate pipeline safety regulations and inspecting intrastate

17

pipelines. In practice, because states can adopt stricter standards for intrastate pipelines than those imposed by the federal government for interstate lines, they vary considerably in their authority and capacity to address pipeline safety.

On January 3, 2012, the Pipeline Safety Act was enacted. The Pipeline Safety Act requires PHMSA to complete a number of reports in preparation for potential rulemakings. The issues addressed in these rulemaking provisions include, but are not limited to, the use of automatic or remotely controlled shut-off valves on new or replaced transmission line facilities, modifying the requirements for pipeline leak detection systems, and expanding the scope of the pipeline integrity management requirements for both gas and liquid pipeline systems. On June 22, 2016, the Protecting Our Infrastructure of Pipelines and Enhancing Safety Act of 2016 was enacted, further strengthening PHMSA’s safety authority.

Pipeline Integrity Regulations

We have developed an enterprise-wide Gas Integrity Management Plan that we believe meets the PHMSA final rule that was issued pursuant to the requirements of the Pipeline Safety Improvement Act of 2002. The rule requires gas pipeline operators to develop an integrity management program for gas transmission pipelines that could affect high-consequence areas in the event of pipeline failure. The integrity management program includes a baseline assessment plan along with periodic reassessments to be completed within required time frames. In meeting the integrity regulations, we have identified high-consequence areas and developed baseline assessment plans. Ongoing periodic reassessments and initial assessments of any new high-consequence areas have been completed. We estimate that the cost to be incurred in 2017 associated with this program to be approximately $57 million. Management considers the costs associated with compliance with the rule to be prudent costs incurred in the ordinary course of business and, therefore, recoverable through Northwest Pipeline’s and Transco’s rates.

We developed a Liquid Integrity Management Plan that we believe meets the PHMSA final rule that was issued pursuant to the requirements of the Pipeline Safety Improvement Act of 2002. The rule requires liquid pipeline operators to develop an integrity management program for liquid transmission pipelines that could affect high-consequence areas in the event of pipeline failure. The integrity management program includes a baseline assessment plan along with periodic reassessments expected to be completed within required time frames. In meeting the integrity regulations, we utilized government defined high-consequence areas and developed baseline assessment plans. We completed assessments within the required time frames. We estimate that the cost to be incurred in 2017 associated with this program will be approximately $7 million. Ongoing periodic reassessments and initial assessments of any new high-consequence areas are expected to be completed within the time frames required by the rule. Management considers the costs associated with compliance with the rule to be prudent costs incurred in the ordinary course of business.

State Gathering Regulation

Our onshore midstream gathering operations are subject to laws and regulations in the various states in which we operate. For example, the Texas Railroad Commission has the authority to regulate the terms of service for our intrastate natural gas gathering business in Texas. Although the applicable state regulations vary widely, they generally require that pipeline rates and practices be reasonable and nondiscriminatory, and may include provisions covering marketing, pricing, pollution, environment, and human health and safety. Some states, such as New York, have specific regulations pertaining to the design, construction, and operations of gathering lines within such state.

OCSLA

Our offshore midstream gathering is subject to the Outer Continental Shelf Lands Act (OCSLA). Although offshore gathering facilities are not subject to the NGA, offshore transmission pipelines are subject to the NGA, and in recent years the FERC has taken a broad view of offshore transmission, finding many shallow-water pipelines to be jurisdictional transmission. Most offshore gathering facilities are subject to the OCSLA, which provides in part that outer continental shelf pipelines “must provide open and nondiscriminatory access to both owner and nonowner shippers.”

18

Olefins

Our olefins assets are regulated by the Louisiana Department of Environmental Quality, the Texas Railroad Commission, and various other state and federal entities regarding our liquids pipelines.

These olefins assets are also subject to the liquid pipeline safety and integrity regulations previously discussed above since both Louisiana and Texas have adopted the integrity management regulations defined by PHMSA.

See Note 18 – Contingent Liabilities and Commitments of Notes to Consolidated Financial Statements for further details on our regulatory matters. For additional information regarding regulatory matters, please also refer to “Risk Factors — The operation of our businesses might also be adversely affected by regulatory proceedings, changes in government regulations or in their interpretation or implementation, or the introduction of new laws or regulations applicable to our businesses or our customers,” and “The natural gas sales, transportation, and storage operations of our gas pipelines are subject to regulation by the FERC, which could have an adverse impact on their ability to establish transportation and storage rates that would allow them to recover the full cost of operating their respective pipelines, including a reasonable rate of return."

ENVIRONMENTAL MATTERS

Our operations are subject to federal environmental laws and regulations as well as the state, local, and tribal laws and regulations adopted by the jurisdictions in which we operate. We could incur liability to governments or third parties for any unlawful discharge of pollutants into the air, soil, or water, as well as liability for cleanup costs. Materials could be released into the environment in several ways including, but not limited to:

• Leakage from gathering systems, underground gas storage caverns, pipelines, processing or treating facilities, transportation facilities, and storage tanks;

• Damage to facilities resulting from accidents during normal operations;

• Damages to onshore and offshore equipment and facilities resulting from storm events or natural disasters;

• Blowouts, cratering, and explosions.

In addition, we may be liable for environmental damage caused by former owners or operators of our properties.

We believe compliance with current environmental laws and regulations will not have a material adverse effect on our capital expenditures, earnings, or current competitive position. However, environmental laws and regulations could affect our business in various ways from time to time, including incurring capital and maintenance expenditures, fines and penalties, and creating the need to seek relief from the FERC for rate increases to recover the costs of certain capital expenditures and operation and maintenance expenses.

For additional information regarding the potential impact of federal, state, tribal, or local regulatory measures on our business and specific environmental issues, please refer to “Risk Factors — “Our operations are subject to environmental laws and regulations, including laws and regulations relating to climate change and greenhouse gas emissions, which may expose us to significant costs, liabilities, and expenditures that could exceed current expectations,” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Environmental” and “Environmental Matters” in Note 18 – Contingent Liabilities and Commitments of Notes to Consolidated Financial Statements.

COMPETITION

Gas Pipeline Business

The market for supplying natural gas is highly competitive and new pipelines, storage facilities, and other related services are expanding to service the growing demand for natural gas. Additionally, pipeline capacity in many growing natural gas supply basins is constrained causing competition to increase among pipeline companies as they strive to connect those basins to major natural gas demand centers.

19

In our business, we compete with major intrastate and interstate natural gas pipelines. In the last few years, local distribution companies have also started entering into the long haul transportation business through joint venture pipelines. The principle elements of competition in the interstate natural gas pipeline business are based on rates, reliability, quality of customer service, diversity of supply, and proximity to customers and market hubs.

Significant entrance barriers to build new pipelines exist, including federal and growing state regulations and public opposition against new pipeline builds, and these factors will continue to impact potential competition for the foreseeable future. However, we believe the position of our existing infrastructure, established strategic long-term contracts, and the fact that our pipelines have numerous receipt and delivery points along our systems provide us a competitive advantage, especially along the eastern seaboard and northwestern United States.

Midstream Business

Competition for natural gas gathering, processing, treating, transporting, and storing natural gas continues to increase as production from shales and other resource areas continues to grow. Our midstream services compete with similar facilities that are in the same proximity as our assets.

We face competition from major and independent natural gas midstream providers, private equity firms, and major integrated oil and natural gas companies that gather, transport, process, fractionate, store, and market natural gas and NGLs, as well as some larger exploration and production companies that are choosing to develop midstream services to handle their own natural gas.

Our gathering and processing agreements are generally long-term agreements that may include acreage dedication. We primarily face competition to the extent these agreements approach renewal and new volume opportunities arise. Competition for natural gas volumes is primarily based on reputation, commercial terms (products retained or fees charged), array of services provided, efficiency and reliability of services, location of gathering facilities, available capacity, downstream interconnects, and latent capacity. We believe our significant presence in traditional prolific supply basins, our solid positions in growing shale plays, and our ability to offer integrated packages of services position us well against our competition.

Our olefins business (primarily ethylene and propylene production), competes in a worldwide market place. However, the majority of North American olefins producers have significant downstream petrochemical manufacturing for plastics and other petrochemical products. We participate as a merchant seller of olefins with no downstream petrochemical manufacturing; therefore, at any time we can be either a supplier or a competitor to these companies. We compete on the basis of service, price, and availability of products that we produce.

For additional information regarding competition for our services or otherwise affecting our business, please refer to “Risk Factors - The financial condition of our natural gas transportation and midstream businesses is dependent on the continued availability of natural gas supplies in the supply basins that we access, and demand for those supplies in the markets we serve,” “Our industry is highly competitive and increased competitive pressure could adversely affect our business and operating results,” and “We may not be able to replace, extend, or add additional customer contracts or contracted volumes on favorable terms, or at all, which could affect our financial condition, the amount of cash available to pay dividends, and our ability to grow.” 

EMPLOYEES

At February 1, 2017, we had approximately 5,604 full-time employees.

FINANCIAL INFORMATION ABOUT GEOGRAPHIC AREAS

See Note 19 – Segment Disclosures of Notes to Consolidated Financial Statements for amounts of revenues during the last three fiscal years from external customers attributable to the United States and all foreign countries. Also see Note 19 – Segment Disclosures of Notes to Consolidated Financial Statements for information relating to long-lived assets during the last three fiscal years, located in the United States and all foreign countries.

20

Item 1A. Risk Factors

FORWARD-LOOKING STATEMENTS AND CAUTIONARY STATEMENT

FOR PURPOSES OF THE “SAFE HARBOR” PROVISIONS OF

THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995

The reports, filings and other public announcements of The Williams Companies, Inc. (Williams) may contain or incorporate by reference statements that do not directly or exclusively relate to historical facts. Such statements are “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (Securities Act), and Section 21E of the Securities Exchange Act of 1934, as amended (Exchange Act). These forward-looking statements relate to anticipated financial performance, management’s plans and objectives for future operations, business prospects, outcome of regulatory proceedings, market conditions and other matters. We make these forward-looking statements in reliance on the safe harbor protections provided under the Private Securities Litigation Reform Act of 1995.

All statements, other than statements of historical fact, included in this report that address activities, events or developments that we expect, believe or anticipate will exist or may occur in the future, are forward-looking statements. Forward-looking statements can 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. These forward-looking statements are based on management’s beliefs and assumptions and on information currently available to management and include, among others, statements regarding:

• Levels of cash distributions by Williams Partners L.P. (WPZ) with respect to limited partner interests;

• Levels of dividends to Williams stockholders;

• Future credit ratings of Williams, WPZ, and their affiliates;

• Amounts and nature of future capital expenditures;

• Expansion and growth of our business and operations;

• Financial condition and liquidity;

• Business strategy;

• Cash flow from operations or results of operations;

• Seasonality of certain business components;

• Natural gas, natural gas liquids, and olefins prices, supply, and demand;

• Demand for our services.

Forward-looking statements are based on numerous assumptions, uncertainties and risks that could cause future events or results to be materially different from those stated or implied in this report. Many of the factors that will determine these results are beyond our ability to control or predict. Specific factors that could cause actual results to differ from results contemplated by the forward-looking statements include, among others, the following:

• Whether WPZ will produce sufficient cash flows to provide the level of cash distributions that we expect;

21

• Whether we are able to pay current and expected levels of dividends;

• Whether WPZ elects to pay expected levels of cash distributions and we elect to pay expected levels of dividends;

• Whether we will be able to effectively execute our financing plan including the receipt of anticipated levels of proceeds from planned asset sales;

• Whether we will be able to effectively manage the transition in our board of directors and management as well as successfully execute our business restructuring;

• Availability of supplies, including lower than anticipated volumes from third parties served by our midstream business, and market demand;

• Volatility of pricing including the effect of lower than anticipated energy commodity prices and margins;

• Inflation, interest rates, and general economic conditions (including future disruptions and volatility in the global credit markets and the impact of these events on customers and suppliers);

• The strength and financial resources of our competitors and the effects of competition;

• Whether we are able to successfully identify, evaluate, and timely execute our capital projects and other

investment opportunities in accordance with our forecasted capital expenditures budget;

• Our ability to successfully expand our facilities and operations;

• Development of alternative energy sources;

• Availability of adequate insurance coverage and the impact of operational and developmental hazards and unforeseen interruptions;

• The impact of existing and future laws, regulations, the regulatory environment, environmental liabilities, and litigation, as well as our ability to obtain permits and achieve favorable rate proceeding outcomes;

• Our costs and funding obligations for defined benefit pension plans and other postretirement benefit plans;

• Changes in maintenance and construction costs;

• Changes in the current geopolitical situation;

• Our exposure to the credit risk of our customers and counterparties;

• Risks related to financing, including restrictions stemming from debt agreements, future changes in credit ratings as determined by nationally-recognized credit rating agencies and the availability and cost of capital;

• The amount of cash distributions from and capital requirements of our investments and joint ventures in which we participate;

22

• Risks associated with weather and natural phenomena, including climate conditions and physical damage to our facilities;

• Acts of terrorism, including cybersecurity threats and related disruptions;

• Additional risks described in our filings with the Securities and Exchange Commission (SEC).

Given the uncertainties and risk factors that could cause our actual results to differ materially from those contained in any forward-looking statement, we caution investors not to unduly rely on our forward-looking statements. We disclaim any obligations to and do not intend to update the above list or announce publicly the result of any revisions to any of the forward-looking statements to reflect future events or developments.

In addition to causing our actual results to differ, the factors listed above and referred to below may cause our intentions to change from those statements of intention set forth in this report. Such changes in our intentions may also cause our results to differ. We may change our intentions, at any time and without notice, based upon changes in such factors, our assumptions, or otherwise.

Because forward-looking statements involve risks and uncertainties, we caution that there are important factors, in addition to those listed above, that may cause actual results to differ materially from those contained in the forward-looking statements. These factors are described in the following section.

RISK FACTORS

You should carefully consider the following risk factors in addition to the other information in this report. Each of these factors could adversely affect our business, prospects, financial condition, results of operations, cash flows and, in some cases our reputation. The occurrence of any of such risks could also adversely affect the value of an investment in our securities.

Litigation pertaining to the ETC Merger, including litigation related to Energy Transfer Equity, L.P.’s (ETE’s) termination of and failure to close the ETC Merger, may negatively impact our business and operations.

We have incurred and may continue to incur additional costs in connection with the prosecution, defense or settlement of the currently pending and any future litigation relating to the ETC Merger or ETE’s termination of and failure to close the ETC Merger. Such litigation includes, among other litigation matters, litigation brought by stockholders of us and unitholders of WPZ related to the ETC Merger and/or Williams’ termination of the merger agreement with WPZ. Such litigation also includes the on-going litigation against ETE and its affiliates a portion of which is on appeal in the Delaware Supreme Court and in which ETE has asserted counterclaims against us. We continue to believe that our lawsuit against ETE and its affiliates is an enforcement of our rights under the Merger Agreement and that this lawsuit is designed to deliver to our stockholders benefits under the Merger Agreement. We cannot predict the outcome of this litigation. Such litigation may also create a distraction for our management team and board of directors and require time and attention. In addition, any litigation relating to the ETC Merger or ETE’s termination of and failure to close the ETC Merger could, among other things, adversely affect our financial condition and results of operations.

We are exposed to the credit risk of our customers and counterparties, including Chesapeake Energy Corporation and its affiliates, and our credit risk management will not be able to completely eliminate such risk.

We are subject to the risk of loss resulting from nonpayment and/or nonperformance by our customers and counterparties in the ordinary course of our business. Generally, our customers are rated investment grade, are otherwise considered creditworthy or are required to make prepayments or provide security to satisfy credit concerns. However, our credit procedures and policies cannot completely eliminate customer and counterparty credit risk. Our customers and counterparties include industrial customers, local distribution companies, natural gas producers, and marketers whose creditworthiness may be suddenly and disparately impacted by, among other factors, commodity price volatility,

23

deteriorating energy market conditions, and public and regulatory opposition to energy producing activities. In a low commodity price environment certain of our customers could be negatively impacted, causing them significant economic stress including, in some cases, to file for bankruptcy protection or to renegotiate contracts. To the extent one or more of our key customers commences bankruptcy proceedings, our contracts with the customers may be subject to rejection under applicable provisions of the United States Bankruptcy Code, or may be renegotiated. Further, during any such bankruptcy proceeding, prior to assumption, rejection or renegotiation of such contracts, the bankruptcy court may temporarily authorize the payment of value for our services less than contractually required, which could have a material adverse effect on our business, results of operations, cash flows, and financial conditions. For example, Chesapeake Energy Corporation and its affiliates, which accounted for approximately 14 percent of our 2016 consolidated revenues, have experienced significant, negative financial results due to sustained low commodity prices. If we fail to adequately assess the creditworthiness of existing or future customers and counterparties or otherwise do not take or are unable to take sufficient mitigating actions, including obtaining sufficient collateral, deterioration in their creditworthiness and any resulting increase in nonpayment and/or nonperformance by them could cause us to write down or write off accounts receivable. Such write-downs or write-offs could negatively affect our operating results in the periods in which they occur, and, if significant, could have a material adverse effect on our business, financial condition, results of operations, and cash flows.

Prices for NGLs, olefins, natural gas, oil, and other commodities, are volatile and this volatility has and could continue to adversely affect our financial results, cash flows, access to capital, and ability to maintain our existing businesses.

Our revenues, operating results, future rate of growth, and the value of certain components of our businesses depend primarily upon the prices of NGLs, olefins, natural gas, oil, or other commodities, and the differences between prices of these commodities, and could be materially adversely affected by an extended period of current low commodity prices or a further decline in commodity prices. Price volatility has and could continue to impact both the amount we receive for our products and services and the volume of products and services we sell. Prices affect the amount of cash flow available for capital expenditures and our ability to borrow money or raise additional capital. Price volatility has and could continue to have an adverse effect on our business, results of operations, financial condition, and cash flows.

The markets for NGLs, olefins, natural gas, oil, and other commodities are likely to continue to be volatile. Wide fluctuations in prices might result from one or more factors beyond our control, including:

• Worldwide and domestic supplies of and demand for natural gas, NGLs, olefins, oil, and related commodities;

• Turmoil in the Middle East and other producing regions;

• The activities of the Organization of Petroleum Exporting Countries;

• The level of consumer demand;

• The price and availability of other types of fuels or feedstocks;

• The availability of pipeline capacity;

• Supply disruptions, including plant outages and transportation disruptions;

• The price and quantity of foreign imports of natural gas and oil;

• Domestic and foreign governmental regulations and taxes;

24

• The credit of participants in the markets where products are bought and sold.

Downgrades of our credit ratings, which are determined outside of our control by independent third parties, impact our liquidity, access to capital, and our costs of doing business.

Downgrades of our credit ratings increase our cost of borrowing and could require us to provide collateral to our counterparties, negatively impacting our available liquidity. In addition, our ability to access capital markets could continue to be limited by the downgrading of our credit ratings.

Credit rating agencies perform independent analysis when assigning credit ratings. This analysis includes a number of criteria such as, business composition, market, and operational risks, as well as various financial tests. Credit rating agencies continue to review the criteria for industry sectors and various debt ratings and may make changes to those criteria from time to time. Credit ratings are subject to revision or withdrawal at any time by the ratings agencies. As of the date of the filing of this report, we have been assigned below investment-grade credit ratings by each of the three credit ratings agencies.

Our ability to obtain credit in the future could be affected by WPZ’s credit ratings.

A substantial portion of our operations are conducted through, and our cash flows are substantially derived from distributions paid to us by, WPZ. Due to our relationship with WPZ, our ability to obtain credit will be affected by WPZ’s credit ratings. If WPZ were to experience a deterioration in its credit standing or financial condition, our access to capital, and our ratings could be adversely affected. Any future downgrading of a WPZ credit rating could also result in a downgrading of our credit rating. A downgrading of a WPZ credit rating could limit our ability to obtain financing in the future upon favorable terms, if at all.

The financial condition of our natural gas transportation and midstream businesses is dependent on the continued availability of natural gas supplies in the supply basins that we access and demand for those supplies in the markets we serve.

Our ability to maintain and expand our natural gas transportation and midstream businesses depends on the level of drilling and production by third parties in our supply basins. Production from existing wells and natural gas supply basins with access to our pipeline and gathering systems will naturally decline over time. The amount of natural gas reserves underlying these existing wells may also be less than anticipated, and the rate at which production from these reserves declines may be greater than anticipated. We do not obtain independent evaluations of natural gas reserves connected to our systems and processing facilities. Accordingly, we do not have independent estimates of total reserves dedicated to our systems or the anticipated life of such reserves. In addition, low prices for natural gas, regulatory limitations, or the lack of available capital could adversely affect the development and production of additional natural gas reserves, the installation of gathering, storage, and pipeline transportation facilities and the import and export of natural gas supplies. Localized low natural gas prices in one or more of our existing supply basins, whether caused by a lack of infrastructure or otherwise, could also result in depressed natural gas production in such basins and limit the supply of natural gas made available to us. The competition for natural gas supplies to serve other markets could also reduce the amount of natural gas supply for our customers. A failure to obtain access to sufficient natural gas supplies will adversely impact our ability to maximize the capacities of our gathering, transportation, and processing facilities.

Demand for our services is dependent on the demand for gas in the markets we serve. Alternative fuel sources such as electricity, coal, fuel oils, or nuclear energy could reduce demand for natural gas in our markets and have an adverse effect on our business.

A failure to obtain access to sufficient natural gas supplies or a reduction in demand for our services in the markets we serve could result in impairments of our assets and have a material adverse effect on our business, financial condition, results of operations, and cash flows.

25

We may not be able to grow or effectively manage our growth.

As part of our growth strategy, we consider acquisition opportunities and engage in significant capital projects. We have both a project lifecycle process and an investment evaluation process. These are processes we use to identify, evaluate, and execute on acquisition opportunities and capital projects. We may not always have sufficient and accurate information to identify and value potential opportunities and risks or our investment evaluation process may be incomplete or flawed. Regarding potential acquisitions, suitable acquisition candidates may not be available on terms and conditions we find acceptable or, where multiple parties are trying to acquire an acquisition candidate, we may not be chosen as the acquirer. If we are able to acquire a targeted business, we may not be able to successfully integrate the acquired businesses and realize anticipated benefits in a timely manner. Our growth may also be dependent upon the construction of new natural gas gathering, transportation, compression, processing or treating pipelines, and facilities, NGL transportation, or fractionation or storage facilities as well as the expansion of existing facilities.

We also face all the risks associated with construction, including political opposition by landowners, environmental activists, and others resulting in the delay and/or denial of required governmental permits. Other construction risks include the inability to obtain rights-of-way, skilled labor, equipment, materials, and other required inputs in a timely manner such that projects are completed, on time or at all, and the risk that construction cost overruns could cause total project costs to exceed budgeted costs. Additional risks associated with growing our business include, among others, that:

• Changing circumstances and deviations in variables could negatively impact our investment analysis, including our projections of revenues, earnings, and cash flow relating to potential investment targets, resulting in outcomes which are materially different than anticipated;

• We could be required to contribute additional capital to support acquired businesses or assets;

• We may assume liabilities that were not disclosed to us, that exceed our estimates and for which contractual protections are either unavailable or prove inadequate;

• Acquisitions could disrupt our ongoing business, distract management, divert financial, and operational resources from existing operations and make it difficult to maintain our current business standards, controls, and procedures;

• Acquisitions and capital projects may require substantial new capital, including the issuance of debt or equity, and we may not be able to access capital markets or obtain acceptable terms.

If realized, any of these risks could have an adverse impact on our financial condition, results of operations, including the possible impairment of our assets, or cash flows.

We do not own all of the interests in the Partially Owned Entities, which could adversely affect our ability to operate and control these assets in a manner beneficial to us.

Because we do not control the Partially Owned Entities, we may have limited flexibility to control the operation of or cash distributions received from these entities. The Partially Owned Entities’ organizational documents generally require distribution of their available cash to their members on a quarterly basis; however, in each case, available cash is reduced, in part, by reserves appropriate for operating the businesses. As of December 31, 2016, our investments in the Partially Owned Entities accounted for approximately 8 percent of our total consolidated assets. Conflicts of interest may arise in the future between us, on the one hand, and our Partially Owned Entities, on the other hand, with regard to our Partially Owned Entities’ governance, business, or operations. If a conflict of interest arises between us and a Partially Owned Entity, other owners may control the Partially Owned Entity’s actions with respect to such matter (subject to certain limitations), which could be detrimental to our business. Any future disagreements with the other co-owners of these assets could adversely affect our ability to respond to changing economic or industry conditions, which could have a material adverse effect on our business, financial condition, results of operations, and cash flows.

26

Holders of our common stock may not receive dividends in the amount expected or any dividends.

We may not have sufficient cash each quarter to pay dividends or maintain current or expected levels of dividends. The actual amount of cash we dividend may fluctuate from quarter to quarter and will depend on various factors, some of which are beyond our control, including:

• The amount of cash that WPZ and our other subsidiaries distribute to us;

• The amount of cash we generate from our operations, our working capital needs, our level of capital expenditures, and our ability to borrow;

• The restrictions contained in our indentures and credit facility and our debt service requirements;

• The cost of acquisitions, if any.

A failure either to pay dividends or to pay dividends at expected levels could result in a loss of investor confidence, reputational damage, and a decrease in the value of our stock price.

Our cash flow depends heavily on the earnings and distributions of WPZ.

Our partnership interest in WPZ is currently our largest cash-generating asset. Therefore, we are, at the least, indirectly exposed to all the risks to which WPZ is subject and our cash flow is heavily dependent upon the ability of WPZ to make distributions to its partners. A significant decline in WPZ’s earnings and/or distributions would have a corresponding negative impact on us.

We may not be able to sell assets or, if we are able to sell assets, to raise a sufficient amount of capital from such asset sales. In addition, the timing to enter into and close any asset sales could be significantly different than our expected timeline.

We are planning to monetize certain assets held by our subsidiaries in 2017 (including without limitation the Geismar olefins facility owned by WPZ) to fund additional debt reduction and capital and investment expenditures. Given the commodity markets, financial markets, and other challenges currently facing the energy sector, our competitors may also engage in asset sales leading to lower demand for the assets we wish to sell. We may not be able to sell the assets we identify for sale on favorable terms or at all. If we are able to sell assets, the timing of the receipt of the asset sale proceeds may not align with the timing of our capital requirements. A failure to raise sufficient capital from asset sales or a misalignment of the timing of capital raised and capital funding needs could have an adverse impact on our business, financial condition, results of operations, and cash flows.

An impairment of our assets, including goodwill, property, plant, and equipment, intangible assets, and/or equity-method investments, could reduce our earnings.

GAAP requires us to test certain assets for impairment on either an annual basis or when events or circumstances occur which indicate that the carrying value of such assets might be impaired. The outcome of such testing could result in impairments of our assets including our goodwill, property, plant, and equipment, intangible assets, and/or equity method investments. Additionally, any asset monetizations could result in impairments if any assets are sold or otherwise exchanged for amounts less than their carrying value. If we determine that an impairment has occurred, we would be required to take an immediate noncash charge to earnings.

Our industry is highly competitive and increased competitive pressure could adversely affect our business and operating results.

We have numerous competitors in all aspects of our businesses, and additional competitors may enter our markets. Some of our competitors are large oil, natural gas, and petrochemical companies that have greater access to supplies

27

of natural gas and NGLs than we do. In addition, current or potential competitors may make strategic acquisitions or have greater financial resources than we do, which could affect our ability to make strategic investments or acquisitions. Our competitors may be able to respond more quickly to new laws or regulations or emerging technologies or to devote greater resources to the construction, expansion, or refurbishment of their facilities than we can. Similarly, a highly-liquid competitive commodity market in natural gas and increasingly competitive markets for natural gas services, including competitive secondary markets in pipeline capacity, have developed. As a result, pipeline capacity is being used more efficiently, and peaking and storage services are increasingly effective substitutes for annual pipeline capacity. Failure to successfully compete against current and future competitors could have a material adverse effect on our business, results of operations, financial condition, and cash flows.

We may not be able to replace, extend, or add additional customer contracts or contracted volumes on favorable terms, or at all, which could affect our financial condition, the amount of cash available to pay dividends, and our ability to grow.

We rely on a limited number of customers and producers for a significant portion of our revenues and supply of natural gas and NGLs. Although many of our customers and suppliers are subject to long-term contracts, if we are unable to replace or extend such contracts, add additional customers, or otherwise increase the contracted volumes of natural gas provided to us by current producers, in each case on favorable terms, if at all, our financial condition, growth plans, and the amount of cash available to pay dividends could be adversely affected. Our ability to replace, extend, or add additional customer or supplier contracts, or increase contracted volumes of natural gas from current producers, on favorable terms, or at all, is subject to a number of factors, some of which are beyond our control, including:

• The level of existing and new competition in our businesses or from alternative fuel sources, such as electricity, coal, fuel oils, or nuclear energy;

• Natural gas, NGL, and olefins prices, demand, availability, and margins in our markets. Higher prices for energy commodities related to our businesses could result in a decline in the demand for those commodities and, therefore, in customer contracts or throughput on our pipeline systems. Also, lower energy commodity prices could negatively impact our ability to maintain or achieve favorable contractual terms, including pricing, and could also result in a decline in the production of energy commodities resulting in reduced customer contracts, supply contracts, and throughput on our pipeline systems;

• General economic, financial markets, and industry conditions;

• The effects of regulation on us, our customers, and our contracting practices;

• Our ability to understand our customers’ expectations, efficiently and reliably deliver high quality services and effectively manage customer relationships. The results of these efforts will impact our reputation and positioning in the market.

Some of our businesses are exposed to supplier concentration risks arising from dependence on a single or a limited number of suppliers.

Some of our businesses may be dependent on a small number of suppliers for delivery of critical goods or services. For instance, pursuant to a compression services agreement, one of our businesses receives a substantial portion of its compression capacity on certain gathering systems from EXLP Operating LLC (“Exterran Operating”). Exterran Operating has, until December 31, 2020, the exclusive right to provide compression services on certain gas gathering systems located in Wyoming, Texas, Oklahoma, Louisiana, and Arkansas, in return for the payment of specified monthly rates for the services provided, subject to an annual escalation provision. If a supplier on which one of our businesses depends were to fail to timely supply required goods and services, such business may not be able to replace such goods and services in a timely manner or otherwise on favorable terms or at all. If our business is unable to adequately diversify or otherwise mitigate such supplier concentration risks and such risks were realized, such businesses could be subject to reduced revenues and increased expenses, which could have a material adverse effect on our financial condition, results of operation, and cash flows.

28

We will conduct certain operations through joint ventures that may limit our operational flexibility or require us to make additional capital contributions.

Some of our operations are conducted through joint venture arrangements, and we may enter additional joint ventures in the future. In a joint venture arrangement, we have less operational flexibility, as actions must be taken in accordance with the applicable governing provisions of the joint venture. In certain cases:

• We cannot control the amount of capital expenditures that we are required to fund with respect to these operations;

• We are dependent on third parties to fund their required share of capital expenditures;

• We may be subject to restrictions or limitations on our ability to sell or transfer our interests in the jointly owned assets;

• We may be forced to offer rights of participation to other joint venture participants in the area of mutual interest;

• We have limited ability to influence or control certain day to day activities affecting the operations.

In addition, joint venture participants may have obligations that are important to the success of the joint venture, such as the obligation to pay substantial carried costs pertaining to the joint venture and to pay their share of capital and other costs of the joint venture. The performance and ability of third parties to satisfy their obligations under joint venture arrangements is outside our control. If these third parties do not satisfy their obligations under these arrangements, our business may be adversely affected. Joint venture partners may be in a position to take actions contrary to instructions or requests or contrary to our policies or objectives, and disputes between us and our joint venture partners may result in delays, litigation or operational impasses.

If we fail to make a required capital contribution under the applicable governing provisions of a joint venture arrangements, we could be deemed to be in default under the joint venture agreement. Joint venture partners may be permitted to fund any deficiency resulting from our failure to make such capital contribution, which would result in a dilution of our ownership interest, or such joint venture partners may have the option to purchase all of our existing interest in the subject joint venture.

The risks described above or the failure to continue joint ventures, or to resolve disagreements with joint venture partners could adversely affect our ability to conduct our operations that are the subject of any joint venture, which could in turn negatively affect our financial condition and results of operations.

Our operations are subject to operational hazards and unforeseen interruptions.

There are operational risks associated with the gathering, transporting, storage, processing, and treating of natural gas, the fractionation, transportation, and storage of NGLs, the processing of olefins, and crude oil transportation and production handling, including:

• Aging infrastructure and mechanical problems;

• Damages to pipelines and pipeline blockages or other pipeline interruptions;

• Uncontrolled releases of natural gas (including sour gas), NGLs, olefins products, brine, or industrial chemicals;

• Collapse or failure of storage caverns;

29

• Operator error;

• Damage caused by third-party activity, such as operation of construction equipment;

• Pollution and other environmental risks;

• Fires, explosions, craterings, and blowouts;

• Truck and rail loading and unloading;

• Operating in a marine environment.

Any of these risks could result in loss of human life, personal injuries, significant damage to property, environmental pollution, impairment of our operations, loss of services to our customers, reputational damage, and substantial losses to us. The location of certain segments of our facilities in or near populated areas, including residential areas, commercial business centers, and industrial sites, could increase the level of damages resulting from these risks. An event such as those described above could have a material adverse effect on our financial condition and results of operations, particularly if the event is not fully covered by insurance.

We do not insure against all potential risks and losses and could be seriously harmed by unexpected liabilities or by the inability of our insurers to satisfy our claims.

In accordance with customary industry practice, we maintain insurance against some, but not all, risks and losses, and only at levels we believe to be appropriate. We currently maintain excess liability insurance with limits of $820 million per occurrence and in the annual aggregate with a $2 million per occurrence deductible. This insurance covers us, our subsidiaries, and certain of our affiliates for legal and contractual liabilities arising out of bodily injury or property damage, including resulting loss of use to third parties. This excess liability insurance includes coverage for sudden and accidental pollution liability for full limits, with the first $135 million of insurance also providing gradual pollution liability coverage for natural gas and NGL operations.

Although we maintain property insurance on certain physical assets that we own, lease or are responsible to insure, the policy may not cover the full replacement cost of all damaged assets or the entire amount of business interruption loss we may experience. In addition, certain perils may be excluded from coverage or be sub-limited. We may not be able to maintain or obtain insurance of the type and amount we desire at reasonable rates. We may elect to self-insure a portion of our risks. We do not insure our onshore underground pipelines for physical damage, except at certain locations such as river crossings and compressor stations. Offshore assets are covered for property damage when loss is due to a named windstorm event, but coverage for loss caused by a named windstorm is subject to a significant sub-limit and to a large deductible. All of our insurance is subject to deductibles.

In addition, to the insurance coverage described above, we are a member of Oil Insurance Limited (OIL), an energy industry mutual insurance company, which provides coverage for damage to our property. As an insured member of OIL, we share in the losses among other OIL members even if our property is not damaged.

The occurrence of any risks not fully covered by insurance could have a material adverse effect on our business, financial condition, results of operations, and cash flows and our ability to repay our debt.

Our assets and operations, as well as our customers’ assets and operations, can be adversely affected by weather and other natural phenomena.

Our assets and operations, especially those located offshore, and our customers’ assets and operations can be adversely affected by hurricanes, floods, earthquakes, landslides, tornadoes, fires, and other natural phenomena and weather conditions, including extreme or unseasonable temperatures, making it more difficult for us to realize the

30

historic rates of return associated with our assets and operations. A significant disruption in our or our customers’ operations or a significant liability for which we are not fully insured could have a material adverse effect on our business, financial condition, results of operations, and cash flows.

Acts of terrorism could have a material adverse effect on our business, financial condition, results of operations, and cash flows.

Given the volatile nature of the commodities we transport, process, store, and sell, our assets and the assets of our customers and others in our industry may be targets of terrorist activities. A terrorist attack could create significant price volatility, disrupt our business, limit our access to capital markets, or cause significant harm to our operations, such as full or partial disruption to our ability to produce, process, transport, or distribute natural gas, NGLs, or other commodities. Acts of terrorism, as well as events occurring in response to or in connection with acts of terrorism, could cause environmental repercussions that could result in a significant decrease in revenues or significant reconstruction or remediation costs, which could have a material adverse effect on our business, financial condition, results of operations, and cash flows.

Our business could be negatively impacted by security threats, including cybersecurity threats, and related disruptions.

We rely on our information technology infrastructure to process, transmit, and store electronic information, including information we use to safely operate our assets. While we believe that we maintain appropriate information security policies, practices, and protocols, we face cybersecurity and other security threats to our information technology infrastructure, which could include threats to our operational industrial control systems and safety systems that operate our pipelines, plants, and assets. We could face unlawful attempts to gain access to our information technology infrastructure, including coordinated attacks from hackers, whether state-sponsored groups, “hacktivists”, or private individuals. The age, operating systems, or condition of our current information technology infrastructure and software assets and our ability to maintain and upgrade such assets could affect our ability to resist cybersecurity threats. We could also face attempts to gain access to information related to our assets through attempts to obtain unauthorized access by targeting acts of deception against individuals with legitimate access to physical locations or information.

Breaches in our information technology infrastructure or physical facilities, or other disruptions including those arising from theft, vandalism, fraud, or unethical conduct, could result in damage to our assets, unnecessary waste, safety incidents, damage to the environment, reputational damage, potential liability, or the loss of contracts, and have a material adverse effect on our operations, financial condition, results of operations, and cash flows.

The natural gas sales, transportation, and storage operations of our gas pipelines are subject to regulation by the FERC, which could have an adverse impact on their ability to establish transportation and storage rates that would allow them to recover the full cost of operating their respective pipelines, including a reasonable rate of return.

In addition to regulation by other federal, state, and local regulatory authorities, under the Natural Gas Act of 1938, interstate pipeline transportation and storage service is subject to regulation by the FERC. Federal regulation extends to such matters as:

• Transportation and sale for resale of natural gas in interstate commerce;

• Rates, operating terms, types of services, and conditions of service;

• Certification and construction of new interstate pipelines and storage facilities;

• Acquisition, extension, disposition, or abandonment of existing interstate pipelines and storage facilities;

• Accounts and records;

31

• Depreciation and amortization policies;

• Relationships with affiliated companies who are involved in marketing functions of the natural gas business;

• Market manipulation in connection with interstate sales, purchases, or transportation of natural gas.

Regulatory or administrative actions in these areas, including successful complaints or protests against the rates of the gas pipelines, can affect our business in many ways, including decreasing tariff rates and revenues, decreasing volumes in our pipelines, increasing our costs, and otherwise altering the profitability of our pipeline business.

Our operations are subject to environmental laws and regulations, including laws and regulations relating to climate change and greenhouse gas emissions, which may expose us to significant costs, liabilities, and expenditures that could exceed our expectations.

Our operations are subject to extensive federal, state, tribal, and local laws and regulations governing environmental protection, endangered and threatened species, the discharge of materials into the environment, and the security of chemical and industrial facilities. Substantial costs, liabilities, delays, and other significant issues related to environmental laws and regulations are inherent in the gathering, transportation, storage, processing, and treating of natural gas, fractionation, transportation, and storage of NGLs, processing of olefins, and crude oil transportation and production handling as well as waste disposal practices and construction activities. Failure to comply with these laws, regulations, and permits may result in the assessment of administrative, civil and/or criminal penalties, the imposition of remedial obligations, the imposition of stricter conditions on or revocation of permits, the issuance of injunctions limiting or preventing some or all of our operations, and delays or denials in granting permits.

Joint and several, strict liability may be incurred without regard to fault under certain environmental laws and regulations, for the remediation of contaminated areas and in connection with spills or releases of materials associated with natural gas, oil, and wastes on, under or from our properties and facilities. Private parties, including the owners of properties through which our pipeline and gathering systems pass and facilities where our wastes are taken for reclamation or disposal, may have the right to pursue legal actions to enforce compliance as well as to seek damages for noncompliance with environmental laws and regulations or for personal injury or property damage arising from our operations. Some sites at which we operate are located near current or former third-party hydrocarbon storage and processing or oil and natural gas operations or facilities, and there is a risk that contamination has migrated from those sites to ours.

We are generally responsible for all liabilities associated with the environmental condition of our facilities and assets, whether acquired or developed, regardless of when the liabilities arose and whether they are known or unknown. In connection with certain acquisitions and divestitures, we could acquire, or be required to provide indemnification against, environmental liabilities that could expose us to material losses, which may not be covered by insurance. In addition, the steps we could be required to take to bring certain facilities into compliance could be prohibitively expensive, and we might be required to shut down, divest or alter the operation of those facilities, which might cause us to incur losses.

In addition, climate change regulations and the costs associated with the regulation of emissions of greenhouse gases (GHGs) have the potential to affect our business. Regulatory actions by the Environmental Protection Agency or the passage of new climate change laws or regulations could result in increased costs to (i) operate and maintain our facilities, (ii) install new emission controls on our facilities, or (iii) administer and manage our GHG compliance program. If we are unable to recover or pass through a significant level of our costs related to complying with climate change regulatory requirements imposed on us, it could have a material adverse effect on our results of operations and financial condition. To the extent financial markets view climate change and GHG emissions as a financial risk, this could negatively impact our cost of and access to capital. Climate change and GHG regulation could also reduce demand for our services.

32

If third-party pipelines and other facilities interconnected to our pipelines and facilities become unavailable to transport natural gas and NGLs or to treat natural gas, our revenues could be adversely affected.

We depend upon third-party pipelines and other facilities that provide delivery options to and from our pipelines and facilities for the benefit of our customers. Because we do not own these third-party pipelines or other facilities, their continuing operation is not within our control. If these pipelines or facilities were to become temporarily or permanently unavailable for any reason, or if throughput were reduced because of testing, line repair, damage to pipelines or facilities, reduced operating pressures, lack of capacity, increased credit requirements or rates charged by such pipelines or facilities or other causes, we and our customers would have reduced capacity to transport, store or deliver natural gas or NGL products to end use markets or to receive deliveries of mixed NGLs, thereby reducing our revenues. Any temporary or permanent interruption at any key pipeline interconnect or in operations on third-party pipelines or facilities that would cause a material reduction in volumes transported on our pipelines or our gathering systems or processed, fractionated, treated, or stored at our facilities could have a material adverse effect on our business, financial condition, results of operations, and cash flows.

The operation of our businesses might also be adversely affected by regulatory proceedings, changes in government regulations or in their interpretation or implementation, or the introduction of new laws or regulations applicable to our businesses or our customers.

Public and regulatory scrutiny of the energy industry has resulted in the proposal and/or implementation of increased regulations. Such scrutiny has also resulted in various inquiries, investigations, and court proceedings, including litigation of energy industry matters. Both the shippers on our pipelines and regulators have rights to challenge the rates we charge under certain circumstances. Any successful challenge could materially affect our results of operations.

Certain inquiries, investigations, and court proceedings are ongoing. Adverse effects may continue as a result of the uncertainty of ongoing inquiries, investigations, and court proceedings, or additional inquiries and proceedings by federal or state regulatory agencies or private plaintiffs. In addition, we cannot predict the outcome of any of these inquiries or whether these inquiries will lead to additional legal proceedings against us, civil or criminal fines and/or penalties, or other regulatory action, including legislation, which might be materially adverse to the operation of our business and our results of operations or increase our operating costs in other ways. Current legal proceedings or other matters, including environmental matters, suits, regulatory appeals, and similar matters might result in adverse decisions against us which, among other outcomes, could result in the imposition of substantial penalties and fines and could damage our reputation. The result of such adverse decisions, either individually or in the aggregate, could be material and may not be covered fully or at all by insurance.

In addition, existing regulations, including those pertaining to financial assurances to be provided by our businesses in respect of potential asset decommissioning and abandonment activities, might be revised, reinterpreted, or otherwise enforced in a manner which differs from prior regulatory action. New laws and regulations, including those pertaining to oil and gas hedging and cash collateral requirements, might also be adopted or become applicable to us, our customers, or our business activities. If new laws or regulations are imposed relating to oil and gas extraction, or if additional or revised levels of reporting, regulation, or permitting moratoria are required or imposed, including those related to hydraulic fracturing, the volumes of natural gas and other products that we transport, gather, process, and treat could decline, our compliance costs could increase, and our results of operations could be adversely affected.

Certain of our gas pipeline services are subject to long-term, fixed-price contracts that are not subject to adjustment, even if our cost to perform such services exceeds the revenues received from such contracts.

Our gas pipelines provide some services pursuant to long-term, fixed-price contracts. It is possible that costs to perform services under such contracts will exceed the revenues our pipelines collect for their services. Although most of the services are priced at cost-based rates that are subject to adjustment in rate cases, under FERC policy, a regulated service provider and a customer may mutually agree to sign a contract for service at a “negotiated rate” that may be above or below the FERC regulated cost-based rate for that service. These “negotiated rate” contracts are not generally

33

subject to adjustment for increased costs that could be produced by inflation or other factors relating to the specific facilities being used to perform the services.

Our operating results for certain components of our business might fluctuate on a seasonal basis.

Revenues from certain components of our business can have seasonal characteristics. In many parts of the country, demand for natural gas and other fuels peaks during the winter. As a result, our overall operating results in the future might fluctuate substantially on a seasonal basis. Demand for natural gas and other fuels could vary significantly from our expectations depending on the nature and location of our facilities and pipeline systems and the terms of our natural gas transportation arrangements relative to demand created by unusual weather patterns.

We do not own all of the land on which our pipelines and facilities are located, which could disrupt our operations.

We do not own all of the land on which our pipelines and facilities have been constructed. As such, we are subject to the possibility of increased costs to retain necessary land use. In those instances in which we do not own the land on which our facilities are located, we obtain the rights to construct and operate our pipelines and gathering systems on land owned by third parties and governmental agencies for a specific period of time. In addition, some of our facilities cross Native American lands pursuant to rights-of-way of limited terms. We may not have the right of eminent domain over land owned by Native American tribes. Our loss of these rights, through our inability to renew right-of-way contracts or otherwise, could have a material adverse effect on our business, financial condition, results of operations, and cash flows.

Difficult conditions in the global financial markets and the economy in general could negatively affect our business and results of operations.

Our businesses may be negatively impacted by adverse economic conditions or future disruptions in global financial markets. Included among these potential negative impacts are industrial or economic contraction leading to reduced energy demand and lower prices for our products and services and increased difficulty in collecting amounts owed to us by our customers. If financing is not available when needed, or is available only on unfavorable terms, we may be unable to implement our business plans or otherwise take advantage of business opportunities or respond to competitive pressures. In addition, financial markets have periodically been affected by concerns over U.S. fiscal and monetary policies. These concerns, as well as actions taken by the U.S. federal government in response to these concerns, could significantly and adversely impact the global and U.S. economies and financial markets, which could negatively impact us in the manner described above.

Restrictions in our debt agreements and the amount of our indebtedness may affect our future financial and operating flexibility.

Our total outstanding long-term debt (including current portion) as of December 31, 2016, was $23.41 billion.

The agreements governing our indebtedness contain covenants that restrict our and our material subsidiaries’ ability to incur certain liens to support indebtedness and our ability to merge or consolidate or sell all or substantially all of our assets in certain circumstances. In addition, certain of our debt agreements contain various covenants that restrict or limit, among other things, our ability to make certain distributions during the continuation of an event of default, the ability of our subsidiaries to incur additional debt, and our and our material subsidiaries’ ability to enter into certain affiliate transactions and certain restrictive agreements. Certain of our debt agreements also contain, and those we enter into in the future may contain, financial covenants, and other limitations with which we will need to comply.

Our debt service obligations and the covenants described above could have important consequences. For example, they could:

• Make it more difficult for us to satisfy our obligations with respect to our indebtedness, which could in turn result in an event of default on such indebtedness;

34

• Impair our ability to obtain additional financing in the future for working capital, capital expenditures, acquisitions, general corporate purposes, or other purposes;

• Diminish our ability to withstand a continued or future downturn in our business or the economy generally;

• Require us to dedicate a substantial portion of our cash flow from operations to debt service payments, thereby reducing the availability of cash for working capital, capital expenditures, acquisitions, the payments of dividends, general corporate purposes, or other purposes;

• Limit our flexibility in planning for, or reacting to, changes in our business, and the industry in which we operate, including limiting our ability to expand or pursue our business activities and preventing us from engaging in certain transactions that might otherwise be considered beneficial to us.

Our ability to comply with our debt covenants, to repay, extend, or refinance our existing debt obligations and to obtain future credit will depend primarily on our operating performance. Our ability to refinance existing debt obligations or obtain future credit will also depend upon the current conditions in the credit markets and the availability of credit generally. If we are unable to comply with these covenants, meet our debt service obligations, or obtain future credit on favorable terms, or at all, we could be forced to restructure or refinance our indebtedness, seek additional equity capital or sell assets. We may be unable to obtain financing or sell assets on satisfactory terms, or at all.

Our failure to comply with the covenants in the documents governing our indebtedness could result in events of default, which could render such indebtedness due and payable. We may not have sufficient liquidity to repay our indebtedness in such circumstances. In addition, cross-default or cross-acceleration provisions in our debt agreements could cause a default or acceleration to have a wider impact on our liquidity than might otherwise arise from a default or acceleration of a single debt instrument. For more information regarding our debt agreements, please read Note 14 – Debt, Banking Arrangements, and Leases of Notes to Consolidated Financial Statements.

The Company’s business could be negatively impacted as a result of stockholder activism.

In recent years, stockholder activism, including threatened or actual proxy contests, has been directed against numerous public companies, including the Company. During the latter part of fiscal year 2016, the Company was the target of a proxy contest from a stockholder activist, which resulted in significant costs to the Company. If stockholder activists were to again take or threaten to take actions against the Company, the Company could incur significant costs as well as the distraction of management, which could have an adverse effect on the Company’s financial results. Stockholder activists may also seek to involve themselves in the governance, strategic direction, and operations of the Company. Such proposals may disrupt the Company’s business and divert the attention of the Company’s management and employees; and any perceived uncertainties as to the Company’s future direction resulting from such a situation could result in the loss of potential business opportunities, the perception that the Company needs a change in the direction of its business, or the perception that the Company is unstable or lacks continuity, any or all of which may be exploited by our competitors, cause concern to our current or potential customers, and may make it more difficult for the Company to attract and retain qualified personnel and business partners, which could adversely affect the Company’s business. In addition, actions of activist stockholders may cause significant fluctuations in our stock price based on temporary or speculative market perceptions or other factors that do not necessarily reflect the underlying fundamentals and prospects of our business.

We are experiencing significant change in the composition of our Board of Directors and senior management.

On June 30, 2016, Frank T. MacInnis stepped down as Chairman of the Board and Kathleen B. Cooper was appointed as Chairman of the Board. Also on June 30, 2016, each of Ralph Izzo, Frank T. MacInnis, Eric W. Mandelblatt, Keith A. Meister, Steven W. Nance, and Laura A. Sugg resigned from the Board. On August 28, 2016, the Board appointed three new independent directors to the Board: Stephen W. Bergstrom, Scott D. Sheffield, and William H. Spence; on September 23, 2016, the Board appointed two additional new independent directors to the Board: Stephen I. Chazen and Peter A. Ragauss; and on December 5, 2016, the Board appointed two more additional new independent

35

directors to the Board: Charles “Casey” Cogut and Michael A. Creel. Three of Williams former directors, Joseph R. Cleveland, John A. Hagg, and Juanita H. Hinshaw, determined not to stand for re-election at the Company’s November 23, 2016 annual meeting. Thus, the Board is now composed of eleven directors, seven of whom were appointed in the second half of 2016.

On December 13, 2016, the Company announced the retirement of Senior Vice President Robert S. Purgason, effective January 31, 2017. The Company is also executing on a restructuring process, shifting from five operating areas to three, and on February 14, 2017 the Company announced the appointment of Micheal Dunn as Executive Vice President and Chief Operating Officer.

The changes in composition of the Company’s board and management impose an additional demand for attention, time and energy of board members and management in connection with orientation and education of new members about the Company, including with regard to its business strategies and objectives, assets and operations, and policies and practices, which could distract the board and management from execution of the Company’s strategy and objectives. Additionally, such changes invite new analysis of our business as the new members contribute to the formulation of our business strategies and objectives, which could implicate changes to such strategy and objectives. It is possible that changes to the composition of our board and management could have a negative impact on our business, financial condition, and results of operations.

Institutional knowledge residing with current employees nearing retirement eligibility or with our former employees might not be adequately preserved.

We expect that a significant percentage of employees will become eligible for retirement over the next several years. In addition, as part of an internal restructuring, we recently announced the reduction of five operating areas into three and the closing of our Oklahoma City office and the consolidation of employee positions to Tulsa or other locations. As employees with significant institutional knowledge reach retirement age, choose not to relocate with us, or their services are otherwise no longer available to us, we may not be able to replace them with employees of comparable knowledge and experience. In addition, we may not be able to retain or recruit other qualified individuals, and our efforts at knowledge transfer could be inadequate. If knowledge transfer, recruiting, and retention efforts are inadequate, access to significant amounts of knowledge and expertise could become unavailable to us.

Our hedging activities might not be effective and could increase the volatility of our results.

In an effort to manage our financial exposure related to commodity price and market fluctuations, we have entered, and may in the future enter into, contracts to hedge certain risks associated with our assets and operations. In these hedging activities, we have used, and may in the future use, fixed-price, forward, physical purchase, and sales contracts, futures, financial swaps, and option contracts traded in the over-the-counter markets or on exchanges. Nevertheless, no single hedging arrangement can adequately address all risks present in a given contract. For example, a forward contract that would be effective in hedging commodity price volatility risks would not hedge the contract’s counterparty credit or performance risk. Therefore, unhedged risks will always continue to exist. While we attempt to manage counterparty credit risk within guidelines established by our credit policy, we may not be able to successfully manage all credit risk and as such, future cash flows and results of operations could be impacted by counterparty default.

One of our subsidiaries acts as the general partner of a publicly traded limited partnership, Williams Partners L.P. As such, this subsidiary’s operations may involve a greater risk of liability than ordinary business operations.

One of our subsidiaries acts as the general partner of WPZ, a publicly traded limited partnership. This subsidiary may be deemed to have undertaken contractual obligations with respect to WPZ as the general partner and to the limited partners of WPZ. Activities, determined to involve such obligations to other persons or entities typically involve a higher standard of conduct than ordinary business operations and therefore may involve a greater risk of liability, particularly when a conflict of interest is found to exist. Our control of the general partner of WPZ may increase the possibility of claims of breach of such duties, including claims brought due to conflicts of interest (including conflicts

36

of interest that may arise between WPZ, on the one hand, and its general partner and that general partner’s affiliates, including us, on the other hand). Any liability resulting from such claims could be material.

Failure of our service providers or disruptions to our outsourcing relationships might negatively impact our ability to conduct our business.

Certain of our accounting and information technology services are currently provided by third-party vendors, and sometimes from service centers outside of the United States. Services provided pursuant to these agreements could be disrupted. Similarly, the expiration of such agreements or the transition of services between providers could lead to loss of institutional knowledge or service disruptions. Our reliance on others as service providers could have a material adverse effect on our business, financial condition, results of operations, and cash flows.

Our costs and funding obligations for our defined benefit pension plans and costs for our other postretirement benefit plans are affected by factors beyond our control.

We have defined benefit pension plans covering substantially all of our U.S. employees and other postretirement benefit plans covering certain eligible participants. The timing and amount of our funding requirements under the defined benefit pension plans depend upon a number of factors that we control, including changes to pension plan benefits, as well as factors outside of our control, such as asset returns, interest rates, and changes in pension laws. Changes to these and other factors that can significantly increase our funding requirements could have a significant adverse effect on our financial condition and results of operations.

If there is a determination that the spin-off of WPX Energy, Inc. (WPX) stock to our stockholders is taxable for U.S. federal income tax purposes because the facts, representations or undertakings underlying a U.S. Internal Revenue Service (IRS) private letter ruling or a tax opinion are incorrect or for any other reason, then we and our stockholders could incur significant income tax liabilities.

In connection with our original separation plan that called for an initial public offering (IPO) of stock of WPX and a subsequent spin-off of our remaining shares of WPX to our stockholders, we obtained a private letter ruling from the IRS and an opinion of our outside tax advisor, to the effect that the distribution by us of WPX shares to our stockholders, and any related restructuring transaction undertaken by us, would not result in recognition for U.S. federal income tax purposes, of income, gain or loss to us or our stockholders under section 355 and section 368(a)(1)(D) of the U.S. Internal Revenue Code of 1986, as amended (Code), except for cash payments made to our stockholders in lieu of fractional shares of WPX common stock. In addition, we received an opinion from our outside tax advisor to the effect that the spin-off pursuant to our revised separation plan which was ultimately consummated on December 31, 2011, which did not involve an IPO of WPX shares, would not result in the recognition, for federal income tax purposes, of income, gain, or loss to us or our stockholders under section 355 and section 368(a)(1)(D) of the Code, except for cash payments made to our stockholders in lieu of fractional shares of WPX. The private letter ruling and opinion have relied on or will rely on certain facts, representations, and undertakings from us and WPX regarding the past and future conduct of the companies’ respective businesses and other matters. If any of these facts, representations, or undertakings are, or become, incorrect or are not otherwise satisfied, including as a result of certain significant changes in the stock ownership of us or WPX after the spin-off, or if the IRS disagrees with any such facts and representations upon audit, we and our stockholders may not be able to rely on the private letter ruling or the opinion of our tax advisor and could be subject to significant income tax liabilities.

The spin-off may expose us to potential liabilities arising out of state and federal fraudulent conveyance laws and legal dividend requirements that we did not assume in our agreements with WPX.

The spin-off is subject to review under various state and federal fraudulent conveyance laws. A court could deem the spin-off or certain internal restructuring transactions undertaken by us in connection with the separation to be a fraudulent conveyance or transfer. Fraudulent conveyances or transfers are defined to include transfers made or obligations incurred with the actual intent to hinder, delay, or defraud current or future creditors or transfers made or obligations incurred for less than reasonably equivalent value when the debtor was insolvent, or that rendered the debtor

37

insolvent, inadequately capitalized or unable to pay its debts as they become due. A court could void the transactions or impose substantial liabilities upon us, which could adversely affect our financial condition and our results of operations. Whether a transaction is a fraudulent conveyance or transfer will vary depending upon the jurisdiction whose law is being applied. Under the separation and distribution agreement between us and WPX, from and after the spin-off, each of WPX and we are responsible for the debts, liabilities, and other obligations related to the business or businesses which each owns and operates. Although we do not expect to be liable for any such obligations not expressly assumed by us pursuant to the separation and distribution agreement, it is possible that a court would disregard the allocation agreed to between the parties, and require that we assume responsibility for obligations allocated to WPX, particularly if WPX were to refuse or were unable to pay or perform the subject allocated obligations.

Increases in interest rates could adversely impact our share price, our ability to issue equity or incur debt for acquisitions or other purposes, and our ability to make cash dividends at our intended levels.

Interest rates may increase further in the future. As a result, interest rates on future credit facilities and debt offerings could be higher than current levels, causing our financing costs to increase accordingly. As with other yield-oriented securities, our share price will be impacted by the level of our dividends and implied dividend yield. The distribution yield is often used by investors to compare and rank yield-oriented securities for investment decision-making purposes. Therefore, changes in interest rates, either positive or negative, may affect the yield requirements of investors who invest in our shares, and a rising interest rate environment could have an adverse impact on our share price and our ability to issue equity or incur debt for acquisitions or other purposes and to pay cash dividends at our intended levels.

Item 1B. Unresolved Staff Comments

Not applicable.

Item 2. Properties

Please read “Business” for a description of the location and general character of our principal physical properties. We generally own our facilities, although a substantial portion of our pipeline and gathering facilities is constructed and maintained pursuant to rights-of-way, easements, permits, licenses, or consents on and across properties owned by others.

Item 3. Legal Proceedings

Environmental

Certain reportable legal proceedings involving governmental authorities under federal, state, and local laws regulating the discharge of materials into the environment are described below. While it is not possible for us to predict the final outcome of the proceedings which are still pending, we do not anticipate a material effect on our consolidated financial position if we receive an unfavorable outcome in any one or more of such proceedings.

On January 21, 2016, we received a Compliance Order from the Pennsylvania Department of Environmental Protection requiring the correction of several alleged deficiencies arising out of the construction of the Springville Gathering Line, the Pennsylvania Mainline Gathering Line, and the 2008 Core Zone Gathering Line. The original Order identified civil penalties in the amount of approximately $712,000. On December 28, 2016, we entered into an Order with the Pennsylvania Department of Environmental Protection to address the issues and paid the associated penalty of $581,477.

On February 21, 2017, we received notice from the Environmental Enforcement Section of the United States Department of Justice regarding certain alleged violations of the Clean Air Act at our Moundsville facility as set forth in a Notice of Noncompliance issued by the EPA on January 14, 2016. The notice includes an offer to avoid further legal action on the alleged violations by paying $2,000,000.  We are currently evaluating the communication and our response.

38

Other

The additional information called for by this item is provided in Note 18 – Contingent Liabilities and Commitments of Notes to Consolidated Financial Statements included under Part II, Item 8 Financial Statements of this report, which information is incorporated by reference into this item.

Item 4. Mine Safety Disclosures

Not applicable.

39

Executive Officers of the Registrant

The name, age, period of service, and title of each of our executive officers as of February 22, 2017, are listed below. As previously discussed, Williams Partners L.P. merged with ACMP in February 2015 (the ACMP Merger). ACMP was the surviving entity in the ACMP Merger and changed its name to Williams Partners L.P. References in the biographical information below to (a) “Pre-merger WPZ” will mean Williams Partners L.P. prior to the ACMP Merger and (b) “ACMP/WPZ” will refer to both ACMP prior to and after the ACMP Merger, when it changed its name to Williams Partners L.P.

Alan S. Armstrong	Director, Chief Executive Officer, and President
	Age: 54
	Position held since 2011.
	From 2002 to 2011, Mr. Armstrong served as Senior Vice President - Midstream and acted as President of our midstream business. From 1999 to 2002, Mr. Armstrong was Vice President, Gathering and Processing in our midstream business and from 1998 to 1999 was Vice President, Commercial Development. Mr.  Armstrong has served as a director of the general partner of ACMP/WPZ since 2012, as Chief Executive Officer since December 31, 2014, and as Chairman of the Board since February 2, 2015. Mr. Armstrong has served as a director of BOK Financial Corporation, a financial services company, since 2013. Mr. Armstrong also served as Chairman of the Board and Chief Executive Officer of the general partner of Pre-merger WPZ from 2011 until the ACMP Merger, as Senior Vice President - Midstream from 2010 to 2011, and director and Chief Operating Officer from 2005 to 2010.

Walter J. Bennett	Senior Vice President — West
	Age: 47
	Position held since January 2015.
	Mr. Bennett was formerly Chief Operating Officer of Chesapeake Midstream Development and served as Senior Vice President-Operations at Boardwalk Pipeline Partners. Previously, Mr. Bennett served in a variety of senior positions at Gulf South Pipeline Company that included operations and commercial responsibilities. Mr. Bennett began his career at a subsidiary of Koch Industries. Mr. Bennett has served as Senior Vice President - West of the general partner of ACMP/WPZ since December 2013 and served as Senior Vice President - West of the general partner of Pre-merger WPZ from January 2015 until the ACMP Merger. He has served as a director of the general partner of ACMP/WPZ since February 2017.

40

Francis (Frank) E. Billings	Senior Vice President — Corporate Strategic Development
	Age: 54
	Position held since January 2014.
	Mr. Billings served as Senior Vice President - Northeast G&P of us and Pre-merger WPZ from January 2013 to January 2014. Mr. Billings served as Vice President of our midstream gathering and processing business from 2011 until 2013 and as Vice President, Business Development from 2010 to 2011. Mr. Billings served as President of Cumberland Plateau Pipeline Company, a privately held company developing an ethane pipeline to serve the Marcellus Shale area, from 2009 until 2010. From 2008 to 2009, Mr. Billings served as Senior Vice President of Commercial for Crosstex Energy, Inc. and Crosstex Energy L.P., an independent midstream energy services master limited partnership and its parent corporation. In 1988, Mr. Billings joined MAPCO Inc., which merged with one of our subsidiaries in 1998, serving in various management roles, including in 2008 as a Vice President in the midstream business. Mr. Billings served as Senior Vice President - Corporate Strategic Development of the general partner of Pre-merger WPZ from January 2014 until the ACMP Merger. He has served as Senior Vice President - Corporate Strategic Development since the ACMP Merger, and as a director of the general partner of ACMP/WPZ since the ACMP Merger until February 2017.

Donald R. Chappel	Senior Vice President and Chief Financial Officer
	Age: 65
	Position held since 2003.
	Prior to joining us, Mr. Chappel held various financial, administrative and operational leadership positions. Mr. Chappel has served as a director of the general partner of ACMP/WPZ since 2012 and as Chief Financial Officer of the general partner of ACMP/WPZ since December 31, 2014. Mr. Chappel has also served as a member of the Management Committee of Northwest Pipeline since 2007. Mr. Chappel served as Chief Financial Officer and a director of the general partner of Pre-merger WPZ from 2005 until the ACMP Merger. Mr. Chappel was Chief Financial Officer from 2007 and a director from 2008 of the general partner of Williams Pipeline Partners L.P. (WMZ), until its merger with Pre-merger WPZ in 2010. Mr. Chappel is a director of SUPERVALU, Inc. (a grocery and pharmacy company).

John R. Dearborn	Senior Vice President — NGL & Petchem Services
	Age: 59
	Position held since 2013.
	Mr. Dearborn served as a senior leader for Saudi Basic Industries Corporation, a petrochemical company, from 2011 to 2013. From 2001 to 2011, Mr. Dearborn served in a variety of leadership positions with the Dow Chemical Company. Mr. Dearborn also worked for Union Carbide Corporation, prior to its merger with DOW, from 1981 to 2001 where he served in several leadership roles. Mr. Dearborn also served as Senior Vice President - NGL & Petchem Services of the general partner of Pre-merger WPZ from 2013 until the ACMP Merger and has served in that role for the general partner of ACMP/WPZ since the ACMP Merger.

41

Robyn L. Ewing	Senior Vice President and Chief Administrative Officer
	Age: 61
	Position held since 2008.
	From 2004 to 2008, Ms. Ewing was Vice President of Human Resources. Prior to joining Williams, Ms. Ewing worked at MAPCO, which merged with Williams in 1998. Ms. Ewing began her career with Cities Service Company in 1976.

Rory L. Miller	Senior Vice President — Atlantic - Gulf
	Age: 56
	Position held since 2013.
	From 2011 until 2013, Mr. Miller was Senior Vice President - Midstream of Williams and the general partner of Pre-merger WPZ, acting as President of Williams’ midstream business. Mr. Miller was a Vice President of Williams’ midstream business from 2004 until 2011. Mr. Miller served as a director and Senior Vice-President - Atlantic-Gulf of the general partner of Pre-merger WPZ from 2011 until the ACMP Merger and has served in those roles for the general partner of ACMP/WPZ since the ACMP Merger. Mr. Miller has also served as a member of the Management Committee of Transco, since 2013.

Sarah C. Miller	Senior Vice President and General Counsel
	Age: 45
	Position held since 2015.
	Ms. Miller joined Williams in 2000, where she has served in a variety of legal leadership positions, including Vice President, Corporate Secretary and Assistant General Counsel for the company’s corporate secretary team, Senior Counsel for the company’s midstream business, and as Senior Attorney for the legal department’s business development team. She was named Senior Vice President and General Counsel on June 20, 2015. Prior to joining Williams, Ms. Miller was a litigation associate at Crowe & Dunlevy.

James E. Scheel	Senior Vice President — Northeast G&P
	Age: 52
	Position held since January 2014.
	From 2012 to 2014, Mr. Scheel served as Senior Vice President - Corporate Strategic Development of us and the general partner of Pre-merger WPZ. From 2011 until 2012, Mr. Scheel served as Vice President of Business Development for our midstream business. Mr. Scheel joined Williams in 1988 and has served in leadership roles in business strategic development, engineering and operations, our NGL business, and international operations. Mr. Scheel has served as a director and Senior Vice President - Northeast G&P of the general partner of ACMP/WPZ since the ACMP Merger, having previously served as a director of the general partner of ACMP/WPZ from 2012 to February 2014. Mr. Scheel served as a director of the general partner of Pre-merger WPZ from 2012 until the ACMP Merger.

42

John D. Seldenrust	Senior Vice President — Engineering Services
	Age: 52
	Position held since July 2015.
	Mr. Seldenrust served as Senior Vice President - Eastern Operations for us from January 2015 to July 2015, and for ACMP/WPZ from 2013 to July 2015. Mr. Seldenrust also previously served in a variety of operations and engineering leadership roles at ACMP and Chesapeake Energy from 2004 to August 2013. Prior to joining Chesapeake, Mr. Seldenrust held reservoir, production and facilities engineering positions with ARCO Oil & Gas, Vastar Resources and BP America.

Ted T. Timmermans	Vice President, Controller, and Chief Accounting Officer
	Age: 60
	Position held since 2005.
	Mr. Timmermans served as Assistant Controller of Williams from 1998 to 2005. Mr. Timmermans served as Vice President, Controller & Chief Accounting Officer of the general partner of Pre-merger WPZ until the ACMP Merger and has served in those roles for the general partner of ACMP/WPZ since the ACMP Merger. Mr. Timmermans served as Chief Accounting Officer of the general partner of WMZ from 2008 until its merger with Pre-merger WPZ in 2010.

43

PART II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

Our common stock is listed on the New York Stock Exchange under the symbol “WMB.” At the close of business on February 17, 2017, we had approximately 7,376holders of record of our common stock. The high and low sales price ranges (New York Stock Exchange composite transactions) and dividends declared by quarter for each of the past two years are as follows:

	High		Low		Dividend
2016
First Quarter	$	26.68	$	10.22	$	0.64
Second Quarter	23.89		14.60		0.64
Third Quarter	31.43		19.68		0.20
Fourth Quarter	32.21		27.35		0.20
2015
First Quarter	$	51.15	$	40.07	$	0.58
Second Quarter	61.38		46.28		0.59
Third Quarter	58.77		34.64		0.64
Fourth Quarter	44.51		20.95		0.64

Some of our subsidiaries’ borrowing arrangements may limit the transfer of funds to us. These terms have not impeded, nor are they expected to impede, our ability to pay dividends. On February 20, 2017, our board of directors approved a regular quarterly dividend of $0.30 per share payable on March 27, 2017, representing a 50 percent increase from our previous quarterly dividend.

Performance Graph

Set forth below is a line graph comparing our cumulative total stockholder return on our common stock (assuming reinvestment of dividends) with the cumulative total return of the S&P 500 Stock Index and the Bloomberg Americas Pipelines Index for the period of five fiscal years commencing January 1, 2012. The Bloomberg Americas Pipelines Index is composed of Enbridge, Inc., Inter Pipeline Ltd., Kinder Morgan, Inc., ONEOK, Inc., Pembina Pipeline Corp, Plains GP Holdings LP, Spectra Energy Corp, TransCanada Corp., Keyera Corp., AltaGas Ltd., and Williams. The graph below assumes an investment of $100 at the beginning of the period.

	2011	2012	2013	2014	2015	2016
The Williams Companies, Inc.	100.0	126.1	154.5	187.4	114.2	150.0
S&P 500 Index	100.0	115.9	153.4	174.3	176.8	197.8
Bloomberg Americas Pipelines Index	100.0	113.4	125.9	147.3	81.5	119.2

44

Item 6. Selected Financial Data

The following financial data at December 31, 2016 and 2015, and for each of the three years in the period ended December 31, 2016, should be read in conjunction with the other financial information included in Part II, Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations and Part II, Item 8, FinancialStatements and Supplementary Data of this Form 10-K. All other financial data has been prepared from our accounting records.

	2016			2015			2014		2013		2012
	(Millions, except per-share amounts)
Revenues (1)	$	7,499		$	7,360		$	7,637	$	6,860	$	7,486
Income (loss) from continuing operations (2)	(350		)	(1,314		)	2,335		679		929
Amounts attributable to The Williams Companies, Inc.:
Income (loss) from continuing operations (2)	(424		)	(571		)	2,110		441		723
Diluted earnings (loss) per common share:
Income (loss) from continuing operations (2)	(.57		)	(.76		)	2.91		.64		1.15
Total assets at December 31 (3)	46,835			49,020			50,455		27,065		24,248
Commercial paper and long-term debt due within one year at December 31 (4)	878			675			802		226		1
Long-term debt at December 31 (3)	22,624			23,812			20,780		11,276		10,656
Stockholders’ equity at December 31 (3)	4,643			6,148			8,777		4,864		4,752
Cash dividends declared per common share	1.680			2.450			1.9575		1.438		1.196

_________

(1) Revenues for 2014 increased reflecting the consolidation of ACMP beginning in third quarter and new Canadian construction management services.

(2) Income (loss) from continuing operations:

• For 2016 includes an $873 million impairment of certain assets and a $430 million impairment of certain equity-method investments;

• For 2015 includes a $1.4 billion impairment of certain equity-method investments and a $1.1 billion impairment of goodwill;

• For 2014 includes $2.5 billion pretax gain recognized as a result of remeasuring to fair value the equity-method investment we held before we acquired a controlling interest in ACMP, $246 million of insurance recoveries related to the 2013 Geismar Incident, and $154 million of cash received related to a contingency settlement. 2014 also includes $78 million of pretax equity losses from Bluegrass Pipeline and Moss Lake related primarily to the underlying write-off of previously capitalized project development costs and $76 million of pretax acquisition, merger, and transition expenses related to our acquisition of ACMP;

• For 2013 includes $99 million of deferred income tax expense incurred on undistributed earnings of our foreign operations that are no longer considered permanently reinvested.

(3) The increases in 2014 reflect assets acquired and debt assumed primarily related to our acquisition of ACMP (see Note 2 – Acquisitions) in third quarter as well as $1.9 billion of related debt issuances and $2.8 billion of debt issuances at WPZ. Additionally, we issued $3.4 billion of equity (see Note 15 – Stockholders' Equity).

(4) The increases in 2014 and 2013 reflect borrowings under WPZ’s commercial paper program, which was initiated in 2013.

45

Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

General

We are an energy infrastructure company focused on connecting North America’s significant hydrocarbon resource plays to growing markets for natural gas, NGLs, and olefins. Our operations are located principally in the United States and are organized into the Williams Partners and Williams NGL & Petchem Services reportable segments. All remaining business activities are included in Other.

Williams Partners

Williams Partners consists of our consolidated master limited partnership, WPZ, which includes gas pipeline and midstream businesses. The gas pipeline businesses include interstate natural gas pipelines and pipeline joint project investments; and the midstream businesses provide natural gas gathering, treating, and processing services; NGL production, fractionation, storage, marketing and transportation; deepwater production handling and crude oil transportation services; an olefin production business, and is comprised of several wholly owned and partially owned subsidiaries and joint project investments. As of December 31, 2016, we owned approximately 60 percent of the interests in WPZ, including the interests of the general partner, which were wholly owned by us, and IDRs.

Williams Partners’ gas pipeline businesses consist primarily of Transco and Northwest Pipeline. The gas pipeline business also holds interests in joint venture interstate and intrastate natural gas pipeline systems including a 50 percent equity-method investment in Gulfstream and a 41 percent interest in Constitution (a consolidated entity), which is under development. As of December 31, 2016, Transco and Northwest Pipeline own and operate a combined total of approximately 13,600 miles of pipelines with a total annual throughput of approximately 4,230 Tbtu of natural gas and peak-day delivery capacity of approximately 15.5 MMdth of natural gas.

Williams Partners' midstream businesses primarily consist of (1) natural gas gathering, treating, compression, and processing; (2) NGL fractionation, storage and transportation; (3) crude oil production handling and transportation; and (4) olefins production. (See Geismar Olefins Facility Monetization below.) The primary service areas are concentrated in major producing basins in Colorado, Texas, Oklahoma, Kansas, New Mexico, Wyoming, the Gulf of Mexico, Louisiana, Pennsylvania, West Virginia, New York, and Ohio which include the Barnett, Eagle Ford, Haynesville, Marcellus, Niobrara, and Utica Shale plays as well as the Mid-Continent region.

The midstream businesses include equity-method investments in natural gas gathering and processing assets and NGL fractionation and transportation assets, including a 62 percent equity-method investment in UEOM, a 50 percent equity-method investment in the Delaware basin gas gathering system (DBJV) in the Mid-Continent region, a 69 percent equity-method investment in Laurel Mountain, a 58 percent equity-method investment in Caiman II, a 60 percent equity-method investment in Discovery, a 50 percent equity-method investment in OPPL, and Appalachia Midstream Services, LLC, which owns an approximate average 41 percent equity-method investment interest in multiple gas gathering systems in the Marcellus Shale (Appalachia Midstream Investments).

The midstream businesses previously included our Canadian midstream operations, which were comprised of an oil sands offgas processing plant near Fort McMurray, Alberta and an NGL/olefin fractionation facility at Redwater, Alberta. In September 2016, these Canadian operations were sold. (See Note 3 – Divestiture of Notes to Consolidated Financial Statements.)

Williams Partners’ ongoing strategy is to safely and reliably operate large-scale, interstate natural gas transmission and midstream infrastructures where our assets can be fully utilized and drive low per-unit costs. We focus on consistently attracting new business by providing highly reliable service to our customers and investing in growing markets, including the deepwater Gulf of Mexico, the Marcellus Shale, the Gulf Coast Region, and areas of increasing natural gas demand.

Williams Partners’ interstate transmission and related storage activities are subject to regulation by the FERC and as such, our rates and charges for the transportation of natural gas in interstate commerce, and the extension, expansion

46

or abandonment of jurisdictional facilities and accounting, among other things, are subject to regulation. The rates are established through the FERC’s ratemaking process. Changes in commodity prices and volumes transported have limited near-term impact on these revenues because the majority of cost of service is recovered through firm capacity reservation charges in transportation rates.

Williams NGL & Petchem Services

Williams NGL & Petchem Services includes certain domestic olefins pipeline assets as well as the previously owned Canadian assets which included a liquids extraction plant near Fort McMurray, Alberta, that began operations in March 2016 and a propane dehydrogenation facility under development in Canada. In September 2016, these Canadian operations were sold. (See Note 3 – Divestiture of Notes to Consolidated Financial Statements.)

Unless indicated otherwise, the following discussion and analysis of results of operations and financial condition and liquidity relates to our current continuing operations and should be read in conjunction with the consolidated financial statements and notes thereto included in Part II, Item 8 of this report.

Dividends

In December 2016, we paid a regular quarterly dividend of $0.20 per share. On February 20, 2017, our board of directors approved a regular quarterly dividend of $0.30 per share payable on March 27, 2017, representing a 50 percent increase from our previous quarterly dividend.

Overview

Net income (loss) attributable to The Williams Companies, Inc., for the year ended December 31, 2016, increased $147 millioncompared to the year ended December 31, 2015, reflecting the absence of certain goodwill impairments, lower impairments of equity-method investments, an increase in olefins margins associated with our Geismar plant, decreases in operating and maintenance expenses, and higher equity earnings. These favorable changes were partially offset by an unfavorable change in net income attributable to noncontrolling interests driven primarily by higher WPZ income as well as the impact of reduced incentive distributions from WPZ associated with the termination of the WPZ Merger Agreement. The favorable changes were also partially offset by increased impairment charges and loss on sale associated with our Canadian operations, lower insurance recoveries, as well as higher interest incurred. See additional discussion in Results of Operations.

Acquisition of Additional Interests in Appalachia Midstream Investments

In February, 2017, we announced agreements to acquire additional interests in two Marcellus Shale gathering systems within Williams Partners’ Appalachia Midstream Investments in exchange for equity-method investment interests in DBJV and the Ranch Westex gas processing plant, both currently reported within the Williams Partners segment. We also expect to receive a total of $200 million in cash as part of the agreements subject to customary closing conditions and purchase price adjustments. The transactions are expected to close in late first-quarter or early second-quarter 2017.

Financial Repositioning

In January 2017, we announced agreements with WPZ, wherein we permanently waived the general partner’s incentive distribution rights and converted our 2 percent general partner interest in WPZ to a non-economic interest in exchange for 289 million newly issued WPZ common units. Pursuant to this agreement, we also purchased approximately 277 thousand WPZ common units for $10 million. Additionally, we purchased approximately 59 million common units of WPZ at a price of $36.08586 per unit in a private placement transaction, funded with proceeds from our equity offering (see Note 15 - Stockholders’ Equity of Notes to Consolidated Financial Statements). Following these transactions, we own a 74 percent limited partner interest in WPZ. It is anticipated that the combination of these measures will improve WPZ’s cost of capital, provide for debt reduction, and eliminate WPZ’s need to access the public equity markets for several years.

In addition to the previously announced Geismar monetization process, we have announced plans to monetize other select assets that are not core to our strategy. We expect to raise more than $2 billion in after-tax proceeds from

47

the monetization process of Geismar and the other select assets. As we pursue these other asset monetizations, it is possible that we may incur impairments of certain equity-method investments, property, plant, and equipment, and intangible assets. Such impairments could potentially be caused by indications of fair value implied through the monetization process or, in the case of asset dispositions that are part of a broader asset group, the impact of the loss of future estimated cash flows.

Energy Transfer Merger Agreement

On September 28, 2015, we publicly announced in a press release that we had entered into a Merger Agreement with Energy Transfer and certain of its affiliates. The Merger Agreement provided that, subject to the satisfaction of customary closing conditions, we would merge with and into the newly formed ETC, with ETC surviving the ETC Merger.

On June 29, 2016, Energy Transfer provided us written notice terminating the Merger Agreement, citing the alleged failure of certain conditions under the Merger Agreement.

Termination of WPZ Merger Agreement

On May 12, 2015, we entered into an agreement for a unit-for-stock transaction whereby we would have acquired all of the publicly held outstanding common units of WPZ in exchange for shares of our common stock (WPZ Merger Agreement).

On September 28, 2015, prior to our entry into the Merger Agreement, we entered into a Termination Agreement and Release (Termination Agreement), terminating the WPZ Merger Agreement. Under the terms of the Termination Agreement, we were required to pay a $428 million termination fee to WPZ, at which time we owned approximately 60 percent, including the interests of the general partner and IDRs. Such termination fee settled through a reduction of quarterly incentive distributions we were entitled to receive from WPZ (such reduction not to exceed $209 million per quarter). The distributions from WPZ in November 2015, February 2016, and May 2016 were reduced by $209 million, $209 million, and $10 million, respectively, related to this termination fee.

Organizational Realignment

In September 2016, we announced organizational changes aiming to simplify our structure, increase direct operational alignment to advance our natural gas-focused strategy, and drive continued focus on customer service and execution. Effective January 1, 2017, we implemented these changes, which combined the management of certain of our operations and reduced the overall number of operating areas managed within our business.

Information in this report has generally been prepared to be consistent with the reportable segment presentation in our consolidated financial statement in Part II, Item 8 of this document. These segments are discussed in further detail in the following sections.

Williams Partners

Northwest Pipeline rate case

On January 23, 2017, Northwest Pipeline filed a Stipulation and Settlement Agreement with the FERC for new rates.  The new rates become effective January 1, 2018, and are not expected to materially affect our trend of earnings.  Pursuant to this agreement, Northwest Pipeline can file for new rates to be effective after October 1, 2018, and must file a general rate case for new rates to become effective no later than January 1, 2023.

Geismar olefins facility monetization

In September 2016, Williams Partners announced the initiation of an ongoing process to explore monetization of its ownership interest in the Geismar, Louisiana, olefins plant and complex, consistent with our strategy to narrow our focus and allocate capital to our natural gas–focused business.

48

Sale of Canadian operations

In September 2016, we completed the sale of our Canadian operations for total consideration of $1.02 billion. We recognized an impairment charge of $747 million during the second quarter of 2016 related to these operations and an additional loss of $66 million upon completion of the sale. (See Note 3 – Divestiture.)

Barnett Shale and Mid-Continent contract restructurings

In August 2016, Williams Partners conditionally committed to execute a new gas gathering agreement in the Barnett Shale. The agreement was executed in the fourth quarter of 2016, in conjunction with our existing customer, Chesapeake Energy Corporation, closing the sale of its Barnett Shale properties to another producer. That other producer, which has an investment grade credit rating, is now our customer under the new gas gathering agreement. The restructured agreement provided a $754 million up-front cash payment to us primarily in exchange for eliminating future minimum volume commitments. The restructured agreement also provides for revised gathering rates. Based on current commodity price assumptions at the time of the agreement, we generally expect the up-front cash proceeds and the ongoing cash flows generated by gathering services, to represent equivalent net present value of cash flows as compared to expected performance under the existing agreement. Additionally, Williams Partners agreed to a revised contract in the Mid-Continent region, also with Chesapeake Energy Corporation. The revised contract was executed in the third quarter of 2016 and provided an up-front cash payment to us of $66 million primarily in exchange for changing from a cost of service contract to fixed-fee terms. The majority of the up-front cash proceeds from both agreements were recognized as deferred revenue and will be amortized into income in future periods. In the near term, we do not expect that our trend of reported results will be significantly impacted by the effect of the discount associated with the up-front cash proceeds relative to the original minimum volume commitments and reduced gathering rates. It was anticipated that both agreements would reduce customer concentration risk and provide support to realize additional drilling and improved volumes in these regions.

Powder River basin contract restructuring

In October 2016, in conjunction with our partner in the Bucking Horse natural gas processing plant and Jackalope Gas Gathering System, we announced an agreement with Chesapeake Energy Corporation to restructure gathering and processing contracts in the Powder River basin. The restructured contracts became effective in January 2017 and replaced the previous cost-of-service arrangement with MVCs in the near-term such that we do not expect that our near-term trend of reported results will be significantly impacted by the restructured terms.

Rock Springs expansion

In August 2016, the Rock Springs expansion was placed into service. The project expanded Transco’s existing natural gas transmission system from New Jersey to a generation facility in Maryland and increased capacity by 192 Mdth/d.

Gulf Trace expansion

In February 2017, the Gulf Trace expansion was placed into service. The project expanded Transco’s existing natural gas transmission system together with greenfield facilities to provide incremental firm transportation capacity from Station 65 in St. Helena Parish, Louisiana to a new interconnection with Sabine Pass Liquefaction in Cameron Parish, Louisiana. It is expected to increase capacity by 1,200 Mdth/d.

Redwater expansion

In March 2016, we completed the expansion of our Redwater facilities in support of a long-term agreement to provide gas processing services to a second bitumen upgrader in Canada’s oil sands near Fort McMurray, Alberta. The expanded Redwater facility receives NGL/olefins mixtures from the second bitumen upgrader and fractionates the mixtures into an ethane/ethylene mix, propane, polymer grade propylene, normal butane, an alkylation feed and condensate. We sold these operations in September 2016. (See Note 3 – Divestiture of Notes to Consolidated Financial Statements.)

49

Williams NGL & Petchem Services

Horizon liquids extraction plant

In March 2016, we completed a new liquids extraction plant near Fort McMurray, Alberta. The Boreal pipeline was extended to enable transportation of the NGL/olefins mixture from the new liquids extraction plant to Williams Partners’ expanded Redwater facilities. The plant increased the amount of NGLs produced in Canada to a total of approximately 40 Mbbls/d. To mitigate ethane price risk associated with our processing services, we had a long-term agreement with a minimum price for ethane sales to a third-party customer. We sold these operations in September 2016. (See Note 3 – Divestiture of Notes to Consolidated Financial Statements.)

Commodity Prices

NGL per-unit margins were approximately 7 percent lower in 2016 compared to the same period of 2015. Following a sharp decline in late 2014 to early 2015, total NGL margins have remained somewhat consistent in 2015 and 2016. While 2014 and 2015 reflect limited ethane recoveries, we have seen an increase in ethane production during 2016.

NGL margins are defined as NGL revenues less any applicable Btu replacement cost, plant fuel, and third-party transportation and fractionation. Per-unit NGL margins are calculated based on sales of our own equity volumes at the processing plants. Our equity volumes include NGLs where we own the rights to the value from NGLs recovered at our plants under both “keep-whole” processing agreements, where we have the obligation to replace the lost heating value with natural gas, and “percent-of-liquids” agreements whereby we receive a portion of the extracted liquids with no obligation to replace the lost heating value.

The following graph illustrates the NGL production and sales volumes, as well as the margin differential between ethane and non-ethane products and the relative mix of those products.

The potential impact of commodity prices on our business is further discussed in the following Company Outlook.

50

Company Outlook

Our strategy is to provide large-scale energy infrastructure designed to maximize the opportunities created by the vast supply of natural gas and natural gas products that exists in the United States. We accomplish this by connecting the growing demand for cleaner fuels and feedstocks with our major positions in the premier natural gas and natural gas products supply basins. We continue to maintain a strong commitment to safety, environmental stewardship, operational excellence, and customer satisfaction. We believe that accomplishing these goals will position us to deliver safe and reliable service to our customers and an attractive return to our shareholders.

Our business plan for 2017 includes the previously announced agreement with WPZ to permanently waive our incentive distribution rights in exchange for WPZ common units as well as our private purchase of $2.1 billion newly issued WPZ commits units. We expect to increase our dividend to $0.30 per share, or $1.20 annually, beginning in the first quarter of 2017. Our business plan also includes previously discussed asset monetizations, which include our ownership interest in the Geismar olefins facility as well as other select assets that are not core to our strategy. The monetizations are expected to yield after-tax proceeds of greater than $2.0 billion. For WPZ, these transactions are expected to improve its cost of capital, remove its need to access the public equity markets for the next several years, enhance growth, and provide for debt reduction, solidifying WPZ as an attractive financing vehicle. The transactions are also expected to facilitate a reduction of our parent-level debt and provides for dividend growth flexibility, while retaining strategic and financing flexibility.

Our growth capital and investment expenditures in 2017 are expected to total $2.1 billion to $2.8 billion. Approximately $1.4 billion to $1.9 billion of our growth capital funding needs include Transco expansions and other interstate pipeline growth projects, most of which are fully contracted with firm transportation agreements. The remaining growth capital spending in 2017 primarily reflects investment in gathering and processing systems in the Northeast region limited primarily to known new producer volumes, including volumes that support Transco expansion projects including our Atlantic Sunrise project. In addition to growth capital and investment expenditures, we also remain committed to projects that maintain our assets for safe and reliable operations, as well as projects that meet legal, regulatory, and/or contractual commitments.

As a result of our significant continued capital and investment expenditures on Transco expansions and fee-based gathering and processing projects, as well as the previously discussed sale of our Canadian operations and the planned monetization of the Geismar olefins facility, fee-based businesses are becoming an even more significant component of our portfolio and serve to reduce the influence of commodity price fluctuations on our operating results and cash flows. We expect to benefit as continued growth in demand for low-cost natural gas is driven by increases in LNG exports, industrial demand and power generation. Current forward market prices indicate a slightly more favorable energy commodity price environment in 2017 as compared to 2016, including higher natural gas and NGL prices. However, some of our customers may continue to curtail or delay drilling plans until there is a more sustained recovery in prices, which may negatively impact our gathering volumes. Although there has been some improvement, the credit profiles of certain of our producer customers remain challenged. Unfavorable changes in energy commodity prices or the credit profile of our producer customers may also result in noncash impairments of our assets.

In 2017, our operating results will include increases from our fee-based businesses recently placed in service or expected to be placed in service in 2017 primarily along the Transco system, a full year benefit of expanded capacity on our Gulfstar FPS™, and lower general and administrative expenses due to cost reduction initiatives and asset monetizations. We expect overall gathering and processing volumes to remain steady in 2017 and increase thereafter to meet the growing demand for natural gas and natural gas products.

Potential risks and obstacles that could impact the execution of our plan include:

• Opposition to infrastructure projects, including the risk of delay in permits needed for our projects;

• Unexpected significant increases in capital expenditures or delays in capital project execution;

• Counterparty credit and performance risk, including that of Chesapeake Energy Corporation and its affiliates;

51

• Inability to execute or delay in completing planned asset monetizations;

• Lower than anticipated demand for natural gas and natural gas products which could result in lower than expected volumes, energy commodity prices and margins;

• General economic, financial markets, or further industry downturn, including increased interest rates;

• Physical damages to facilities, including damage to offshore facilities by named windstorms;

• Reduced availability of insurance coverage;

• Lower than expected distributions from WPZ.

We seek to maintain a strong financial position and liquidity, as well as manage a diversified portfolio of energy infrastructure assets which continue to serve key growth markets and supply basins in the United States.

Expansion Projects

Our ongoing major expansion projects include the following:

Williams Partners

Eagle Ford

We plan to expand our gathering infrastructure in the Eagle Ford region in order to meet our customers’ production plans. The expansion of the gathering infrastructure includes the addition of new facilities, well connections, and gathering pipeline to the existing systems.

Oak Grove Expansion

We plan to expand our processing capacity at our Oak Grove facility by adding a second 200 MMcf/d cryogenic natural gas processing plant, which, based on our customers’ needs, is expected to be placed into service in 2020.

Gathering System Expansion

We will continue to expand the gathering systems in the Marcellus and Utica Shale regions that are needed to meet our customers’ production plans. The expansion of the gathering infrastructure includes additional compression and gathering pipeline to the existing system.

Constitution Pipeline

In December 2014, we received approval from the FERC to construct and operate the jointly owned Constitution pipeline, which will have an expected capacity of 650 Mdth/d. However, in April 2016, the New York State Department of Environmental Conservation (NYSDEC) denied a necessary water quality certification for the New York portion of the pipeline. We remain steadfastly committed to the project, and in May 2016, Constitution appealed the NYSDEC’s denial of the certification and filed an action in federal court seeking a declaration that the State of New York’s authority to exercise permitting jurisdiction over certain other environmental matters is preempted by federal law. (See Note 4 – Variable Interest Entities of Notes to Consolidated Financial Statements.) We currently own 41 percent of Constitution with three other parties holding 25 percent, 24 percent, and 10 percent, respectively. We will be the operator of Constitution. The 126-mile Constitution pipeline will connect our gathering system in Susquehanna County, Pennsylvania, to the Iroquois Gas Transmission and Tennessee Gas Pipeline systems in New York, as well as to a local distribution company serving New York and Pennsylvania. In light of the NYSDEC’s denial of the water quality certification and the actions taken to challenge the decision, the target in-service date has been revised to as early as the second half of 2018, which assumes that the legal challenge process is satisfactorily and promptly concluded.

52

Garden State

In April 2016, we received approval from the FERC to expand Transco’s existing natural gas transmission system to provide incremental firm transportation capacity from Station 210 in New Jersey to a new interconnection on our Trenton Woodbury Lateral in New Jersey. The project will be constructed in phases and is expected to increase capacity by 180 Mdth/d. We plan to place the initial phase of the project into service during the third quarter of 2017 and the remaining portion in the second quarter of 2018, assuming timely receipt of all necessary regulatory approvals.

Norphlet Project

In March 2016, we announced that we have reached an agreement to provide deepwater gas gathering services to the Appomattox development in the Gulf of Mexico. The project will provide offshore gas gathering services to our existing Transco lateral, which will provide transmission services onshore to our Mobile Bay processing facility. We also plan to make modifications to our Main Pass 261 Platform to install an alternate delivery route from the platform, as well as modifications to our Mobile Bay processing facility. The project is scheduled to go into service during the second quarter of 2020.

Hillabee

In February 2016, the FERC issued a certificate order for the initial phases of Transco’s Hillabee Expansion Project. The project involves an expansion of Transco’s existing natural gas transmission system from Station 85 in west central Alabama to a proposed new interconnection with the Sabal Trail project in Alabama. The project will be constructed in phases, and all of the project expansion capacity will be leased to Sabal Trail. We plan to place the initial phase of the project into service concurrent with the in-service date of the Sabal Trail project, which is planned to occur as early as the second quarter of 2017. The in-service date of the second phase of the project is planned for the second quarter of 2020 and together they are expected to increase capacity by 1,025 Mdth/d.

In March 2016, WPZ entered into an agreement with the member-sponsors of Sabal Trail to resolve several matters. In accordance with the agreement, the member-sponsors will pay us an aggregate amount of $240 million in three equal installments as certain milestones of the project are met. The first $80 million payment was received in March 2016 and the second installment was received in September 2016. WPZ expects to recognize income associated with these receipts over the term of the capacity lease agreement.

New York Bay Expansion

In July 2016, we received approval from the FERC to expand Transco’s existing natural gas transmission system to provide incremental firm transportation capacity from Pennsylvania to the Rockaway Delivery Lateral transfer point and the Narrows meter station in Richmond County, New York. We plan to place the project into service during the fourth quarter of 2017, and it is expected to increase capacity by 115 Mdth/d.

Atlantic Sunrise

In February 2017, we received approval from the FERC to expand Transco’s existing natural gas transmission system along with greenfield facilities to provide incremental firm transportation capacity from the northeastern Marcellus producing area to markets along Transco’s mainline as far south as Station 85 in west central Alabama. We expect to place a portion of the project facilities into service during the second half of 2017 and are targeting a full in-service during mid-2018, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase capacity by 1,700 Mdth/d.

Virginia Southside II

In July 2016, we received approval from the FERC to expand Transco’s existing natural gas transmission system together with greenfield facilities to provide incremental firm transportation capacity from Station 210 in New Jersey and Station 165 in Virginia to a new lateral extending from our Brunswick Lateral in Virginia. We plan

53

to place the project into service during the fourth quarter of 2017 and it is expected to increase capacity by 250 Mdth/d.

Dalton

In August 2016, we obtained approval from the FERC to expand Transco’s existing natural gas transmission system together with greenfield facilities to provide incremental firm transportation capacity from Station 210 in New Jersey to markets in northwest Georgia. We plan to place the project into service in 2017 and it is expected to increase capacity by 448 Mdth/d.

Gulf Connector

In August 2016, we filed an application with the FERC to expand Transco’s existing natural gas transmission system to provide incremental firm transportation capacity from Station 65 in Louisiana to delivery points in Wharton and San Patricio Counties, Texas. The project will be constructed in two phases, with the initial phase of the project expected to be in service during the second half of 2018 and the remaining phase in 2019, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase capacity by 475 Mdth/d.

Williams NGL & Petchem Services

Gulf Coast NGL and Olefin Infrastructure Expansion

Certain previously acquired liquids pipelines in the Gulf Coast region are expected to be combined with an organic build-out of several projects to expand our petrochemical services in that region. The projects include the construction and commissioning of pipeline systems capable of transporting various purity natural gas liquids and olefins products in the Gulf Coast region. In response to the current conditions in the midstream industry, we are slowing the pace of development and may seek partners for these projects.

Critical Accounting Estimates

The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions. We believe that the nature of these estimates and assumptions is material due to the subjectivity and judgment necessary, or the susceptibility of such matters to change, and the impact of these on our financial condition or results of operations.

Pension and Postretirement Obligations

We have employee benefit plans that include pension and other postretirement benefits. Net periodic benefit cost and obligations for these plans are impacted by various estimates and assumptions. These estimates and assumptions include the expected long-term rates of return on plan assets, discount rates, expected rate of compensation increase, health care cost trend rates, and employee demographics, including retirement age and mortality. These assumptions are reviewed annually and adjustments are made as needed. The assumptions utilized to compute cost and the benefit obligations are shown in Note 10 – Employee Benefit Plans of Notes to Consolidated Financial Statements.

54

The following table presents the estimated increase (decrease) in net periodic benefit cost and obligations resulting from a one-percentage-point change in the specific assumption.

	Benefit Cost						Benefit Obligation
	One- Percentage- Point Increase			One- Percentage- Point Decrease			One- Percentage- Point Increase			One- Percentage- Point Decrease
	(Millions)
Pension benefits:
Discount rate	$	(9	)	$	10		$	(130	)	$	154
Expected long-term rate of return on plan assets	(13		)	13			—			—
Rate of compensation increase	3			(2		)	9			(7		)
Other postretirement benefits:
Discount rate	1			1			(21		)	25
Expected long-term rate of return on plan assets	(2		)	2			—			—
Assumed health care cost trend rate	—			—			6			(5		)

Our expected long-term rates of return on plan assets, as determined at the beginning of each fiscal year, are based on the average rate of return expected on the funds invested in the plans. We determine our long-term expected rates of return on plan assets using our expectations of capital market results, which include an analysis of historical results as well as forward-looking projections. These capital market expectations are based on a period of at least 10 years and take into account our investment strategy and mix of assets, which are weighted toward domestic and international equity securities. We develop our expectations using input from our third-party independent investment consultant. The forward-looking capital market projections start with current conditions of interest rates, equity pricing, economic growth, and inflation and those are overlaid with forward looking projections of normal inflation, growth, and interest rates to determine expected returns. The capital market return projections for specific asset classes in the investment portfolio are then applied to the relative weightings of the asset classes in the investment portfolio. The resulting rates are an estimate of future results and, thus, likely to be different than actual results.

In 2016, the benefit plans’ assets outperformed their respective benchmarks for fixed income strategies, but generally underperformed the respective benchmarks for equity strategies. While the 2016 investment performance was greater than our expected rates of return, the expected rates of return on plan assets are long-term in nature and are not significantly impacted by short-term market performance. Changes to our asset allocation would also impact these expected rates of return. Our expected long-term rate of return on plan assets used for our pension plans was 6.85 percent in 2016. The 2016 actual return on plan assets for our pension plans was approximately 7.5 percent. The 10-year average rate of return on pension plan assets through December 2016 was approximately 3.7 percent.

The discount rates are used to measure the benefit obligations of our pension and other postretirement benefit plans. The objective of the discount rates is to determine the amount, if invested at the December 31 measurement date in a portfolio of high-quality debt securities, that will provide the necessary cash flows when benefit payments are due. Increases in the discount rates decrease the obligation and, generally, decrease the related cost. The discount rates for our pension and other postretirement benefit plans are determined separately based on an approach specific to our plans and their respective expected benefit cash flows as described in Note 1 – General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies and Note 10 – Employee Benefit Plans of Notes to Consolidated Financial Statements. Our discount rate assumptions are impacted by changes in general economic and market conditions that affect interest rates on long-term, high-quality debt securities as well as by the duration of our plans’ liabilities.

The expected rate of compensation increase represents average long-term salary increases. An increase in this rate causes the pension obligation and cost to increase.

The assumed health care cost trend rates are based on national trend rates adjusted for our actual historical cost rates and plan design. An increase in this rate causes the other postretirement benefit obligation and cost to increase.

55

Equity-Method Investments

At the end of the third quarter of 2016, we became aware of changes involving certain of DBJV’s customer contracts, which impacted our estimates of DBJV’s future cash flows. As such, we evaluated this investment for impairment at September 30, 2016, and determined that no impairment was necessary. We also entered into initial discussions with the system operator regarding the terms and economic assumptions of these contract changes.

During the fourth quarter of 2016, these discussions led to negotiations with the system operator to exchange our interest in DBJV and another equity-method investment in the Permian basin (Ranch Westex) for its interests in certain gathering systems in the Northeast and cash. We already hold partial interests in these Northeast gathering systems through our Appalachia Midstream Investments. As previously discussed, we reached agreements for such transactions in February 2017.

As part of the preparation of our year-end financial statements, we evaluated the carrying amounts of our investments in DBJV, Ranch Westex and these certain gathering systems within our Appalachia Midstream Investments for impairment. We also evaluated other equity-method investments within the Northeast area for impairment as of December 31, 2016, including other gathering systems within our Appalachia Midstream Investments and our investment in UEOM. Our impairment evaluations utilized an income approach, but also considered the fair values indicated by the previously described transaction. The estimated fair value of our investment in DBJV exceeded its carrying value and no impairment was necessary. Based on the fair value of the consideration expected to be received, we currently expect to recognize a gain upon consummation of the previously described exchange transaction in 2017.

We estimated the fair value of our Appalachia Midstream Investments and UEOM using an income approach with discount rates ranging from 10.2 percent to 12.5 percent and also considered the value implied by the previously described transactions as applicable. For certain gathering systems within our Appalachia Midstream Investments, the fair value was determined to be less than our carrying value, resulting in an other-than-temporary impairment charge of $294 million. No impairment was necessary for other gathering systems within our Appalachia Midstream Investments or our investment in UEOM. For those investments evaluated for which no impairment was required, our estimate of fair value exceeded our carrying value by amounts ranging from approximately 2.5 percent to 7.5 percent. We estimate that an increase in the discount rate utilized of 50 basis points would have resulted in an additional impairment charge of approximately $45 million. We also recorded an additional impairment of $24 million related to our interest in Ranch Westex.

Judgments and assumptions are inherent in our estimates of future cash flows, discount rates, and market measures utilized. The use of alternate judgments and assumptions could result in a different calculation of fair value, which could ultimately result in the recognition of a different impairment charge in the consolidated financial statements.

At December 31, 2016, our Consolidated Balance Sheet includes approximately $6.7 billion of investments that are accounted for under the equity-method of accounting. We evaluate these investments for impairment when events or changes in circumstances indicate, in our management’s judgment, that the carrying value of such investments may have experienced an other-than-temporary decline in value. We continue to monitor our equity-method investments for any indications that the carrying value may have experienced an other-than-temporary decline in value. When evidence of a loss in value has occurred, we compare our estimate of the fair value of the investment to the carrying value of the investment to determine whether an impairment has occurred. We generally estimate the fair value of our investments using an income approach where significant judgments and assumptions include expected future cash flows and the appropriate discount rate. In some cases, we may utilize a form of market approach to estimate the fair value of our investments.

If the estimated fair value is less than the carrying value and we consider the decline in value to be other-than-temporary, the excess of the carrying value over the fair value is recognized in the consolidated financial statements as an impairment charge. Events or changes in circumstances that may be indicative of an other-than-temporary decline in value will vary by investment, but may include:

• A significant or sustained decline in the market value of an investee;

• Lower than expected cash distributions from investees;

56

• Significant asset impairments or operating losses recognized by investees;

• Significant delays in or lack of producer development or significant declines in producer volumes in markets served by investees;

• Significant delays in or failure to complete significant growth projects of investees.

Constitution Pipeline Capitalized Project Costs

As of December 31, 2016, Property, plant, and equipment – netin our Consolidated Balance Sheet includes approximately $381 million of capitalized project costs for Constitution, for which we are the construction manager and own a 41 percent consolidated interest. In December 2014, we received approval from the FERC to construct and operate this jointly owned pipeline. However, in April 2016, the New York State Department of Environmental Conservation (NYSDEC) denied a necessary water quality certification for the New York portion of the Constitution pipeline. We remain steadfastly committed to the project, and in May 2016, Constitution appealed the NYSDEC's denial of the certification and filed an action in federal court seeking a declaration that the State of New York's authority to exercise permitting jurisdiction over certain other environmental matters is preempted by federal law.

As a result of the denial by the NYSDEC, we evaluated the capitalized project costs for impairment as of March 31, 2016, and as of December 31, 2016, and determined that no impairment was necessary. Our evaluation considered probability-weighted scenarios of undiscounted future net cash flows, including a scenario assuming successful resolution with the NYSDEC and construction of the pipeline, as well as a scenario where the project does not proceed. We continue to monitor the capitalized project costs associated with Constitution for potential impairment.

57

Results of Operations

Consolidated Overview

The following table and discussion is a summary of our consolidated results of operations for the three years ended December 31, 2016. The results of operations by segment are discussed in further detail following this consolidated overview discussion.

	Years Ended December 31,
	2016			$ Change from 2015*	% Change from 2015*		2015			$ Change from 2014*	% Change from 2014*		2014
	(Millions)
Revenues:
Service revenues	$	5,171		+7	—	%	$	5,164		+1,048	+25	%	$	4,116
Product sales	2,328			+132	+6	%	2,196			-1,325	-38	%	3,521
Total revenues	7,499						7,360						7,637
Costs and expenses:
Product costs	1,725			+54	+3	%	1,779			+1,237	+41	%	3,016
Operating and maintenance expenses	1,580			+75	+5	%	1,655			-163	-11	%	1,492
Depreciation and amortization expenses	1,763			-25	-1	%	1,738			-562	-48	%	1,176
Selling, general, and administrative expenses	723			+18	+2	%	741			-80	-12	%	661
Impairment of goodwill	—			+1,098	+100	%	1,098			-1,098	NM		—
Impairment of certain assets	873			-664	NM		209			-157	NM		52
Net insurance recoveries – Geismar Incident	(7		)	-119	-94	%	(126		)	-106	-46	%	(232		)
Other (income) expense – net	142			-102	NM		40			-137	NM		(97		)
Total costs and expenses	6,799						7,134						6,068
Operating income (loss)	700						226						1,569
Equity earnings (losses)	397			+62	+19	%	335			+191	+133	%	144
Gain on remeasurement of equity-method investment	—			—	—	%	—			-2,544	-100	%	2,544
Impairment of equity-method investments	(430		)	+929	+68	%	(1,359		)	-1,359	NM		—
Other investing income (loss) – net	63			+36	+133	%	27			-16	-37	%	43
Interest expense	(1,179		)	-135	-13	%	(1,044		)	-297	-40	%	(747		)
Other income (expense) – net	74			-28	-27	%	102			+71	NM		31
Income (loss) from continuing operations before income taxes	(375		)				(1,713		)				3,584
Provision (benefit) for income taxes	(25		)	-374	-94	%	(399		)	+1,648	NM		1,249
Income (loss) from continuing operations	(350		)				(1,314		)				2,335
Income (loss) from discontinued operations	—			—	—	%	—			-4	-100	%	4
Net income (loss)	(350		)				(1,314		)				2,339
Less: Net income (loss) attributable to noncontrolling interests	74			-817	NM		(743		)	+968	NM		225
Net income (loss) attributable to The Williams Companies, Inc.	$	(424	)				$	(571	)				$	2,114

_______

* + = Favorable change; - = Unfavorable change; NM = A percentage calculation is not meaningful due to a change in signs, a zero-value denominator, or a percentage change greater than 200.

58

2016 vs. 2015

Service revenuesincreased slightly primarily due toexpansion projects placed in service in 2015 and 2016, partially offset by a decrease in gathering, processing, and fractionation revenue primarily due to lower volumes in the Barnett Shale and Anadarko basin.

Product sales increased primarily due to higher olefin sales reflecting increased volumes at our Geismar plant as a result of the plant operating at higher production levels in 2016, partially offset by a decrease from our other olefin operations associated with lower volumes and per-unit sales prices. Product sales also reflect higher marketing revenues associated with higher NGL and propylene prices and natural gas and crude oil volumes, partially offset by lower NGL volumes, and crude oil prices.

The decrease in Product costsincludes lower olefin feedstock purchases and lower costs associated with other product sales, partially offset by higher marketing purchases primarily due to the same factors that increased marketing sales. The decline in olefin feedstock purchases is primarily associated with lower per-unit feedstock costs and volumes at our other olefin operations, partially offset by an increase in olefin feedstock purchases at our Geismar plant reflecting increased volumes resulting from higher production levels in 2016.

Operating and maintenance expensesdecreased primarily due to lower labor-related and outside service costs resulting from our first-quarter 2016 workforce reductions and cost containment efforts and lower costs associated with general maintenance activities in the Marcellus Shale, as well as the absence of ACMP transition-related costs recognized in 2015. These decreases are partially offset by $16 million of severance and related costs recognized in 2016 and higher pipeline testing and general maintenance costs at Transco.

Depreciation and amortization expensesincreased primarily due to depreciation on new assets placed in service, including Transco pipeline projects, partially offset by lower depreciation related to Canadian operations sold in 2016.

Selling, general, and administrative expenses(SG&A) decreased primarily due to lower merger and transition costs associated with the ACMP merger and lower labor-related costs resulting from our first-quarter 2016 workforce reductions and cost containment efforts. These decreases were partially offset by certain project development costs associated with the Canadian PDH facility that we began expensing in 2016, as well as $26 million of severance and related costs recognized in 2016 and $17 million of higher costs associated with our evaluation of strategic alternatives.

Impairment of goodwilldecreased due to the absence of a 2015 impairment charge associated with certain goodwill. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk of Notes to Consolidated Financial Statements.)

Impairment of certain assets reflects 2016 impairments of our Canadian operations and certain Mid-Continent assets, and other assets. Impairments recognized in 2015 relate primarily to previously capitalized development costs and surplus equipment write-downs. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk of Notes to Consolidated Financial Statements.)

Net insurance recoveries – Geismar Incident changed unfavorably reflecting the receipt of $126 million of insurance proceeds in the second quarter of 2015, as compared to the receipt of $7 million of proceeds in the fourth quarter of 2016.

The unfavorable change inOther (income) expense – netwithin Operating income (loss) includes a loss on the sale of our Canadian operations that were sold in September 2016, project development costs at Constitution as we discontinued capitalization of these costs in April 2016, and an unfavorable change in foreign currency exchange that primarily relates to losses incurred on foreign currency transactions and the remeasurement of the U.S. dollar-denominated current assets and liabilities within our former Canadian operations, partially offset by a $10 million gain on the sale of idle pipe in 2016.

Operating income (loss) changed favorably primarily due to the absence of a goodwill impairment in 2015, higher olefin margins related to the Geismar plant operating at higher production levels in 2016, lower costs related to the merger and integration of ACMP, and lower costs and expenses primarily associated with cost containment efforts.

59

These favorable changes are partially offset by impairments and loss on sale of certain assets in 2016, a decrease in insurance proceeds received, expensed Canadian PDH facility project development costs, and higher depreciation expenses related to new projects placed in service.

Equity earnings (losses)changed favorably primarily due to a $30 million increase at Discovery driven by the completion of the Keathley Canyon Connector in the first quarter of 2015. Additionally, OPPL, Laurel Mountain, and DBJV improved $16 million, $11 million, and $10 million, respectively.

Impairment of equity-method investments reflects 2016 impairment charges associated with our Appalachia Midstream Investments, DBJV, and Laurel Mountain equity-method investments, while the 2015 impairment charges relate to our equity-method investments in Appalachia Midstream Investments, DBJV, UEOM, and Laurel Mountain. (See Note 6 – Investing Activitiesof Notes to Consolidated Financial Statements.)

Other investing income (loss) – netchanged favorably due to a 2016 gain on the sale of an equity-method investment interest in a gathering system that was part of our Appalachia Midstream Investments and higher interest income associated with a receivable related to the sale of certain former Venezuela assets. (See Note 6 – Investing Activities of Notes to Consolidated Financial Statements.)

Interest expenseincreased due to higher Interest incurred of $99 million primarily attributable to new debt issuances in 2016 and 2015 and lower Interest capitalized of $36 million primarily related to construction projects that have been placed into service, partially offset by lower interest due to 2015 and 2016 debt retirements. (See Note 14 – Debt, Banking Arrangements, and Leases of Notes to Consolidated Financial Statements.)

Other income (expense) – net below Operating income (loss) changed unfavorably primarily due to a decrease in allowance for equity funds used during construction (AFUDC) due to decreased spending on Constitution and the absence of a $14 million gain on early debt retirement in 2015.

Provision (benefit) for income taxes changed unfavorably primarily due to a decrease in pretax loss in 2016. See Note 8 – Provision (Benefit) for Income Taxes of Notes to Consolidated Financial Statements for a discussion of the effective tax rates compared to the federal statutory rate for both years.

The unfavorable change in Net income (loss) attributable to noncontrolling interests is primarily due to higher operating results at WPZ, the impact of decreased income allocated to the WPZ general partner driven by the impact of reduced incentive distributions from WPZ associated with the termination of the WPZ Merger Agreement, and the absence of the accelerated amortization of a beneficial conversion feature from the first quarter of 2015. These changes are partially offset by a favorable change primarily related to our partners’ share of Constitution project development costs in 2016.

2015 vs. 2014

Service revenuesincreased primarily due to additional revenues associated with a full year of ACMP operations in 2015, increased revenues associated with the start-up of operations at Gulfstar One during the fourth quarter of 2014, and an increase in Transco’s natural gas transportation fees due to new projects placed in service in 2014 and 2015. Revenues from operations associated with our acquisition of ACMP and the northeast region also increased due to higher volumes related to new well connects. A decrease in Canadian construction management revenues, reflecting a shift to internal customer construction projects, partially offset these increases.

Product sales decreased due to a decrease in marketing revenues primarily associated with lower prices across all products, partially offset by higher non-ethane volumes, and a decrease in revenues from our equity NGLs reflecting lower NGL prices, partially offset by higher NGL volumes. Product sales also decreased due to lower olefin sales from other olefin operations associated with lower per-unit sales prices, partially offset by higher volumes. These decreases are partially offset by an increase in olefin sales primarily due to resuming our Geismar operations during 2015.

Product costs decreased due to a decrease in marketing purchases primarily associated with lower per-unit costs, partially offset by higher non-ethane volumes, and a decrease in natural gas purchases associated with the production of equity NGLs primarily due to lower natural gas prices, partially offset by higher volumes. Product costs also decreased

60

due to lower feedstock purchases in our other olefin operations primarily due to lower per-unit feedstock costs across all products as well as lower per-unit costs, partially offset by significantly higher volumes in 2015. These decreases are partially offset by an increase in olefin feedstock purchases primarily associated with resuming our Geismar operations.

Operating and maintenance expenses increased primarily due to new expenses associated with operations acquired in our acquisition of ACMP, increased growth of operating activity in certain areas, increased maintenance and repair expenses, and the return to operations of the Geismar plant. These increases are partially offset by a decrease in Canadian construction management expenses that reflect a shift to internal customer construction projects.

Depreciation and amortization expenses increased primarily due to new expenses associated with operations acquired in our acquisition of ACMP and from depreciation on new projects placed in service, including Gulfstar One and the Geismar expansion.

SG&A increased primarily due to administrative expenses associated with operations acquired in our acquisition of ACMP, including $31 million higher ACMP merger and transition-related costs, partially offset by the absence of $16 million of acquisition costs incurred in 2014. In addition, 2015 includes $32 million of costs associated with our evaluation of strategic alternatives. These increases are partially offset by the absence of $18 million of project development costs incurred in 2014 related to the Bluegrass Pipeline reflecting 100 percent of such costs. The 50 percent noncontrolling interest share of these costs are presented in Net income (loss) attributable to noncontrolling interests.

Impairment of goodwill reflects a 2015 impairment charge associated with certain goodwill. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk of Notes to Consolidated Financial Statements.)

Impairment of certain assets relate primarily to 2015 impairments of previously capitalized development costs and surplus equipment write-downs. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk of Notes to Consolidated Financial Statements.)

Net insurance recoveries – Geismar Incident changed unfavorably primarily due to the receipt of $126 million of insurance recoveries in 2015 as compared to the receipt of $246 million of insurance recoveries in 2014.

Other (income) expense – net within Operating income (loss) changedunfavorably primarily due to the absence of $154 million of cash proceeds received in 2014 related to a contingency settlement gain and the absence of a $12 million net gain recognized in 2014 related to a partial acreage dedication release. (See Note 7 – Other Income and Expenses of Notes to Consolidated Financial Statements.)

Operating income (loss) changed unfavorably primarily due to a 2015 impairment of goodwill, higher impairments of certain assets, higher depreciation, operating, and maintenance expenses related to construction projects placed in service and the start-up of the Geismar plant, $229 million lower NGL margins driven by lower prices, lower insurance recoveries related to the Geismar Incident, higher costs related to the merger and integration of ACMP into WPZ, and 2015 strategic alternative expenses. These decreases were partially offset by increased service revenues related to construction projects placed in service, $116 million higher olefin margins primarily due to our Geismar plant that returned to operations in 2015, and contributions from the operations acquired in our acquisition of ACMP.

Equity earnings (losses) changed favorably primarily due to the absence of equity losses from Bluegrass Pipeline and Moss Lake in 2014 and due to contributions from investments acquired in our acquisition of ACMP. In addition, equity earnings at Discovery increased $76 million primarily related to the completion of the Keathley Canyon Connector in early 2015. These changes were partially offset by $33 million of losses associated with our share of impairments recognized at equity investees in 2015. (See Note 6 – Investing Activities of Notes to Consolidated Financial Statements.)

Gain on remeasurement of equity-method investment reflects the 2014 gain recognized as a result of remeasuring to fair value the equity-method investment that we held before we acquired a controlling interest in ACMP. (See Note 2 – Acquisitions of Notes to Consolidated Financial Statements.)

Impairment of equity-method investments reflects 2015 impairment charges associated with certain equity-method investments. (See Note 6 – Investing Activitiesof Notes to Consolidated Financial Statements.)

61

Other investing income (loss) – net changed unfavorably primarily due to lower interest income associated with a receivable related to the sale of certain former Venezuela assets.

Interest expense increased due to a $230 million increase in Interest incurred primarily due to new debt issuances in 2014 and 2015 and interest expense associated with debt assumed in conjunction with our acquisition of ACMP. This increase was partially offset by lower interest due to 2015 debt retirements and the absence of a $9 million transaction-related financing fee incurred in the second quarter of 2014 related to our acquisition of ACMP. In addition, Interest capitalized decreased $67 million primarily related to construction projects that have been placed into service. (See Note 2 – Acquisitions and Note 14 – Debt, Banking Arrangements, and Leases of Notes to Consolidated Financial Statements.)

Other income (expense) – net below Operating income(loss) changed favorably primarily due to a $43 million benefit related to an increase in AFUDC associated with an increase in spending on various Transco expansion projects and Constitution, a $14 million gain on early debt retirement in April 2015, and a $9 million contingency gain settlement.

Provision (benefit) for income taxes changed favorably primarily due to lower pretax income in 2015. See Note 8 – Provision (Benefit) for Income Taxes of Notes to Consolidated Financial Statements for a discussion of the effective tax rates compared to the federal statutory rate for both years.

The favorable change in Net income (loss) attributable to noncontrolling interests related to our investment in WPZ is primarily due to lower operating results at WPZ, our increased percentage of limited partner ownership of WPZ, and the impact of increased income allocated to the WPZ general partner, held by us, associated with IDRs. These changes are partially offset by an unfavorable change related to our investment in Gulfstar One associated with its start up in 2014.

Year-Over-Year Operating Results – Segments

We evaluate segment operating performance based upon Modified EBITDA. Note 19 – Segment Disclosures of Notes to Consolidated Financial Statements includes a reconciliation of this non-GAAP measure to Net income (loss). Management uses Modified EBITDA because it is an accepted financial indicator used by investors to compare company performance. In addition, management believes that this measure provides investors an enhanced perspective of the operating performance of our assets. Modified EBITDA should not be considered in isolation or as a substitute for a measure of performance prepared in accordance with GAAP.

Williams Partners

	Years Ended December 31,
	2016			2015			2014
	(Millions)
Service revenues	$	5,173		$	5,135		$	3,888
Product sales	2,318			2,196			3,521
Segment revenues	7,491			7,331			7,409
Product costs	(1,728		)	(1,779		)	(3,016		)
Other segment costs and expenses	(2,203		)	(2,229		)	(1,760		)
Net insurance recoveries – Geismar Incident	7			126			232
Impairment of certain assets	(457		)	(145		)	(52		)
Proportional Modified EBITDA of equity-method investments	754			699			431
Williams Partners Modified EBITDA	$	3,864		$	4,003		$	3,244
NGL margin	$	169		$	159		$	388
Olefin margin	337			226			110

62

2016 vs. 2015

Modified EBITDA decreased primarily due to higher impairments, lower insurance recoveries associated with the Geismar Incident, and loss on sale associated with our Canadian operations. These decreases were partially offset by higher olefin margins related to the Geismar plant operating at higher production levels in 2016, lower segment costs and expenses, and higher earnings related to our equity-method investments, including the completion of the Keathley Canyon Connector at Discovery in the first quarter of 2015. Additionally, higher marketing margins, higher service revenues related to projects placed in service, and higher NGL margins improved Modified EBITDA.

The increase in Service revenues is primarily due to a $79 million increase in Transco’s natural gas transportation fee revenues primarily associated with expansion projects placed in service in 2015 and 2016 and a $31 million transportation and fractionation revenue increase associated with Williams NGL & Petchem’s Horizon liquids extraction plant in Canada. The Canadian operations were sold in late September 2016. These increases were partially offset by a decrease in gathering, processing, and fractionation revenue primarily due to lower volumes primarily in the Barnett Shale and Anadarko basin and a $15 million decrease in Transco’s storage revenue related to potential refunds associated with a ruling received in certain rate case litigation in 2016.

Product sales increased primarily due to:

• A $94 million increase in olefin sales comprised of a $170 million increase from our Geismar plant that returned to service in late March 2015, partially offset by a $76 million decrease from our other olefin operations. The increase at Geismar includes $153 million associated with increased volumes as a result of the plant operating at higher production levels in 2016 than when production resumed in March 2015 following the Geismar Incident and $17 million primarily associated with higher ethylene per-unit sales prices. The decrease in other olefin sales includes a $14 million reduction due to the absence of our former Canadian operations in the fourth quarter of 2016, as well as lower volumes and lower per-unit sales prices within our other olefin operations;

• A $70 million increase in marketing revenues primarily due to higher NGL and propylene prices and natural gas and crude oil volumes, partially offset by lower NGL volumes and crude oil prices (partially offset in marketing purchases);

• A $6 million increase in revenues from our equity NGLs due to a $10 million increase associated with higher volumes, partially offset by a $4 million decrease associated with lower NGL prices;

• A $39 million decrease in system management gas sales from Transco. System management gas sales are offset in Product costs and, therefore, have no impact on Modified EBITDA.

The decrease in Product costs includes:

• A $39 million decrease in system management gas costs (offset in Product sales);

• A $17 million decrease in olefin feedstock purchases is primarily comprised of $78 million in lower purchases at our other olefins operations, partially offset by $61 million of higher purchases due primarily to increased volumes at our Geismar plant resulting from higher productions levels. The lower costs at our other olefin operations are comprised of $54 million in lower per-unit feedstock costs and $24 million in primarily lower propylene volumes;

• A $4 million decrease in natural gas purchases associated with the production of equity NGLs reflecting a decrease of $13 million due to lower natural gas prices, partially offset by a $9 million increase associated with higher volumes;

• Lower costs associated with various other products, primarily condensate;

63

• A $22 million increase in marketing purchases primarily due to the same factors that increased marketing sales (more than offset in marketing revenues). The increase in marketing costs does not reflect the intercompany costs associated with certain gathering and processing services performed by an affiliate.

The decrease in Other segment costs and expenses is primarily due to lower operating costs and general and administrative expenses reflecting decreases in primarily labor-related and outside services costs resulting from our first-quarter 2016 workforce reductions and ongoing cost containment efforts and lower costs associated with general maintenance activities in the Marcellus Shale, as well as $43 million of lower ACMP Merger and transition-related expenses. Other items partially offsetting these decreases are as follows:

• $34 million increase related to the 2016 loss on sale of our Canadian operations;

• $37 million increase for severance and related costs associated with workforce reductions incurred in the first quarter of 2016 and the organizational realignment in the fourth quarter of 2016;

• $28 million higher project development costs at Constitution as we discontinued capitalization of development costs related to this project beginning in April 2016;

• $22 million higher contract services for pipeline testing and general maintenance at Transco;

• $20 million unfavorable change in foreign currency exchange that primarily relates to losses incurred on foreign currency transactions and the remeasurement of the U.S. dollar-denominated current assets and liabilities within our former Canadian operations;

• $19 million unfavorable change in AFUDC associated with a decrease in spending on Constitution;

• The absence of a $14 million gain recognized in second-quarter 2015 resulting from the early retirement of certain debt.

Net insurance recoveries – Geismar Incident decreased reflecting $7 million of insurance proceeds received in 2016 compared to $126 million received in 2015.

Impairment of certain assets increased primarily due to 2016 impairments of $341 million associated with our Canadian operations and $63 million associated with certain Mid-Continent gathering assets as well as impairments or write-downs of other certain assets that may no longer be in use or are surplus in nature, partially offset by the absence of 2015 impairments of $94 million associated with previously capitalized project development costs for a gas processing plant and $20 million associated with certain surplus equipment within our Ohio Valley Midstream business. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk of Notes to Consolidated Financial Statements.)

The increase in Proportional Modified EBITDA of equity-method investments is primarily due to a $30 million increase from Discovery primarily associated with higher fee revenues attributable to the completion of the Keathley Canyon Connector in the first quarter of 2015. Additionally, Caiman II contributed a $20 million increase resulting from higher volumes due to assets placed into service in 2015, OPPL contributed a $16 million increase primarily due to higher transportation volumes and lower expenses, and UEOM contributed an $11 million increase primarily associated with an increase in our ownership percentage. These increases were partially offset by an $29 million decrease from Appalachia Midstream Investments primarily due to lower fee revenues driven by lower rates, partially offset by lower impairments and higher volumes.

2015 vs. 2014

Modified EBITDA increased primarily due to the acquisition of ACMP during the third quarter of 2014 and increased fee revenue associated with contributions from new and expanded facilities, including Gulfstar One during the fourth quarter of 2014, in addition to resuming our Geismar operations and contributions related to the completion of the Keathley Canyon Connector at Discovery. Partially offsetting these increases to Modified EBITDA is a decrease in

64

NGL margins as a result of a significant decline in commodity prices beginning in the fourth quarter of 2014 and lower insurance recoveries related to the Geismar Incident.

The increase in Service revenues is primarily due to $810 million additional revenues associated with a full year of ACMP operations in 2015 which includes a $72 million increase in the minimum volume commitment fees, $223 million in increased revenues associated with the start-up of operations at Gulfstar One during the fourth quarter of 2014, and a $155 million increase in Transco’s natural gas transportation fees due to new projects placed in service in 2015 and 2014. Additionally, service revenues reflect higher fees associated with increased volumes and additional contributions in the Northeast. Higher revenues in the Northeast include expanded gathering operations and processing, fractionation and transportation operations, contributing $59 million and $27 million of additional fees, respectively.

The decrease in Product sales includes:

• A $1,173 million decrease in marketing revenues primarily associated with lower prices across all products, partially offset by higher non-ethane volumes (more than offset in marketing purchases);

• A $324 million decrease in revenues from our equity NGLs reflecting a decrease of $365 million due to lower NGL prices, partially offset by a $41 million increase associated with higher NGL volumes;

• A $41 million decrease in revenues primarily due to lower condensate prices;

• A $214 million increase in olefin sales primarily due to $298 million in higher sales from our Geismar plant that returned to operation, partially offset by an $84 million decrease from our other olefin operations due to lower sales prices, partially offset by higher volumes across all products, particularly propylene.

The decrease in Product costs includes:

• A $1,219 million decrease in marketing purchases primarily due to a decrease in non-ethane per-unit cost (substantially offset in marketing revenues);

• A $95 million decrease in the natural gas purchases associated with the production of equity NGLs reflecting a decrease of $126 million due to lower natural gas prices, partially offset by a $31 million increase associated with higher volumes;

• A $20 million decrease in costs primarily due to lower gas prices;

• A $98 million increase in olefin feedstock purchases is comprised of $127 million in higher purchases due to increased volumes at our Geismar plant as it returned to operation, partially offset by $29 million in lower other olefin operations feedstock purchases primarily due to lower per-unit feedstock costs, partially offset by higher volumes across most products, particularly propylene.

The increase in Other segment costs and expenses includes:

• An increase for new expenses associated with operations associated with the acquisition of ACMP;

• The absence of $154 million of cash received in the fourth quarter of 2014 associated with the resolution of a contingent gain related to claims arising from the purchase of a business in a prior period (see Note 7 – Other Income and Expenses of Notes to Consolidated Financial Statements);

• A $16 million increase in operating expense due to the Geismar plant returning to operation in 2015;

• The absence of a $12 million net gain recognized in 2014 related to a partial acreage dedication release.

The decrease in Net insurance recoveries – Geismar Incident is primarily due to the 2015 receipt of $126 million of insurance proceeds compared to $246 million received in 2014, partially offset by the absence of covered insurable

65

expenses in excess of our retentions (deductibles) related to the Geismar Incident in 2015 compared to $14 million in 2014.

Impairment of certain assets increased primarily due to a 2015 $94 million impairment charge associated with previously capitalized project development costs for a gas processing plant. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk of Notes to Consolidated Financial Statements.)

The increase in Proportional Modified EBITDA of equity-method investments is primarily due to a full year contribution of $160 million from investments associated with the acquisition of ACMP and a $103 million increase from Discovery associated with higher fee revenues attributable to the completion of the Keathley Canyon Connector in the first quarter of 2015. Additionally, Caiman II increased $21 million resulting from assets placed into service in 2014 and 2015, partially offset by the absence of business interruption insurance proceeds received in the prior year, and an $11 million decrease at Laurel Mountain. The decrease at Laurel Mountain was primarily due to $13 million of impairments and lower gathering fees due to lower gathering rates indexed to natural gas prices, partially offset by 24 percent higher volumes and an increase in our ownership percentage compared to the prior year.

Williams NGL & Petchem Services

	Years Ended December 31,
	2016			2015			2014
	(Millions)
Service revenues	$	2		$	2		$	—
Product sales	26			—			—
Segment revenues	28			2			—
Product costs	(13		)	—			—
Other segment costs and expenses	(139		)	(85		)	(37		)
Impairment of certain assets	(416		)	—			—
Proportional Modified EBITDA of equity-method investments	—			—			(78		)
Williams NGL & Petchem Services Modified EBITDA	$	(540	)	$	(83	)	$	(115	)

2016 vs. 2015

The unfavorable change in Modified EBITDA is primarily due to the 2016 impairment and subsequent loss on disposal of our Canadian operations as well as the expensing of certain development costs associated with the Canadian PDH facility, partially offset by the absence of the 2015 write-off of previously capitalized project development costs for an olefins pipeline project.

The increase in Product sales and Product costs is primarily due to the Horizon liquids extraction plant coming online in March 2016 until it was sold in September 2016.

The unfavorable change in Other segment costs and expenses is primarily due to $61 million of certain project development costs associated with the Canadian PDH facility that we began expensing in 2016. Additionally, the unfavorable change includes $33 million of transportation and fractionation fees associated with our new Horizon volumes and a $32 million loss on the sale of our Canadian operations in September 2016. (See Note 3 – Divestiture of Notes to Consolidated Financial Statements.) The unfavorable change in Other segment costs and expenses is partially offset by a $10 million gain on the sale of unused pipe in 2016 and the absence of the $64 million write-off of previously capitalized project development costs for an olefins pipeline project in 2015. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk of Notes to Consolidated Financial Statements.)

The unfavorable change in Impairment of certain assets primarily reflects the 2016 impairment of our Canadian operations and an $8 million impairment of idle pipe. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk of Notes to Consolidated Financial Statements.)

.

66

2015 vs. 2014

The favorable change in Modified EBITDA is primarily due to the absence of our share of the 2014 write-off of previously capitalized project development costs at Bluegrass Pipeline and Moss Lake, as well as costs incurred in 2014 relating to the development of the Bluegrass Pipeline, partially offset by the 2015 write-off of previously capitalized project development costs for an olefins pipeline project.

Other segment costs and expenses increased primarily due to the $64 million write-off of previously capitalized project development costs for an olefins pipeline project in 2015, partially offset by the absence of $18 million of project development costs incurred in 2014 relating to the Bluegrass Pipeline.

The favorable change in Proportional Modified EBITDA of equity-method investments is primarily due to the absence of our share of the 2014 write-off of previously capitalized project development costs at Bluegrass Pipeline and Moss Lake.

Other

	Years Ended December 31,
	2016			2015			2014
	(Millions)
Other Modified EBITDA	$	(2	)	$	(29	)	$	103

2016 vs. 2015

Modified EBITDA improved primarily due to a $31 million decrease in ACMP merger and transition related costs, as well as the impact of various other individually insignificant items, partially offset by a $17 million increase in costs related to our evaluation of strategic alternatives.

2015 vs. 2014

Modified EBITDA decreased significantly as the results from the businesses acquired with our acquisition of ACMP are presented within Williams Partners for periods subsequent to the July 1, 2014, acquisition. Other included the proportional Modified EBITDA of $104 million of our former equity-method investment in ACMP for the first half of 2014, which was partially offset by $19 million associated with our share of compensation costs triggered by the ACMP Acquisition recognized in July 2014. Modified EBITDA also decreased by $30 million related to costs incurred in 2015 related to evaluating our strategic alternatives and the Merger Agreement with Energy Transfer, as well as $24 million of higher costs associated with integration and re-alignment of resources following the ACMP acquisition and merger. These decreases are partially offset by a $9 million contingency gain settlement recognized in fourth quarter 2015.

67

Management’s Discussion and Analysis of Financial Condition and Liquidity

Overview

In 2016, we continued to focus upon growth in our businesses through disciplined investment and reducing our costs and funding needs. Examples of this activity included:

• Expansion of WPZ’s interstate natural gas pipeline system through projects such as Rock Springs to meet the demand of growth markets;

• Completion of WPZ’s Gulfstar One expansion project to provide production handling and gathering services for the Gunflint oil and gas discovery in the eastern deepwater Gulf of Mexico;

• WPZ’s restructuring of contracts in the Barnett Shale and Mid-Continent region,which included cash payments to WPZ of $820 million;

• Sale of our Canadian operations (see Note 3 – Divestiture of Notes to Consolidated Financial Statements).

Outlook

Fee-based businesses are becoming an even more significant component of our portfolio and serve to reduce the influence of commodity price fluctuations on our cash flows. We expect to benefit as continued growth in demand for low-cost natural gas is driven by increases in LNG exports, industrial demand, and power generation.

We believe we have, or have access to, the financial resources and liquidity necessary to meet our requirements for working capital, capital and investment expenditures, dividends and distributions, debt service payments, and tax payments, while maintaining a sufficient level of liquidity. In particular, as previously discussed in Company Outlook, our expected growth capital and investment expenditures total approximately $2.1 billion to $2.8 billion in 2017. Approximately $1.4 billion to $1.9 billion of our growth capital funding needs include Transco expansions and other interstate pipeline growth projects, most of which are fully contracted with firm transportation agreements. The remaining growth capital spending in 2017 primarily reflects investment in gathering and processing systems in the Northeast region limited primarily to known new producer volumes, including volumes that support Transco expansion projects including our Atlantic Sunrise project. In addition to growth capital and investment expenditures, we also remain committed to projects that maintain our assets for safe and reliable operations, as well as projects that meet legal, regulatory, and/or contractual commitments. We retain the flexibility to adjust planned levels of capital and investment expenditures in response to changes in economic conditions or business opportunities.

In January 2017, WPZ announced that it will redeem all of its $750 million6.125 percent senior notes due 2022 on February 23, 2017. In addition, we expect after-tax proceeds in excess of $2 billion from planned asset monetizations of Geismar and other select assets during 2017, which we expect Williams Partners to use for additional debt reduction and to fund capital and investment expenditures.

Liquidity

Based on our forecasted levels of cash flow from operations and other sources of liquidity, we expect to have sufficient liquidity to manage our businesses in 2017. Our internal and external sources of consolidated liquidity to fund working capital requirements, capital and investment expenditures, debt service payments, dividends and distributions, and tax payments include:

• Cash and cash equivalents on hand;

• Cash generated from operations;

• Distributions from WPZ;

• Distributions from our equity-method investees based on our level of ownership;

68

• Use of our credit facility;

• Cash proceeds from issuances of debt and/or equity securities.

WPZ is expected to fund its cash needs through its cash flows from operations and its credit facility and/or commercial paper program, as well as proceeds from planned asset monetizations as previously mentioned. WPZ also established a distribution reinvestment program (DRIP) in the third quarter of 2016.

We previously announced that we intended to reinvest approximately $1.2 billion into WPZ in 2017 via the DRIP, funded primarily by our reduced quarterly cash dividend which would have allowed us to annually retain approximately $1.3 billion for reinvestment. As part of the Financial Repositioning announced in January 2017, we discontinued our participation in the DRIP and expect to increase our regular quarterly cash dividend to $0.30 for the dividend to be paid in March 2017. (See Note 1 – General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies of Notes to Consolidated Financial Statements.)

We anticipate our more significant uses of cash to be:

• Working capital requirements;

• Maintenance and expansion capital and investment expenditures;

• Interest on our long-term debt;

• Repayment of current debt maturities, and additional reductions in WPZ’s debt with funds received as part of the Financial Repositioning;

• Investment in WPZ as part of the Financial Repositioning (see Note 15 – Stockholders' Equity of Notes to Consolidated Financial Statements);

• Quarterly dividends to our shareholders.

Potential risks associated with our planned levels of liquidity discussed above include those previously discussed in Company Outlook.

As of December 31, 2016, we had a working capital deficit (current liabilities, inclusive of $785 million in Long-term debt due within one year, in excess of current assets) of $1.487 billion. Our available liquidity is as follows:

	December 31, 2016
Available Liquidity	WPZ		WMB		Total
	(Millions)
Cash and cash equivalents	$	145	$	25	$	170
Capacity available under our $1.5 billion credit facility (1)			725		725
Capacity available to WPZ under its $3.5 billion credit facility, less amounts outstanding under its $3 billion commercial paper program (2)	3,407				3,407
	$	3,552	$	750	$	4,302

__________

(1) The highest amount outstanding under our credit facility during 2016 was $1.224 billion. At December 31, 2016, we were in compliance with the financial covenants associated with this credit facility. See Note 14 – Debt, Banking Arrangements, and Leases of Notes to Consolidated Financial Statements for additional information on our credit facility. Borrowing capacity available under this facility as of February 20, 2017, was $1.265 billion.

(2) In managing our available liquidity, we do not expect a maximum outstanding amount in excess of the capacity of WPZ’s credit facility inclusive of any outstanding amounts under its commercial paper program. WPZ has $93 million of Commercial paper outstanding at December 31, 2016. The highest amount outstanding under WPZ’s

69

commercial paper program and credit facility during 2016 was $2.326 billion. At December 31, 2016, WPZ was in compliance with the financial covenants associated with this credit facility. See Note 14 – Debt, Banking Arrangements, and Leases of Notes to Consolidated Financial Statements for additional information on WPZ’s credit facility and WPZ’s commercial paper program. Borrowing capacity available under WPZ’s $3.5 billion credit facility as of February 20, 2017, was $3.5 billion.

As described in Note 14 – Debt, Banking Arrangements, and Leases of Notes to Consolidated Financial Statements, we have determined that we have net assets that are technically considered restricted in accordance with Rule 4-08(e) of Regulation S-X of the Securities and Exchange Commission in excess of 25 percent of our consolidated net assets. We do not expect this determination will impact our ability to pay dividends or meet future obligations as the terms of WPZ’s partnership agreement require it to make quarterly distributions of all available cash, as defined, to its unitholders.

WPZ Incentive Distribution Rights

As part of the Financial Repositioning, we permanently waived our right to incentive distributions from WPZ. (See Overview in Management’s Discussion and Analysis of Financial Condition and Results of Operations.)

Through December 31, 2016, our ownership interest in WPZ included the right to incentive distributions determined in accordance with WPZ’s partnership agreement. In connection with the sale of WPZ’s Canadian operations in the third quarter of 2016, we agreed to waive $150 million of incentive distributions otherwise payable by WPZ to us in the fourth quarter of 2016. (See Note 3 – Divestiture of Notes to Consolidated Financial Statements.)

We had agreed to temporarily waive incentive distributions of approximately $2 million per quarter in connection with WPZ’s acquisition of an approximate 13 percent additional interest in UEOM on June 10, 2015. The waiver would have continued through the quarter ending September 30, 2017.

We were required to pay a $428 million termination fee to WPZ, associated with the Termination Agreement (as described in Note 1 – General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies of Notes to Consolidated Financial Statements), which settled through a reduction of quarterly incentive distributions we are entitled to receive from WPZ (such reduction not to exceed $209 million per quarter). The November 2015, February 2016, and May 2016 distributions from WPZ were reduced by $209 million, $209 million, and $10 million, respectively, related to this termination fee.

Registrations

In September 2016, WPZ filed a registration statement for its new DRIP discussed above. In November 2016, WPZ received reinvested distributions of $260 million, of which $250 million related to us.

In May 2015, we filed a shelf registration statement, as a well-known seasoned issuer.

In February 2015, WPZ filed a shelf registration statement, as a well-known seasoned issuer, and WPZ also filed a shelf registration statement for the offer and sale from time to time of common units representing limited partner interests in WPZ having an aggregate offering price of up to $1 billion. These sales are to be made over a period of time and from time to time in transactions at prices which are market prices prevailing at the time of sale, prices related to market price, or at negotiated prices. Such sales are to be made pursuant to an equity distribution agreement between WPZ and certain banks who may act as sales agents or purchase for their own accounts as principals. During 2016 and 2015, WPZ received net proceeds of approximately $115 million and approximately $59 million, respectively, from equity issued under this registration.

Distributions from Equity-Method Investees

The organizational documents of entities in which we have an equity-method investment generally require distribution of their available cash to their members on a quarterly basis. In each case, available cash is reduced, in part, by reserves appropriate for operating their respective businesses. (See Note 6 – Investing Activities of Notes to Consolidated Financial Statements for our more significant equity-method investees.)

70

Credit Ratings

Our ability to borrow money is impacted by our credit ratings and the credit ratings of WPZ. The current ratings are as follows:

	Rating Agency	Outlook	Senior Unsecured Debt Rating	Corporate Credit Rating
WMB:	S&P Global Ratings	Stable	BB	BB
	Moody’s Investors Service	Stable	Ba2	N/A
	Fitch Ratings	Stable	BB+	N/A
WPZ:	S&P Global Ratings	Stable	BBB-	BBB-
	Moody’s Investors Service	Stable	Baa3	N/A
	Fitch Ratings	Stable	BBB-	N/A

Considering our credit ratings as of December 31, 2016, we estimate that we could be required to provide up to $36 million in additional collateral of either cash or letters of credit with third parties under existing contracts.  At the present time, we have not provided any additional collateral to third parties but no assurance can be given that we will not be requested to provide collateral in the future. As of December 31, 2016, we estimate that a downgrade to a rating below investment-grade for WPZ could require it to provide up to $376 million in additional collateral of either cash or letters of credit with third parties under existing contracts.

71

Sources (Uses) of Cash

The following table summarizes the sources (uses) of cash and cash equivalents for each of the periods presented (see Notes to Consolidated Financial Statements for the Notes referenced in the table):

	Cash Flow	Years Ended December 31,
	Category	2016			2015			2014
		(Millions)
Sources of cash and cash equivalents:
Operating activities - net	Operating	$	3,664		$	2,678		$	2,115
Proceeds from WPZ’s credit-facility borrowings	Financing	3,250			3,832			1,646
Proceeds from our credit-facility borrowings	Financing	2,280			2,097			1,040
Proceeds from sale of Canadian operations (see Note 3)	Investing	1,020			—			—
Proceeds from WPZ’s debt offerings (see Note 14)	Financing	998			3,842			2,740
Distributions from unconsolidated affiliates in excess of cumulative earnings	Investing	472			404			206
Proceeds from equity offerings	Financing	123			86			3,471
Contributions from noncontrolling interests	Financing	29			111			340
Special distribution from Gulfstream (see Note 6)	Financing	—			396			—
Proceeds from our debt offerings	Financing	—			—			1,895
Proceeds from WPZ’s commercial paper - net	Financing	—			—			572
Uses of cash and cash equivalents:
Payments on WPZ’s credit-facility borrowings	Financing	(4,560		)	(3,162		)	(1,156		)
Payments on our credit-facility borrowings	Financing	(2,155		)	(1,817		)	(670		)
Capital expenditures	Investing	(2,051		)	(3,167		)	(4,031		)
Quarterly dividends on common stock	Financing	(1,261		)	(1,836		)	(1,412		)
Dividends and distributions to noncontrolling interests	Financing	(940		)	(942		)	(840		)
Payments of WPZ’s commercial paper - net	Financing	(409		)	(306		)	—
Payments on WPZ’s debt retirements (see Note 14)	Financing	(375		)	(1,533		)	—
Purchases of and contributions to equity-method investments	Investing	(177		)	(595		)	(482		)
Contribution to Gulfstream for repayment of debt (see Note 6)	Financing	(148		)	(248		)	—
Purchases of businesses, net of cash acquired	Investing	—			(112		)	(5,958		)
Other sources / (uses) - net	Financing and Investing	310			132			83
Increase (decrease) in cash and cash equivalents		$	70		$	(140	)	$	(441	)

Operating activities

The factors that determine operating activities are largely the same as those that affect Net income (loss), with the exception of noncash items such as Depreciation and amortization, Provision (benefit) for deferred income taxes, Impairment of goodwill, Impairment of equity-method investments, Impairment of and net (gain) loss on sale of assets and businesses, andGain on remeasurement of equity-method investment.

Our Net cash provided (used) by operating activitiesin 2016 increased from 2015 primarily due to the impact of net favorable changes in operating working capital and receipts from contract restructurings.

OurNet cash provided (used) by operating activities in 2015 increased from 2014 primarily due to the impact of net favorable changes in operating working capital and the absence of contributions from ACMP for the first six months of 2014.

72

Off-Balance Sheet Arrangements and Guarantees of Debt or Other Commitments

We have various other guarantees and commitments which are disclosed in Note 4 – Variable Interest Entities, Note 11 – Property, Plant, and Equipment, Note 14 – Debt, Banking Arrangements, and Leases, Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk, and Note 18 – Contingent Liabilities and Commitments of Notes to Consolidated Financial Statements. We do not believe these guarantees and commitments or the possible fulfillment of them will prevent us from meeting our liquidity needs.

Contractual Obligations

The table below summarizes the maturity dates of our contractual obligations at December 31, 2016:

	2017		2018 - 2019		2020 - 2021		Thereafter		Total
					(Millions)
Long-term debt: (1)(2)
Principal	$	785	$	1,382	$	3,767	$	17,506	$	23,440
Interest	1,099		2,132		1,928		7,947		13,106
Commercial paper	93		—		—		—		93
Operating leases	66		109		81		90		346
Purchase obligations (3)	1,074		733		646		320		2,773
Other obligations (4)(5)	2		1		1		1		5
Total	$	3,119	$	4,357	$	6,423	$	25,864	$	39,763

______________

(1) Includes the borrowings outstanding under credit facilities, but does not include any related variable-rate interest payments.

(2) Includes $750 million of 6.125 percent senior notes due 2022 that WPZ intends to redeem on February 23, 2017 and related interest, presented in the table above according to the original contractual terms.

(3) Includes approximately $244 million in open property, plant, and equipment purchase orders. Includes an estimated $418 million long-term ethane purchase obligation with index-based pricing terms that is reflected in this table at December 31, 2016 prices. This obligation is part of an overall exchange agreement whereby volumes we transport on OPPL are sold at a third-party fractionator near Conway, Kansas, and we are subsequently obligated to purchase ethane volumes at Mont Belvieu. The purchased ethane volumes may be utilized or resold at comparable prices in the Mont Belvieu market. Includes an estimated $619 million long-term ethane purchase obligation with index-based pricing terms that primarily supplies third parties at their plants and is valued in this table at a price calculated using December 31, 2016 prices. Any excess purchased volumes may be sold at comparable market prices. Includes an estimated $586 million long-term mixed NGLs purchase obligation with index-based pricing terms that is reflected in this table at December 31, 2016 prices. In addition, we have not included certain natural gas life-of-lease contracts for which the future volumes are indeterminable. We have not included commitments, beyond purchase orders, for the acquisition or construction of property, plant, and equipment or expected contributions to our jointly owned investments. (See Company Outlook — Expansion Projects.)

(4) Does not include estimated contributions to our pension and other postretirement benefit plans. We made contributions to our pension and other postretirement benefit plans of $72 million in 2016 and $70 million in 2015. In 2017, we expect to contribute approximately $69 million to these plans (see Note 10 – Employee Benefit Plans of Notes to Consolidated Financial Statements). Tax-qualified pension plans are required to meet minimum contribution requirements. In the past, we have contributed amounts to our tax-qualified pension plans in excess of the minimum required contribution. These excess amounts can be used to offset future minimum contribution requirements. During 2016, we contributed $60 million to our tax-qualified pension plans. In addition to these contributions, a portion of the excess contributions was used to meet the minimum contribution requirements. During 2017, we expect to contribute approximately $60 million to our tax-qualified pension plans and use excess amounts to satisfy minimum contribution requirements, if needed. Additionally, estimated future minimum funding requirements may vary significantly from historical requirements if actual results differ significantly from estimated

73

results for assumptions such as returns on plan assets, interest rates, retirement rates, mortality, and other significant assumptions or by changes to current legislation and regulations.

(5) We have not included income tax liabilities in the table above. See Note 8 – Provision (Benefit) for Income Taxes of Notes to Consolidated Financial Statements for a discussion of income taxes, including our contingent tax liability reserves.

Effects of Inflation

Our operations have historically not been materially affected by inflation. Approximately 39 percent of our gross property, plant, and equipment is comprised of our interstate natural gas pipeline assets. They are subject to regulation, which limits recovery to historical cost. While amounts in excess of historical cost are not recoverable under current FERC practices, we anticipate being allowed to recover and earn a return based on increased actual cost incurred to replace existing assets. Cost-based regulations, along with competition and other market factors, may limit our ability to recover such increased costs. For our gathering and processing assets, operating costs are influenced to a greater extent by both competition for specialized services and specific price changes in crude oil and natural gas and related commodities than by changes in general inflation. Crude oil, natural gas, and NGL prices are particularly sensitive to the market perceptions concerning the supply and demand balance in the near future, as well as general economic conditions. However, our exposure to certain of these price changes is reduced through the fee-based nature of certain of our services and the use of hedging instruments.

Environmental

We are a participant in certain environmental activities in various stages including assessment studies, cleanup operations, and/or remedial processes at certain sites, some of which we currently do not own (see Note 18 – Contingent Liabilities and Commitments of Notes to Consolidated Financial Statements). We are monitoring these sites in a coordinated effort with other potentially responsible parties, the EPA, or other governmental authorities. We are jointly and severally liable along with unrelated third parties in some of these activities and solely responsible in others. Current estimates of the most likely costs of such activities are approximately $38 million, all of which are included in Accrued liabilities and Regulatory liabilities, deferred income, and other on the Consolidated Balance Sheet at December 31, 2016. We will seek recovery of approximately $9 million of these accrued costs through future natural gas transmission rates. The remainder of these costs will be funded from operations. During 2016, we paid approximately$6 million for cleanup and/or remediation and monitoring activities. We expect to pay approximately $9 million in 2017 for these activities. Estimates of the most likely costs of cleanup are generally based on completed assessment studies, preliminary results of studies, or our experience with other similar cleanup operations. At December 31, 2016, certain assessment studies were still in process for which the ultimate outcome may yield different estimates of most likely costs. Therefore, the actual costs incurred will depend on the final amount, type, and extent of contamination discovered at these sites, the final cleanup standards mandated by the EPA or other governmental authorities, and other factors.

In March 2008, the EPA promulgated a new, lower National Ambient Air Quality Standard (NAAQS) for ground-level ozone. In May 2012, the EPA completed designation of new eight-hour ozone nonattainment areas. Several Transco facilities are located in 2008 ozone nonattainment areas. In December 2014, the EPA proposed to further reduce the ground-level ozone NAAQS from the March 2008 levels and subsequently finalized a rule on October 1, 2015. We are monitoring the rule's implementation as the reduction will trigger additional federal and state regulatory actions that may impact our operations. To date, no federal actions have been proposed to mandate additional emission controls at these facilities. Pursuant to recently finalized state regulatory actions associated with implementation of the 2008 ozone standard, we anticipate that some facilities may be subject to increased controls within five years. Implementation of the regulations is expected to result in impacts to our operations and increase the cost of additions to Property, plant, and equipment – net on the Consolidated Balance Sheetfor both new and existing facilities in affected areas. We are unable at this time to estimate with any certainty the cost of additions that may be required to meet the regulations.

On January 22, 2010, the EPA set a new one-hour nitrogen dioxide (NO2) NAAQS. The effective date of the new NO2 standard was April 12, 2010. On January 20, 2012, the EPA determined pursuant to available information that no area in the country is violating the 2010 NO2 NAAQS and thus designated all areas of the country as “unclassifiable/attainment.” Also, at that time the EPA noted its plan to deploy an expanded NO2 monitoring network beginning in 2013. However on October 5, 2012, the EPA proposed a graduated implementation of the monitoring network between

74

January 1, 2014 and January 1, 2017. Once three years of data is collected from the new monitoring network, the EPA will reassess attainment status with the one-hour NO2 NAAQS. Until that time, the EPA or states may require ambient air quality modeling on a case by case basis to demonstrate compliance with the NO2 standard. Because we are unable to predict the outcome of the EPA’s or states’ future assessment using the new monitoring network, we are unable to estimate the cost of additions that may be required to meet this regulation.

Our interstate natural gas pipelines consider prudently incurred environmental assessment and remediation costs and the costs associated with compliance with environmental standards to be recoverable through rates.

75

Item 7A. Quantitative and Qualitative Disclosures About Market Risk

Interest Rate Risk

Our current interest rate risk exposure is related primarily to our debt portfolio. Our debt portfolio is primarily comprised of fixed rate debt, which mitigates the impact of fluctuations in interest rates. Any borrowings under the credit facilities and any issuances under WPZ’s commercial paper program could be at a variable interest rate and could expose us to the risk of increasing interest rates. The maturity of our long-term debt portfolio is partially influenced by the expected lives of our operating assets. (See Note 14 – Debt, Banking Arrangements, and Leases of Notes to Consolidated Financial Statements.)

The tables below provide information by maturity date about our interest rate risk-sensitive instruments as of December 31, 2016 and 2015. Long-term debt in the tables represents principal cash flows, net of (discount) premium and debt issuance costs, and weighted-average interest rates by expected maturity dates. The fair value of our publicly traded long-term debt is valued using indicative year-end traded bond market prices. Private debt is valued based on market rates and the prices of similar securities with similar terms and credit ratings.

		2017			2018			2019			2020			2021			Thereafter (1)			Total		Fair Value December 31, 2016
	(Millions)
Long-term debt, including current portion:
Fixed rate	$	785		$	500		$	32		$	2,121		$	871		$	17,475		$	21,784	$	22,465
Interest rate		5.2	%		5.2	%		5.2	%		5.2	%		5.2	%		5.6	%
Variable rate	$	—		$	850		$	—		$	775		$	—		$	—		$	1,625	$	1,625
Interest rate (3)
Commercial paper:
Variable rate	$	93		$	—		$	—		$	—		$	—		$	—		$	93	$	93
Interest rate (4)
		2016			2017			2018			2019			2020			Thereafter (1)			Total		Fair Value December 31, 2015
	(Millions)
Long-term debt, including current portion: (2)
Fixed rate	$	375	(*)	$	785		$	500		$	32		$	2,121		$	17,364		$	21,177	$	16,796
Interest rate		5.1	%		5.1	%		5.0	%		5.0	%		5.0	%		5.5	%
Variable rate	$	—		$	—		$	850		$	—		$	1,960		$	—		$	2,810	$	2,810
Interest rate (5)
Commercial paper:
Variable rate	$	499		$	—		$	—		$	—		$	—		$	—		$	499	$	499
Interest rate (4)
_____________
(*) $200 million presented as long-term debt at December 31, 2015, due to WPZ’s intent and ability to refinance.

__________________

(1) Includes unamortized discount / premium and debt issuance costs.

(2) Excludes capital leases.

(3) The weighted-average interest rates for WPZ’s $850 million term loan, and our $775 million credit facility borrowing at December 31, 2016 were 2.50 percent and 2.51 percent, respectively.

(4) The weighted-average interest rate was 1.06 percent and 0.92 percent at December 31, 2016 and 2015, respectively.

76

(5) The weighted-average interest rates for WPZ’s $1.3 billion credit facility borrowing, WPZ’s $850 million term loan, and our $650 million credit facility borrowing at December 31, 2015 were 1.63 percent, 1.85 percent, and 2.32 percent, respectively.

Commodity Price Risk

We are exposed to the impact of fluctuations in the market price of NGLs, olefins, and natural gas, as well as other market factors, such as market volatility and energy commodity price correlations. We are exposed to these risks in connection with our owned energy-related assets, our long-term energy-related contracts, and limited proprietary trading activities. Our management of the risks associated with these market fluctuations includes maintaining sufficient liquidity, as well as using various derivatives and nonderivative energy-related contracts. The fair value of derivative contracts is subject to many factors, including changes in energy commodity market prices, the liquidity and volatility of the markets in which the contracts are transacted, and changes in interest rates. At December 31, 2016 and 2015, our derivative activity was not material. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk of Notes to Consolidated Financial Statements.)

Foreign Currency Risk

In September 2016, we disposed of our Canadian operations, which comprised substantially all of our foreign operations. (See Note 3 – Divestiture of Notes to Consolidated Financial Statements.)

77

Item 8. Financial Statements and Supplementary Data

Report of Independent Registered Public Accounting Firm

The Board of Directors and Stockholders of

The Williams Companies, Inc.

We have audited the accompanying consolidated balance sheet of The Williams Companies, Inc. as of December 31, 2016 and 2015, and the related consolidated statements of operations, comprehensive income (loss), changes in equity and cash flows for each of the three years in the period ended December 31, 2016. Our audits also included the financial statement schedules listed in the index at Item 15(a). These financial statements and schedules are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements and schedules based on our audits. We did not audit the financial statements of Gulfstream Natural Gas System, L.L.C. (“Gulfstream”), a limited liability corporation in which the Company has a 50 percent interest. In the consolidated financial statements, the Company’s investment in Gulfstream was $261million and $293 million as of December 31, 2016 and 2015, respectively, and the Company’s equity earnings in the net income of Gulfstream were $69million and $65 million, respectively, for the years then ended. For the periods indicated above, Gulfstream’s financial statements were audited by other auditors whose report has been furnished to us, and our opinion, insofar as it relates to the amounts included for Gulfstream for 2016 and 2015, is based solely on the report of the other auditors. 

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits and the report of other auditors provide a reasonable basis for our opinion.

In our opinion, based on our audits and, for 2016 and 2015, the report of other auditors, the financial statements referred to above present fairly, in all material respects, the consolidated financial position of The Williams Companies, Inc. at December 31, 2016 and 2015, and the consolidated results of its operations and its cash flows for each of the three years in the period ended December 31, 2016, in conformity with U.S. generally accepted accounting principles. Also, in our opinion, the related financial statement schedules, when considered in relation to the basic financial statements taken as a whole, present fairly in all material respects the information set forth therein.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), The Williams Companies, Inc.'s internal control over financial reporting as of December 31, 2016, based on criteria established in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) and our report dated February 22, 2017 expressed an unqualified opinion thereon.

/s/ Ernst & Young LLP

Tulsa, Oklahoma

February 22, 2017

78

Report of Independent Registered Public Accounting Firm

To the Members of Gulfstream Natural Gas System, L.L.C.

We have audited the balance sheets of Gulfstream Natural Gas System, L.L.C. (the “Company”) as of December 31, 2016 and 2015, and the related statements of operations, comprehensive income, cash flows, and members’ equity for each of the three years in the period ended December 31, 2016. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States) and in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, such financial statements present fairly, in all material respects, the financial position of Gulfstream Natural Gas System, L.L.C. as of December 31, 2016 and 2015, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2016, in conformity with accounting principles generally accepted in the United States of America.

/s/ DELOITTE & TOUCHE LLP

Houston, Texas

February 22, 2017

79

The Williams Companies, Inc.

Consolidated Statement of Operations

		Years Ended December 31,
		2016			2015			2014
	(Millions, except per-share amounts)
Revenues:
Service revenues		$	5,171		$	5,164		$	4,116
Product sales		2,328			2,196			3,521
Total revenues		7,499			7,360			7,637
Costs and expenses:
Product costs		1,725			1,779			3,016
Operating and maintenance expenses		1,580			1,655			1,492
Depreciation and amortization expenses		1,763			1,738			1,176
Selling, general, and administrative expenses		723			741			661
Impairment of goodwill (Note 17)		—			1,098			—
Impairment of certain assets (Note 17)		873			209			52
Net insurance recoveries – Geismar Incident		(7		)	(126		)	(232		)
Other (income) expense – net		142			40			(97		)
Total costs and expenses		6,799			7,134			6,068
Operating income (loss)		700			226			1,569
Equity earnings (losses)		397			335			144
Gain on remeasurement of equity-method investment (Note 2)		—			—			2,544
Impairment of equity-method investments (Note 17)		(430		)	(1,359		)	—
Other investing income (loss) – net		63			27			43
Interest incurred		(1,217		)	(1,118		)	(888		)
Interest capitalized		38			74			141
Other income (expense) – net		74			102			31
Income (loss) from continuing operations before income taxes		(375		)	(1,713		)	3,584
Provision (benefit) for income taxes		(25		)	(399		)	1,249
Income (loss) from continuing operations		(350		)	(1,314		)	2,335
Income (loss) from discontinued operations		—			—			4
Net income (loss)		(350		)	(1,314		)	2,339
Less: Net income (loss) attributable to noncontrolling interests		74			(743		)	225
Net income (loss) attributable to The Williams Companies, Inc.		$	(424	)	$	(571	)	$	2,114
Amounts attributable to The Williams Companies, Inc.:
Income (loss) from continuing operations		$	(424	)	$	(571	)	$	2,110
Income (loss) from discontinued operations		—			—			4
Net income (loss)		$	(424	)	$	(571	)	$	2,114
Basic earnings (loss) per common share:
Income (loss) from continuing operations		$	(.57	)	$	(.76	)	$	2.93
Income (loss) from discontinued operations		—			—			.01
Net income (loss)		$	(.57	)	$	(.76	)	$	2.94
Weighted-average shares (thousands)		750,673			749,271			719,325
Diluted earnings (loss) per common share:
Income (loss) from continuing operations		$	(.57	)	$	(.76	)	$	2.91
Income (loss) from discontinued operations		—			—			.01
Net income (loss)		$	(.57	)	$	(.76	)	$	2.92
Weighted-average shares (thousands)		750,673			749,271			723,641

See accompanying notes.

80

The Williams Companies, Inc.

Consolidated Statement of Comprehensive Income (Loss)

	Years Ended December 31,
	2016			2015			2014
	(Millions)
Net income (loss)	$	(350	)	$	(1,314	)	$	2,339
Other comprehensive income (loss):
Cash flow hedging activities:
Net unrealized gain (loss) from derivative instruments, net of taxes of ($1) in 2016	4			6			—
Reclassifications into earnings of net derivative instruments (gain) loss, net of taxes of $1 in 2016 and 2015	(2		)	(6		)	—
Foreign currency translation activities:
Foreign currency translation adjustments, net of taxes of ($37), $31, and $18 in 2016, 2015, and 2014, respectively	50			(204		)	(96		)
Reclassification into earnings upon sale of foreign entities, net of taxes of ($36) in 2016	119			—			—
Pension and other postretirement benefits:
Prior service credit (cost) arising during the year (Note 10)	—			—			(1		)
Amortization of prior service cost (credit) included in net periodic benefit cost, net of taxes of $2, $3, and $3 in 2016, 2015, and 2014, respectively	(4		)	(3		)	(5		)
Net actuarial gain (loss) arising during the year, net of taxes of $8, ($5) and $60 in 2016, 2015, and 2014, respectively (Note 10)	(15		)	8			(100		)
Amortization of actuarial (gain) loss included in net periodic benefit cost, net of taxes of ($12), ($18), and ($15) in 2016, 2015, and 2014, respectively	20			28			26
Other comprehensive income (loss)	172			(171		)	(176		)
Comprehensive income (loss)	(178		)	(1,485		)	2,163
Less: Comprehensive income (loss) attributable to noncontrolling interests	143			(813		)	206
Comprehensive income (loss) attributable to The Williams Companies, Inc.	$	(321	)	$	(672	)	$	1,957

See accompanying notes.

81

The Williams Companies, Inc.

Consolidated Balance Sheet

	December 31,
	2016			2015
	(Millions, except per-share amounts)
ASSETS
Current assets:
Cash and cash equivalents	$	170		$	100
Trade accounts and other receivables (net of allowance of $6 at December 31, 2016 and $3 at December 31, 2015)	938			1,041
Inventories	138			127
Other current assets and deferred charges	216			259
Total current assets	1,462			1,527
Investments	6,701			7,336
Property, plant, and equipment – net	28,428			29,579
Intangible assets – net of accumulated amortization	9,663			10,017
Regulatory assets, deferred charges, and other	581			561
Total assets	$	46,835		$	49,020
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	623		$	744
Accrued liabilities	1,448			1,078
Commercial paper	93			499
Long-term debt due within one year	785			176
Total current liabilities	2,949			2,497
Long-term debt	22,624			23,812
Deferred income tax liabilities	4,238			4,218
Regulatory liabilities, deferred income, and other	2,978			2,268
Contingent liabilities and commitments (Note 18)
Equity:
Stockholders’ equity:
Common stock (960 million shares authorized at $1 par value; 785 million shares issued at December 31, 2016 and 784 million shares issued at December 31, 2015)	785			784
Capital in excess of par value	14,887			14,807
Retained deficit	(9,649		)	(7,960		)
Accumulated other comprehensive income (loss)	(339		)	(442		)
Treasury stock, at cost (35 million shares of common stock)	(1,041		)	(1,041		)
Total stockholders’ equity	4,643			6,148
Noncontrolling interests in consolidated subsidiaries	9,403			10,077
Total equity	14,046			16,225
Total liabilities and equity	$	46,835		$	49,020

See accompanying notes.

82

The Williams Companies, Inc.

Consolidated Statement of Changes in Equity

	The Williams Companies, Inc., Stockholders
	Common Stock		Capital in Excess of Par Value			Retained Deficit			Accumulated Other Comprehensive Income (Loss)			Treasury Stock			Total Stockholders’ Equity			Noncontrolling Interests			Total Equity
	(Millions)
Balance – December 31, 2013	$	718	$	11,599		$	(6,248	)	$	(164	)	$	(1,041	)	$	4,864		$	4,057		$	8,921
Net income (loss)	—		—			2,114			—			—			2,114			225			2,339
Other comprehensive income (loss)	—		—			—			(157		)	—			(157		)	(19		)	(176		)
Issuance of common stock for acquisition of business (Note 15)	61		3,317			—			—			—			3,378			—			3,378
Noncontrolling interest resulting from acquisition of business (Note 2)	—		—			—			—			—			—			7,502			7,502
Cash dividends – common stock (Note 15)	—		—			(1,412		)	—			—			(1,412		)	—			(1,412		)
Dividends and distributions to noncontrolling interests	—		—			—			—			—			—			(840		)	(840		)
Stock-based compensation and related common stock issuances, net of tax	3		85			—			—			—			88			—			88
Sales of limited partner units of Williams Partners L.P.	—		—			—			—			—			—			55			55
Changes in ownership of consolidated subsidiaries, net	—		(73		)	—			(20		)	—			(93		)	137			44
Contributions from noncontrolling interests	—		—			—			—			—			—			340			340
Deconsolidation of Bluegrass Pipeline (Note 6)	—		—			—			—			—			—			(63		)	(63		)
Other	—		(3		)	(2		)	—			—			(5		)	1			(4		)
Net increase (decrease) in equity	64		3,326			700			(177		)	—			3,913			7,338			11,251
Balance – December 31, 2014	782		14,925			(5,548		)	(341		)	(1,041		)	8,777			11,395			20,172
Net income (loss)	—		—			(571		)	—			—			(571		)	(743		)	(1,314		)
Other comprehensive income (loss)	—		—			—			(101		)	—			(101		)	(70		)	(171		)
Cash dividends – common stock (Note 15)	—		—			(1,836		)	—			—			(1,836		)	—			(1,836		)
Dividends and distributions to noncontrolling interests	—		—			—			—			—			—			(942		)	(942		)
Stock-based compensation and related common stock issuances, net of tax	2		28			—			—			—			30			—			30
Sales of limited partner units of Williams Partners L.P.	—		—			—			—			—			—			59			59
Changes in ownership of consolidated subsidiaries, net	—		(160		)	—			—			—			(160		)	254			94
Contributions from noncontrolling interests	—		—			—			—			—			—			111			111
Other	—		14			(5		)	—			—			9			13			22
Net increase (decrease) in equity	2		(118		)	(2,412		)	(101		)	—			(2,629		)	(1,318		)	(3,947		)
Balance – December 31, 2015	784		14,807			(7,960		)	(442		)	(1,041		)	6,148			10,077			16,225
Net income (loss)	—		—			(424		)	—			—			(424		)	74			(350		)
Other comprehensive income (loss)	—		—			—			103			—			103			69			172
Cash dividends – common stock (Note 15)	—		—			(1,261		)	—			—			(1,261		)	—			(1,261		)
Dividends and distributions to noncontrolling interests	—		—			—			—			—			—			(940		)	(940		)
Stock-based compensation and related common stock issuances, net of tax	1		56			—			—			—			57			—			57
Sales of limited partner units of Williams Partners L.P.	—		—			—			—			—			—			114			114
Changes in ownership of consolidated subsidiaries, net	—		12			—			—			—			12			(18		)	(6		)
Contributions from noncontrolling interests	—		—			—			—			—			—			29			29
Other	—		12			(4		)	—			—			8			(2		)	6
Net increase (decrease) in equity	1		80			(1,689		)	103			—			(1,505		)	(674		)	(2,179		)
Balance – December 31, 2016	$	785	$	14,887		$	(9,649	)	$	(339	)	$	(1,041	)	$	4,643		$	9,403		$	14,046

See accompanying notes.

83

The Williams Companies, Inc.

Consolidated Statement of Cash Flows

	Years Ended December 31,
	2016			2015			2014
	(Millions)
OPERATING ACTIVITIES:
Net income (loss)	$	(350	)	$	(1,314	)	$	2,339
Adjustments to reconcile to net cash provided (used) by operating activities:
Depreciation and amortization	1,763			1,738			1,176
Provision (benefit) for deferred income taxes	(26		)	(337		)	1,264
Impairment of goodwill	—			1,098			—
Impairment of equity-method investments	430			1,359			—
Impairment of and net (gain) loss on sale of assets and businesses	918			215			67
Amortization of stock-based awards	73			82			53
Gain on remeasurement of equity-method investment	—			—			(2,544		)
Cash provided (used) by changes in current assets and liabilities:
Accounts and notes receivable	82			39			(276		)
Inventories	(25		)	105			(36		)
Other current assets and deferred charges	(4		)	4			(44		)
Accounts payable	25			(90		)	(8		)
Accrued liabilities	506			26			(203		)
Other, including changes in noncurrent assets and liabilities	272			(247		)	327
Net cash provided (used) by operating activities	3,664			2,678			2,115
FINANCING ACTIVITIES:
Proceeds from (payments of) commercial paper – net	(409		)	(306		)	572
Proceeds from long-term debt	6,528			9,772			7,321
Payments of long-term debt	(7,091		)	(6,516		)	(1,828		)
Proceeds from issuance of common stock	9			27			3,416
Proceeds from sale of limited partner units of consolidated partnership	114			59			55
Dividends paid	(1,261		)	(1,836		)	(1,412		)
Dividends and distributions paid to noncontrolling interests	(940		)	(942		)	(840		)
Contributions from noncontrolling interests	29			111			340
Payments for debt issuance costs	(9		)	(35		)	(40		)
Special distribution from Gulfstream	—			396			—
Contribution to Gulfstream for repayment of debt	(148		)	(248		)	—
Other – net	—			(1		)	17
Net cash provided (used) by financing activities	(3,178		)	481			7,601
INVESTING ACTIVITIES:
Property, plant, and equipment:
Capital expenditures (1)	(2,051		)	(3,167		)	(4,031		)
Net proceeds from dispositions	30			3			34
Proceeds from sale of businesses, net of cash divested	1,020			—			—
Purchases of businesses, net of cash acquired	—			(112		)	(5,958		)
Purchases of and contributions to equity-method investments	(177		)	(595		)	(482		)
Distributions from unconsolidated affiliates in excess of cumulative earnings	472			404			206
Other – net	290			168			74
Net cash provided (used) by investing activities	(416		)	(3,299		)	(10,157		)
Increase (decrease) in cash and cash equivalents	70			(140		)	(441		)
Cash and cash equivalents at beginning of year	100			240			681
Cash and cash equivalents at end of year	$	170		$	100		$	240
_________
(1) Increases to property, plant, and equipment	$	(1,912	)	$	(3,024	)	$	(3,916	)
Changes in related accounts payable and accrued liabilities	(139		)	(143		)	(115		)
Capital expenditures	$	(2,051	)	$	(3,167	)	$	(4,031	)

See accompanying notes.

84

The Williams Companies, Inc.

Notes to Consolidated Financial Statements

Note 1 – General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies

General

Unless the context clearly indicates otherwise, references in this report to “Williams,” “we,” “our,” “us,” or like terms refer to The Williams Companies, Inc. and its subsidiaries. Unless the context clearly indicates otherwise, references to “Williams,” “we,” “our,” and “us” include the operations in which we own interests accounted for as equity-method investments that are not consolidated in our financial statements. When we refer to our equity investees by name, we are referring exclusively to their businesses and operations.

Financial Repositioning

In January 2017, we announced agreements with Williams Partners L.P. (WPZ), wherein we permanently waived the general partner’s incentive distribution rights (IDRs) and converted our 2 percent general partner interest in WPZ to a non-economic interest in exchange for 289 million newly issued WPZ common units. Pursuant to this agreement, we also purchased approximately 277 thousand WPZ common units for $10 million. Additionally, we purchased approximately 59 million common units of WPZ at a price of $36.08586 per unit in a private placement transaction, funded with proceeds from our equity offering (see Note 15 – Stockholders’ Equity). According to the terms of this agreement, following WPZ’s quarterly distribution in February 2017, we paid additional consideration of approximately $50 millionto WPZ for these units. Following these transactions, we own a 74 percent limited partner interest in WPZ.

Termination of WPZ Merger Agreement

On May 12, 2015, we entered into an agreement for a unit-for-stock transaction whereby we would have acquired all of the publicly held outstanding common units of WPZ in exchange for shares of our common stock (WPZ Merger Agreement).

On September 28, 2015, we entered into a Termination Agreement and Release (Termination Agreement), terminating the WPZ Merger Agreement. Under the terms of the Termination Agreement, we were required to pay a $428 million termination fee to WPZ, at which time we owned approximately 60 percent, including the interests of the general partner and IDRs. Such termination fee settled through a reduction of quarterly incentive distributions we were entitled to receive from WPZ (such reduction not to exceed $209 million per quarter). The distributions from WPZ in November 2015, February 2016, and May 2016 were reduced by $209 million, $209 million, and $10 million, respectively, related to this termination fee.

ACMP Merger

On February 2, 2015, Williams Partners L.P. merged with and into Access Midstream Partners, L.P. (ACMP Merger). For the purpose of these financial statements and notes, WPZ refers to the renamed merged partnership, while Pre-merger Access Midstream Partners, L.P. (ACMP) and Pre-merger Williams Partners L.P. (Pre-merger WPZ) refer to the separate partnerships prior to the consummation of the ACMP Merger and subsequent name change. The net assets of Pre-merger WPZ and ACMP were combined at our historical basis. Our basis in ACMP reflected our business combination accounting resulting from acquiring control of ACMP on July 1, 2014.

Description of Business

We are a Delaware corporation whose common stock is listed and traded on the New York Stock Exchange. Our operations are located principally in the United States and are organized into the Williams Partners and Williams NGL & Petchem Services reportable segments. All remaining business activities are included in Other. For periods after the ACMP Acquisition (see Note 2 – Acquisitions), the acquired ACMP business is reported within Williams Partners. For periods prior to the ACMP Acquisition, the results associated with our former equity-method investment in ACMP are reported within Other.

85

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Williams Partners

Williams Partners consists of our consolidated master limited partnership, WPZ, and primarily includes gas pipeline and midstream businesses.

WPZ’s gas pipeline businesses primarily consist of two interstate natural gas pipelines, which are Transcontinental Gas Pipe Line Company, LLC (Transco) and Northwest Pipeline LLC (Northwest Pipeline), and several joint venture investments in interstate and intrastate natural gas pipeline systems, including a 50 percent equity-method investment in Gulfstream Natural Gas System, L.L.C. (Gulfstream), and a 41 percent interest in Constitution Pipeline Company, LLC (Constitution) (a consolidated entity), which is under development.

WPZ’s midstream businesses primarily consist of (1) natural gas gathering, treating, compression, and processing; (2) natural gas liquid (NGL) fractionation, storage, and transportation; (3) crude oil production handling and transportation; and (4) olefins production. The primary service areas are concentrated in major producing basins in Colorado, Texas, Oklahoma, Kansas, New Mexico, Wyoming, the Gulf of Mexico, Louisiana, Pennsylvania, West Virginia, New York, and Ohio which include the Barnett, Eagle Ford, Haynesville, Marcellus, Niobrara, and Utica Shale plays as well as the Mid-Continent region.

The midstream businesses include equity-method investments in natural gas gathering and processing assets and NGL fractionation and transportation assets, including a 62 percent equity-method investment in Utica East Ohio Midstream, LLC (UEOM), a 50 percent equity-method investment in the Delaware basin gas gathering system (DBJV) in the Mid-Continent region, a 69 percent equity-method investment in Laurel Mountain Midstream, LLC (Laurel Mountain), a 58 percent equity-method investment in Caiman Energy II, LLC (Caiman II), a 60 percent equity-method investment in Discovery Producer Services, LLC (Discovery), a 50 percent equity-method investment in Overland Pass Pipeline, LLC (OPPL), and Appalachia Midstream Services, LLC, which owns equity-method investments with an approximate average 41 percent interest in multiple gathering systems in the Marcellus Shale (Appalachia Midstream Investments).

The midstream businesses also included our Canadian midstream operations, which were comprised of an oil sands offgas processing plant located near Fort McMurray, Alberta, and an NGL/olefin fractionation facility at Redwater, Alberta. In September 2016, we completed the sale of our Canadian operations. (See Note 3 – Divestiture.)

Williams NGL & Petchem Services

Williams NGL & Petchem Services includes certain other domestic olefins pipeline assets, a liquids extraction plant located near Fort McMurray, Alberta, that began operations in March 2016, and a propane dehydrogenation facility under development in Canada. In September 2016, we completed the sale of our Canadian operations. (See Note 3 – Divestiture.)

Other

Other includes other business activities that are not operating segments, as well as corporate operations.

Basis of Presentation

Canada Dropdown

In February 2014, we contributed certain Canadian operations to Pre-merger WPZ (Canada Dropdown) for total consideration of $56 million of cash from Pre-merger WPZ (including a $31 million post-closing adjustment received in the second quarter of 2014), 25,577,521 Pre-merger WPZ Class D limited-partner units, and an increase in the capital account of its general partner to allow us to maintain our 2 percent general partner interest. In lieu of cash distributions, the Class D units received quarterly distributions of additional paid-in-kind Class D units.

86

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

In October 2014, a purchase price adjustment was finalized whereby we paid $56 million in cash to Pre-merger WPZ in the fourth quarter and waived $2 million in payment of IDRs with respect to the November 2014 distribution.

Consolidated master limited partnership

As of December 31, 2016, we owned approximately 60 percent of the interests in WPZ, a variable interest entity (VIE) (see Note 4 – Variable Interest Entities), including the interests of the general partner, which are wholly owned by us, and IDRs.

During 2016, WPZ issued 3,273,601 common units pursuant to an equity distribution agreement between WPZ and certain banks resulting in net proceeds of $115 million. WPZ also implemented a distribution reinvestment program in the third quarter of 2016 resulting in 7,891,414 common units issued associated with reinvested distributions of $260 million, of which $250 million related to our participation. In addition, in August 2016, WPZ completed an equity issuance of 6,975,446 common units sold to us in a private placement transaction for an aggregate purchase price of $250 million.

The above transactions, WPZ’s quarterly distribution of additional paid-in-kind Class B units to us, and other equity issuances by WPZ had the combined net impact of decreasing Noncontrolling interests in consolidated subsidiaries by $18 million, and increasing Capital in excess of par value by $12 million and Deferred income tax liabilities by $6 million in the Consolidated Balance Sheet.

WPZ is self-funding and maintains separate lines of bank credit and cash management accounts and also has a commercial paper program. (See Note 14 – Debt, Banking Arrangements, and Leases.) Cash distributions from WPZ to all partners, including us, are governed by WPZ’s partnership agreement.

Discontinued operations

Unless indicated otherwise, the information in the Notes to Consolidated Financial Statements relates to our continuing operations.

Significant risks and uncertainties

We have announced plans to monetize our olefins production plant in Geismar, Louisiana, as well as other select assets that are not core to our strategy. As we pursue these other select asset monetizations, it is possible that we may incur impairments of certain equity-method investments, property, plant, and equipment, and intangible assets. Such impairments could potentially be caused by indications of fair value implied through the monetization process or, in the case of asset dispositions that are part of a broader asset group, the impact of the loss of future estimated cash flows.

Summary of Significant Accounting Policies

Principles of consolidation

The consolidated financial statements include the accounts of all entities that we control and our proportionate interest in the accounts of certain ventures in which we own an undivided interest. Management’s judgment is required to evaluate whether we control an entity. Key areas of that evaluation include:

• Determining whether an entity is a VIE;

• Determining whether we are the primary beneficiary of a VIE, including evaluating which activities of the VIE most significantly impact its economic performance and the degree of power that we and our related parties have over those activities through our variable interests;

• Identifying events that require reconsideration of whether an entity is a VIE and continuously evaluating whether we are a VIE’s primary beneficiary;

87

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

• Evaluating whether other owners in entities that are not VIEs are able to effectively participate in significant decisions that would be expected to be made in the ordinary course of business such that we do not have the power to control such entities.

We apply the equity method of accounting to investments over which we exercise significant influence but do not control.

Equity-method investment basis differences

Differences between the cost of our equity-method investments and our underlying equity in the net assets of investees are accounted for as if the investees were consolidated subsidiaries. Equity earnings (losses) in the Consolidated Statement of Operations includes our allocable share of net income (loss) of investees adjusted for any depreciation and amortization, as applicable, associated with basis differences.

Use of estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual results could differ from those estimates.

Significant estimates and assumptions include:

• Impairment assessments of investments, property, plant, and equipment, goodwill, and other identifiable intangible assets;

• Litigation-related contingencies;

• Environmental remediation obligations;

• Realization of deferred income tax assets;

• Depreciation and/or amortization of equity-method investment basis differences;

• Asset retirement obligations;

• Pension and postretirement valuation variables;

• Acquisition related purchase price allocations.

These estimates are discussed further throughout these notes.

Regulatory accounting

Transco and Northwest Pipeline are regulated by the Federal Energy Regulatory Commission (FERC). Their rates, which are established by the FERC, are designed to recover the costs of providing the regulated services, and their competitive environment makes it probable that such rates can be charged and collected. Therefore, our management has determined that it is appropriate under Accounting Standards Codification (ASC) Topic 980, “Regulated Operations,” to account for and report regulatory assets and liabilities related to these operations consistent with the economic effect of the way in which their rates are established. Accounting for these operations that are regulated can differ from the accounting requirements for nonregulated operations. For example, for regulated operations, allowance for funds used during construction (AFUDC) represents the estimated cost of debt and equity funds applicable to utility plant in process of construction and is capitalized as a cost of property, plant, and equipment because it constitutes an actual cost of construction under established regulatory practices; nonregulated operations are only allowed to capitalize

88

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

the cost of debt funds related to construction activities, while a component for equity is prohibited. The components of our regulatory assets and liabilities relate to the effects of deferred taxes on equity funds used during construction, asset retirement obligations, fuel cost differentials, levelized incremental depreciation, negative salvage, and pension and other postretirement benefits. Our current and noncurrent regulatory asset and liability balances for the years ended December 31, 2016 and 2015 are as follows:

	December 31,
	2016		2015
	(Millions)
Current assets reported within Other current assets and deferred charges	$	91	$	84
Noncurrent assets reported within Regulatory assets, deferred charges, and other	387		370
Total regulated assets	$	478	$	454
Current liabilities reported within Accrued liabilities	$	11	$	4
Noncurrent liabilities reported within Regulatory liabilities, deferred income, and other	498		434
Total regulated liabilities	$	509	$	438

Cash and cash equivalents

Cash and cash equivalents in the Consolidated Balance Sheet includes amounts primarily invested in funds with high-quality, short-term securities and instruments that are issued or guaranteed by the U.S. government. These have maturity dates of three months or less when acquired.

Accounts receivable

Accounts receivable are carried on a gross basis, with no discounting, less an allowance for doubtful accounts. We estimate the allowance for doubtful accounts based on existing economic conditions, the financial condition of our customers, and the amount and age of past due accounts. We consider receivables past due if full payment is not received by the contractual due date. Interest income related to past due accounts receivable is generally recognized at the time full payment is received or collectability is assured. Past due accounts are generally written off against the allowance for doubtful accounts only after all collection attempts have been exhausted.

Inventories

Inventories in the Consolidated Balance Sheet primarily consist of natural gas liquids, olefins, natural gas in underground storage, and materials and supplies and are stated at the lower of cost or market. The cost of inventories is primarily determined using the average-cost method.

Property, plant, and equipment

Property, plant, and equipment is recorded at cost. We base the carrying value of these assets on estimates, assumptions, and judgments relative to capitalized costs, useful lives, and salvage values.

As regulated entities, Northwest Pipeline and Transco provide for depreciation using the straight-line method at FERC-prescribed rates. Depreciation for nonregulated entities is provided primarily on the straight-line method over estimated useful lives, except for certain offshore facilities that apply an accelerated depreciation method.

Gains or losses from the ordinary sale or retirement of property, plant, and equipment for regulated pipelines are credited or charged to accumulated depreciation. Other gains or losses are recorded in Other (income) expense – net included in Operating income (loss) in the Consolidated Statement of Operations.

Ordinary maintenance and repair costs are generally expensed as incurred. Costs of major renewals and replacements are capitalized as property, plant, and equipment.

89

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

We record a liability and increase the basis in the underlying asset for the present value of each expected future asset retirement obligation (ARO) at the time the liability is initially incurred, typically when the asset is acquired or constructed. As regulated entities, Northwest Pipeline and Transco offset the depreciation of the underlying asset that is attributable to capitalized ARO cost to a regulatory asset as management expects to recover these amounts in future rates. We measure changes in the liability due to passage of time by applying an interest rate to the liability balance. This amount is recognized as an increase in the carrying amount of the liability and as a corresponding accretion expense included in Operating and maintenance expenses in the Consolidated Statement of Operations, except for regulated entities, for which the liability is offset by a regulatory asset. The regulatory asset is amortized commensurate with our collection of those costs in rates.

Measurements of AROs include, as a component of future expected costs, an estimate of the price that a third party would demand, and could expect to receive, for bearing the uncertainties inherent in the obligations, sometimes referred to as a market-risk premium.

Goodwill

Goodwill included within Intangible assets – net of accumulated amortization in the Consolidated Balance Sheet represents the excess of the consideration, plus the fair value of any noncontrolling interest or any previously held equity interest, over the fair value of the net assets acquired. It is not subject to amortization but is evaluated annually as of October 1 for impairment or more frequently if impairment indicators are present that would indicate it is more likely than not that the fair value of the reporting unit is less than its carrying amount. As part of the evaluation, we compare our estimate of the fair value of the reporting unit with its carrying value, including goodwill. If the carrying value of the reporting unit exceeds its fair value, a computation of the implied fair value of the goodwill is compared with its related carrying value. If the carrying value of the reporting unit goodwill exceeds the implied fair value of that goodwill, an impairment loss is recognized in the amount of the excess. Judgments and assumptions are inherent in our management’s estimates of fair value.

Other intangible assets

Our identifiable intangible assets included within Intangible assets – net of accumulated amortization in the Consolidated Balance Sheet are primarily related to gas gathering, processing, and fractionation contractual customer relationships. Our intangible assets are amortized on a straight-line basis over the period in which these assets contribute to our cash flows. We evaluate these assets for changes in the expected remaining useful lives and would reflect any changes prospectively through amortization over the revised remaining useful life.

Impairment of property, plant, and equipment, other identifiable intangible assets, and investments

We evaluate our property, plant, and equipment and other identifiable intangible assets for impairment when events or changes in circumstances indicate, in our management’s judgment, that the carrying value of such assets may not be recoverable. When an indicator of impairment has occurred, we compare our management’s estimate of undiscounted future cash flows attributable to the assets to the carrying value of the assets to determine whether an impairment has occurred and we may apply a probability-weighted approach to consider the likelihood of different cash flow assumptions and possible outcomes including selling in the near term or holding for the remaining estimated useful life. If an impairment of the carrying value has occurred, we determine the amount of the impairment recognized in the financial statements by estimating the fair value of the assets and recording a loss for the amount that the carrying value exceeds the estimated fair value. This evaluation is performed at the lowest level for which separately identifiable cash flows exist.

For assets identified to be disposed of in the future and considered held for sale, we compare the carrying value to the estimated fair value less the cost to sell to determine if recognition of an impairment is required. Until the assets are disposed of, the estimated fair value, which includes estimated cash flows from operations until the assumed date of sale, is recalculated when related events or circumstances change.

90

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

We evaluate our investments for impairment when events or changes in circumstances indicate, in our management’s judgment, that the carrying value of such investments may have experienced an other-than-temporary decline in value. When evidence of loss in value has occurred, we compare our estimate of fair value of the investment to the carrying value of the investment to determine whether an impairment has occurred. If the estimated fair value is less than the carrying value and we consider the decline in value to be other-than-temporary, the excess of the carrying value over the fair value is recognized in the consolidated financial statements as an impairment charge.

Judgments and assumptions are inherent in our management’s estimate of undiscounted future cash flows and an asset’s or investment’s fair value. Additionally, judgment is used to determine the probability of sale with respect to assets considered for disposal.

Deferred income

We record a liability for deferred income related to cash received from customers in advance of providing our services.  Such amounts are generally recognized in revenue upon satisfying our performance obligations, primarily providing services based on units of production or over remaining contractual service periods ranging from 1 to 25 years.  Deferred incomeis reflected within Accrued liabilitiesand Regulatory liabilities, deferred income, and otheron the Consolidated Balance Sheet.  (See Note 13 – Accrued Liabilities.) 

During 2016, we received cash proceeds totaling $820 million associated with restructuring certain gas gathering contracts in the Barnett Shale and Mid-Continent regions. The proceeds were recorded as deferred incomeand are being amortized into income in 2016 and future periods.

In October 2016, we received $104 million of newly constructed assets as part of a noncash investing transaction with a customer for which we provide production handling and other services. The transaction was recorded in Property, plant, and equipment – net and deferred income in the Consolidated Balance Sheet and is being amortized based on units of production through 2024. Due to the noncash nature of this transaction, it is not presented within the Consolidated Statement of Cash Flows.

Contingent liabilities

We record liabilities for estimated loss contingencies, including environmental matters, when we assess that a loss is probable and the amount of the loss can be reasonably estimated. These liabilities are calculated based upon our assumptions and estimates with respect to the likelihood or amount of loss and upon advice of legal counsel, engineers, or other third parties regarding the probable outcomes of the matters. These calculations are made without consideration of any potential recovery from third parties. We recognize insurance recoveries or reimbursements from others when realizable. Revisions to these liabilities are generally reflected in income when new or different facts or information become known or circumstances change that affect the previous assumptions or estimates.

Cash flows from revolving credit facilities and commercial paper program

Proceeds and payments related to borrowings under our credit facilities are reflected in the financing activities in the Consolidated Statement of Cash Flows on a gross basis. Proceeds and payments related to borrowings under our commercial paper program are reflected in the financing activities in the Consolidated Statement of Cash Flows on a net basis, as the outstanding notes generally have maturity dates less than three months from the date of issuance. (See Note 14 – Debt, Banking Arrangements, and Leases.)

Treasury stock

Treasury stock purchases are accounted for under the cost method whereby the entire cost of the acquired stock is recorded as Treasury stock in the Consolidated Balance Sheet. Gains and losses on the subsequent reissuance of shares are credited or charged to Capital in excess of par value in the Consolidated Balance Sheet using the average-cost method.

91

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Derivative instruments and hedging activities

We may utilize derivatives to manage a portion of our commodity price risk. These instruments consist primarily of swaps, futures, and forward contracts involving short- and long-term purchases and sales of energy commodities. We report the fair value of derivatives, except those for which the normal purchases and normal sales exception has been elected, in Other current assets and deferred charges; Regulatory assets, deferred charges, and other;Accrued liabilities; or Regulatory liabilities, deferred income, and other in the Consolidated Balance Sheet. We determine the current and noncurrent classification based on the timing of expected future cash flows of individual trades. We report these amounts on a gross basis. Additionally, we report cash collateral receivables and payables with our counterparties on a gross basis. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk.)

The accounting for the changes in fair value of a commodity derivative can be summarized as follows:

Derivative Treatment	Accounting Method
Normal purchases and normal sales exception	Accrual accounting
Designated in a qualifying hedging relationship	Hedge accounting
All other derivatives	Mark-to-market accounting

We may elect the normal purchases and normal sales exception for certain short- and long-term purchases and sales of physical energy commodities. Under accrual accounting, any change in the fair value of these derivatives is not reflected on the balance sheet after the initial election of the exception.

We may also designate a hedging relationship for certain commodity derivatives. For a derivative to qualify for designation in a hedging relationship, it must meet specific criteria and we must maintain appropriate documentation. We establish hedging relationships pursuant to our risk management policies. We evaluate the hedging relationships at the inception of the hedge and on an ongoing basis to determine whether the hedging relationship is, and is expected to remain, highly effective in achieving offsetting changes in fair value or cash flows attributable to the underlying risk being hedged. We also regularly assess whether the hedged forecasted transaction is probable of occurring. If a derivative ceases to be or is no longer expected to be highly effective, or if we believe the likelihood of occurrence of the hedged forecasted transaction is no longer probable, hedge accounting is discontinued prospectively, and future changes in the fair value of the derivative are recognized currently in Product sales or Product costsin the Consolidated Statement of Operations.

For commodity derivatives designated as a cash flow hedge, the effective portion of the change in fair value of the derivative is reported in Accumulated other comprehensive income (loss) (AOCI) in the Consolidated Balance Sheet and reclassified into earnings in the period in which the hedged item affects earnings. Any ineffective portion of the derivative’s change in fair value is recognized currently in Product sales or Product costs in the Consolidated Statement of Operations. Gains or losses deferred in AOCI associated with terminated derivatives, derivatives that cease to be highly effective hedges, derivatives for which the forecasted transaction is reasonably possible but no longer probable of occurring, and cash flow hedges that have been otherwise discontinued remain in AOCI until the hedged item affects earnings. If it becomes probable that the forecasted transaction designated as the hedged item in a cash flow hedge will not occur, any gain or loss deferred in AOCI is recognized in Product sales or Product costs in the Consolidated Statement of Operations at that time. The change in likelihood of a forecasted transaction is a judgmental decision that includes qualitative assessments made by management.

For commodity derivatives that are not designated in a hedging relationship, and for which we have not elected the normal purchases and normal sales exception, we report changes in fair value currently in Product salesorProduct costsin the Consolidated Statement of Operations.

Certain gains and losses on derivative instruments included in the Consolidated Statement of Operations are netted together to a single net gain or loss, while other gains and losses are reported on a gross basis. Gains and losses recorded

92

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

on a net basis include unrealized gains and losses on all derivatives that are not designated as hedges and for which we have not elected the normal purchases and normal sales exception.

Realized gains and losses on derivatives that require physical delivery, as well as natural gas derivatives for NGL processing activities and which are not held for trading purposes nor were entered into as a pre-contemplated buy/sell arrangement, are recorded on a gross basis.

Revenue recognition

Revenues

As a result of the ratemaking process, certain revenues collected by us may be subject to refunds upon the issuance of final orders by the FERC in pending rate proceedings. We record estimates of rate refund liabilities considering our and other third-party regulatory proceedings, advice of counsel, and other risks.

Service revenues

Revenues from our interstate natural gas pipeline businesses include services pursuant to long-term firm transportation and storage agreements. These agreements provide for a reservation charge based on the volume of contracted capacity and a commodity charge based on the volume of gas delivered, both at rates specified in our FERC tariffs. We recognize revenues for reservation charges ratably over the contract period regardless of the volume of natural gas that is transported or stored. Revenues for commodity charges, from both firm and interruptible transportation services and storage injection and withdrawal services, are recognized when natural gas is delivered at the agreed upon delivery point or when natural gas is injected or withdrawn from the storage facility.

Certain revenues from our midstream operations include those derived from natural gas gathering, processing, treating, and compression services and are performed under volumetric-based fee contracts. These revenues are recorded when services have been performed.

Certain of our gas gathering and processing agreements have minimum volume commitments. If a customer under such an agreement fails to meet its minimum volume commitment for a specified period, generally measured on an annual basis, it is obligated to pay a contractually determined fee based upon the shortfall between actual production volumes and the minimum volume commitment for that period. The revenue associated with minimum volume commitments is recognized in the period that the actual shortfall is determined and is no longer subject to future reduction or offset, which is generally at the end of the annual period or fourth quarter.

Crude oil gathering and transportation revenues and offshore production handling fees are recognized when the services have been performed. Certain offshore production handling contracts contain fixed payment terms that result in the deferral of revenues until such services have been performed or such capacity has been made available.

Storage revenues from our midstream operations associated with prepaid contracted storage capacity contracts are recognized on a straight-line basis over the life of the contract as services are provided.

Product sales

In the course of providing transportation services to customers of our interstate natural gas pipeline businesses, we may receive different quantities of gas from shippers than the quantities delivered on behalf of those shippers. The resulting imbalances are primarily settled through the purchase and sale of gas with our customers under terms provided for in our FERC tariffs. Revenue is recognized from the sale of gas upon settlement of the transportation and exchange imbalances.

93

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

We market NGLs, crude oil, natural gas, and olefins that we purchase from our producer customers as part of the overall service provided to producers. Revenues from marketing NGLs are recognized when the products have been sold and delivered.

Under our keep-whole and percent-of-liquids processing contracts, we retain the rights to all or a portion of the NGLs extracted from the producers’ natural gas stream and recognize revenues when the extracted NGLs are sold and delivered.

Our domestic olefins business produces olefins from purchased or produced feedstock and we recognize revenues when the olefins are sold and delivered.

Our Canadian businesses that were sold in September 2016 had processing and fractionation operations where we retained certain NGLs and olefins from an upgrader’s offgas stream and we recognized revenues when the fractionated products were sold and delivered.

Interest capitalized

We capitalize interest during construction on major projects with construction periods of at least 3 months and a total project cost in excess of $1 million. Interest is capitalized on borrowed funds and, where regulation by the FERC exists, on internally generated funds (equity AFUDC). The latter is included in Other income (expense) – net below Operating income (loss) in the Consolidated Statement of Operations. The rates used by regulated companies are calculated in accordance with FERC rules. Rates used by nonregulated companies are based on our average interest rate on debt.

Employee stock-based awards

We recognize compensation expense on employee stock-based awards, net of estimated forfeitures, on a straight-line basis. (See Note 16 – Equity-Based Compensation.)

Pension and other postretirement benefits

The funded status of each of the pension and other postretirement benefit plans is recognized separately in the Consolidated Balance Sheet as either an asset or liability. The funded status is the difference between the fair value of plan assets and the plan’s benefit obligation. The plans’ benefit obligations and net periodic benefit costs are actuarially determined and impacted by various assumptions and estimates. (See Note 10 – Employee Benefit Plans.)

The discount rates are determined separately for each of our pension and other postretirement benefit plans based on an approach specific to our plans. The year-end discount rates are determined considering a yield curve comprised of high-quality corporate bonds and the timing of the expected benefit cash flows of each plan.

The expected long-term rates of return on plan assets are determined by combining a review of the historical returns within the portfolio, the investment strategy included in the plans’ investment policy statement, and capital market projections for the asset classes in which the portfolio is invested, as well as the weighting of each asset class.

Unrecognized actuarial gains and losses and unrecognized prior service costs and credits are deferred and recorded in AOCI or, for Transco and Northwest Pipeline, as a regulatory asset or liability, until amortized as a component of net periodic benefit cost. Unrecognized actuarial gains and losses in excess of 10 percent of the greater of the benefit obligation or the market-related value of plan assets are amortized over the participants’ average remaining future years of service, which is approximately 13 years for our pension plans and approximately 7 years for our other postretirement benefit plans. Unrecognized prior service costs and credits for the other postretirement benefit plans are amortized on a straight line basis over the average remaining years of service to eligibility for eligible plan participants, which is approximately 4 years.

94

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

The expected return on plan assets component of net periodic benefit cost is calculated using the market-related value of plan assets. For our pension plans, the market-related value of plan assets is equal to the fair value of plan assets adjusted to reflect the amortization of gains or losses associated with the difference between the expected and actual return on plan assets over a 5-year period. Additionally, the market-related value of assets may be no more than 110 percent or less than 90 percent of the fair value of plan assets at the beginning of the year. The market-related value of plan assets for our other postretirement benefit plans is equal to the unadjusted fair value of plan assets at the beginning of the year.

Income taxes

We include the operations of our domestic corporate subsidiaries and income from our subsidiary partnerships in our consolidated federal income tax return and also file tax returns in various foreign and state jurisdictions as required. Deferred income taxes are computed using the liability method and are provided on all temporary differences between the financial basis and the tax basis of our assets and liabilities. Our management’s judgment and income tax assumptions are used to determine the levels, if any, of valuation allowances associated with deferred tax assets.

Earnings (loss) per common share

Basic earnings (loss) per common share in the Consolidated Statement of Operations is based on the sum of the weighted-average number of common shares outstanding and vested restricted stock units. Diluted earnings (loss) per common share in the Consolidated Statement of Operations includes any dilutive effect of stock options, nonvested restricted stock units, and convertible debt, unless otherwise noted. Diluted earnings (loss) per common share are calculated using the treasury-stock method.

Foreign currency translation

Certain of our foreign subsidiaries that used the Canadian dollar as their functional currency were sold in 2016. The assets and liabilities of such foreign subsidiaries were translated at the spot rate in effect at the applicable reporting date, and the combined statements of operations were translated into the U.S. dollar at the average exchange rates in effect during the applicable period. The resulting cumulative translation adjustment was recorded as a separate component of AOCI in the Consolidated Balance Sheet.

Transactions denominated in currencies other than the functional currency were recorded based on exchange rates at the time such transactions arose. Subsequent changes in exchange rates when the transactions were settled resulted in transaction gains and losses which were reflected in Other (income) expense – net within Costs and expenses in the Consolidated Statement of Operations. Substantially all of our Canadian operations were sold in September 2016.

Accounting standards issued but not yet adopted

In January 2017, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2017-04 “Intangibles - Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment” (ASU 2017-04). ASU 2017-04 modifies the concept of goodwill impairment to represent the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill. Under ASU 2017-04, entities will no longer be required to determine the implied fair value of goodwill by assigning the fair value of a reporting unit to its individual assets and liabilities as if that reporting unit had been acquired in a business combination. ASU 2017-04 is effective for goodwill impairment testing for interim and annual periods beginning after December 15, 2019, and requires a prospective transition. Early adoption is permitted for interim and annual goodwill impairment tests performed after January 1, 2017, and we plan to adopt this standard in 2017. Our Williams Partners reportable segment has $47 million of goodwill included in Intangible assets – net of accumulated amortization in the Consolidated Balance Sheet (see Note 12 – Goodwill and Other Intangible Assets).

In August 2016, the FASB issued ASU 2016-15 “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments” (ASU 2016-15). ASU 2016-15 provides specific guidance on eight cash flow classification issues, including debt prepayment or debt extinguishment costs and distributions received from equity

95

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

method investees, to reduce diversity in practice. ASU 2016-15 is effective for interim and annual periods beginning after December 15, 2017. Early adoption is permitted. ASU 2016-15 requires a retrospective transition. We are evaluating the impact of ASU 2016-15 on our consolidated financial statements.

In June 2016, the FASB issued ASU 2016-13 “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments” (ASU 2016-13). ASU 2016-13 changes the impairment model for most financial assets and certain other instruments. For trade and other receivables, held-to-maturity debt securities, loans, and other instruments, entities will be required to use a new forward-looking “expected loss” model that generally will result in the earlier recognition of allowances for losses. The guidance also requires increased disclosures. ASU 2016-13 is effective for interim and annual periods beginning after December 15, 2019. Early adoption is permitted. ASU 2016-13 requires varying transition methods for the different categories of amendments. We are evaluating the impact of ASU 2016-13 on our consolidated financial statements. Although we do not expect ASU 2016-13 to have a significant impact, it will impact our trade receivables as the related allowance for credit losses will be recognized earlier under the expected loss model than under our current policy.

In March 2016, the FASB issued ASU 2016-09 “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting” (ASU 2016-09). The objective of ASU 2016-09 is to simplify several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. ASU 2016-09 is effective for interim and annual periods beginning after December 15, 2016. We adopted ASU 2016-09 effective January 1, 2017. The standard requires varying transition methods for the different categories of amendments. ASU 2016-09 will not have a material effect on our consolidated financial statements.

In February 2016, the FASB issued ASU 2016-02 “Leases (Topic 842)” (ASU 2016-02). ASU 2016-02 establishes a comprehensive new lease accounting model. ASU 2016-02 clarifies the definition of a lease, requires a dual approach to lease classification similar to current lease classifications, and causes lessees to recognize leases on the balance sheet as a lease liability with a corresponding right-of-use asset. ASU 2016-02 is effective for interim and annual periods beginning after December 15, 2018. Early adoption is permitted. ASU 2016-02 requires a modified retrospective transition for capital or operating leases existing at or entered into after the beginning of the earliest comparative period presented in the financial statements. We are reviewing contracts to identify leases, particularly reviewing the applicability of ASU 2016-02 to contracts involving easements/rights-of-way.

In May 2014, the FASB issued ASU 2014-09 establishing Accounting Standards Codification (ASC) Topic 606, “Revenue from Contracts with Customers” (ASC 606). ASC 606 establishes a comprehensive new revenue recognition model designed to depict the transfer of goods or services to a customer in an amount that reflects the consideration the entity expects to be entitled to receive in exchange for those goods or services and requires significantly enhanced revenue disclosures. In August 2015, the FASB issued ASU 2015-14 “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date” (ASU 2015-14). Per ASU 2015-14, the standard is effective for interim and annual reporting periods beginning after December 15, 2017. ASC 606 allows either full retrospective or modified retrospective transition and early adoption is permitted for annual periods beginning after December 15, 2016.

We continue to evaluate the impact the standard may have on our financial statements. For each revenue contract type, we are conducting a formal contract review process to evaluate the impact, if any, that the new revenue standard may have. We have substantially completed that process, but continue to evaluate our accounting for noncash consideration, which exists in contracts where we receive commodities as full or partial consideration, contracts with a significant financing component, which may exist in situations where the timing of the consideration we received varies significantly from the timing of the service we provide, and the accounting for contributions in aid of construction. As such, we are unable to determine the potential impact upon the amount and timing of revenue recognition and related disclosures. Additionally, we have identified possible financial system and internal control changes necessary for adoption. We currently anticipate utilizing a modified retrospective transition upon the adoption of ASC 606 as of January 1, 2018.

96

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Note 2 – Acquisitions

ACMP

On December 20, 2012, we purchased approximately 24 percent of ACMP’s outstanding limited partnership units and 50 percent of the ACMP general partner 2 percent interest which included IDRs for approximately $2.19 billion in cash, including transaction costs. We accounted for these acquired interests as equity-method investments.

On July 1, 2014, we acquired control of ACMP (ACMP Acquisition) through the acquisition of an additional 26 percent of ACMP’s outstanding limited partnership units and the remaining 50 percent interest in the general partner for $5.995 billion in cash. The acquisition was funded through the issuance of equity (see Note 15 – Stockholders' Equity) and debt, credit facility borrowings, and cash on hand.

At the time of acquisition, ACMP owned, operated, developed, and acquired natural gas gathering systems and other midstream energy assets. The purpose of the acquisition was to enhance our position in the Marcellus and Utica Shale plays, provide additional diversity via the Eagle Ford, Haynesville, Barnett, Mid-Continent, and Niobrara areas, and to fortify our stable, fee-based business model and support our dividend growth strategy.

Our basis in ACMP reflects business combination accounting, which, among other things, requires identifiable assets acquired and liabilities assumed to be measured at their acquisition-date fair values. Prior to the ACMP Acquisition we accounted for our investment in ACMP using the equity method. The acquisition-date fair value of our equity-method investment in ACMP was $4.6 billion. As a result of remeasuring our equity-method investment to fair value, for the year ended December 31, 2014 we recognized a $2.5 billion noncash gain within the Gain on remeasurement of equity-method investment line item in the Consolidated Statement of Operations.

The valuation techniques used to measure the acquisition-date fair value of the ACMP Acquisition, including our previous equity-method investment in ACMP, consisted of valuing the limited partner units and general partner interest separately. The limited partner units, consisting of common and Class B units, were valued based on ACMP’s closing common unit price at July 1, 2014. The general partner interest, including IDRs, was valued on a noncontrolling basis using an income approach based on a discounted cash flow analysis and a market comparison analysis based on comparable guideline companies and an implied fair value from our purchase.

The following table presents the allocation of the acquisition-date fair value of the major classes of the assets acquired, which are presented in the Williams Partners segment, liabilities assumed, and noncontrolling interest at July 1, 2014. The fair value of accounts receivable acquired equaled contractual amounts receivable. Changes to the preliminary allocation disclosed in Exhibit 99.1 of our Form 8-K dated May 6, 2015, which were recorded in the first quarter of 2015, reflect an increase of $150 million in Property, plant, and equipment and $25 million in Goodwill, and a decrease of $168 million in Other intangible assets and $7 million in Investments. These adjustments during the measurement period were not considered significant to require retrospective revisions of our financial statements.

	(Millions)
Accounts receivable	$	168
Other current assets	63
Investments	5,865
Property, plant, and equipment	7,165
Goodwill	499
Other intangible assets	8,841
Current liabilities	(408		)
Debt	(4,052		)
Other noncurrent liabilities	(9		)
Noncontrolling interest in ACMP’s subsidiaries	(958		)
Noncontrolling interest in ACMP	(6,544		)

97

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Other intangible assets recognized in the acquisition are related to contractual customer relationships from gas gathering agreements with our customers. The basis for determining the value of these intangible assets was estimated future net cash flows to be derived from acquired contractual customer relationships discounted using a risk-adjusted discount rate. These intangible assets are being amortized on a straight-line basis over 30 years during which contractual customer relationships are expected to contribute to our cash flows. As estimated at the time of acquisition, approximately 56 percent of the expected future revenues from these contractual customer relationships were impacted by our ability and intent to renew or renegotiate existing customer contracts. We expense costs incurred to renew or extend the terms of our gas gathering, processing, and fractionation contracts with customers. Based on the estimated future revenues during the current contract periods (as estimated at the time of acquisition), the weighted-average periods to the next renewal or extension of the existing customer contracts were approximately 17 years.

The noncash adjustment to record the fair value of the noncontrolling interest in ACMP was determined based on the common units and ACMP’s closing common unit price at July 1, 2014.

The following unaudited pro forma Total revenues and Net income (loss) attributable to The Williams Companies, Inc. for the year ended December 31, 2014, are presented as if the ACMP Acquisition had been completed on January 1, 2014. These pro forma amounts are not necessarily indicative of what the actual results would have been if the acquisition had in fact occurred on the date or for the period indicated, nor do they purport to project Total revenues or Net income (loss) attributable to The Williams Companies, Inc. for any future periods or as of any date. These amounts do not give effect to any potential cost savings, operating synergies, or revenue enhancements to result from the transactions or the potential costs to achieve these cost savings, operating synergies, and revenue enhancements.

	December 31,
	2014
	(Millions)
Total revenues	$	8,181
Net income (loss) attributable to The Williams Companies, Inc.	$	622

Significant adjustments to pro forma Net income (loss) attributable to The Williams Companies, Inc. include the removal of the previously described $2.5 billion gain on remeasurement of equity-method investment, and include additional depreciation and amortization expense associated with reflecting the acquired investments, property, plant, and equipment, and other intangible assets at fair value. The adjustments assume estimated useful lives of 30 years. Other significant adjustments to pro forma Net income (loss) attributable to The Williams Companies, Inc. include interest expense related to debt financing associated with the acquisition as well as Net income (loss) attributable to noncontrolling interests.

During the year ended December 31, 2014, ACMP contributed Total revenues of $781 million and Net income (loss) attributable to The Williams Companies, Inc. of $165 million.

Costs related to this acquisition were $16 million in 2014 and are reported within our Williams Partners segment and included in Selling, general, and administrative expenses in the Consolidated Statement of Operations. Direct transaction costs associated with financing commitments were $9 million in 2014 and reported within Interest incurred in the Consolidated Statement of Operations. Equity earnings (losses) within the Consolidated Statement of Operations in 2014 includes $19 million of equity losses associated with certain compensation-related costs at ACMP that were triggered by the acquisition.

Eagle Ford Gathering System

In May 2015, WPZ acquired a gathering system comprised of approximately 140 miles of pipeline and a sour gas compression facility in the Eagle Ford Shale for $112 million. The acquisition was accounted for as a business combination, and the allocation of the acquisition-date fair value of the major classes of assets acquired includes $80 million of Property, plant, and equipment – net and $32 million of Intangible assets – net of accumulated amortization in the Consolidated Balance Sheet. Changes to the preliminary allocation disclosed in the second quarter of 2015 reflect

98

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

an increase of $20 million in Property, plant, and equipment – net, and a decrease of $20 million in Intangible assets – net of accumulated amortization.

UEOM Equity-Method Investment

In June 2015, WPZ acquired an approximate 13 percent additional interest in its equity-method investment, UEOM, for $357 million. Following the acquisition WPZ owns approximately 62 percent of UEOM. However, WPZ continues to account for this as an equity-method investment because WPZ does not control UEOM due to the significant participatory rights of its partner. In connection with the acquisition of the additional interest, we agreed to waive approximately $2 million of our WPZ IDR payments each quarter through 2017. See Note 1 – General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies for discussion of agreement with WPZ wherein we permanently waived IDR payment obligations from WPZ.

Note 3 – Divestiture

In September 2016, we completed the sale of subsidiaries conducting Canadian operations, including subsidiaries of WPZ, (such subsidiaries, the disposal group). Consideration received to date totaled $1.020 billion, net of $31 million of cash divested and subject to customary working capital adjustments. In connection with the sale, we waived $150 million of incentive distributions otherwise payable by WPZ to us in the fourth quarter of 2016 in recognition of certain affiliate contracts wherein WPZ’s Canadian operations provided services to certain of our other businesses. The proceeds were primarily used to reduce borrowings on credit facilities.

During the second quarter of 2016, we designated these operations as held for sale. As a result, we measured the fair value of the disposal group as of June 30, 2016, resulting in an impairment charge of $747 million, reflected in Impairment of certain assets in the Consolidated Statement of Operations. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk.) During the second half of 2016 we recorded an additional loss of $66 million upon completion of the sale, primarily reflecting revisions to the sales price and estimated contingent consideration and including a $15 million benefit related to transactions to hedge our foreign currency exchange risk on the Canadian proceeds, reflected in Other (income) expense – net within Costs and expenses in the Consolidated Statement of Operations. The total loss consists of a loss of $34 million at Williams Partners and $32 million at Williams NGL & Petchem Services.

The following table presents the results of operations for the disposal group, excluding the impairment and loss noted above:

	Years Ended December 31,
	2016			2015
	(Millions)
Income (loss) before income taxes of disposal group	$	(98	)	$	17
Income (loss) before income taxes of disposal group attributable to The Williams Companies, Inc.	(95		)	15

Note 4 – Variable Interest Entities

On January 1, 2016, we adopted ASU 2015-02 “Amendments to the Consolidation Analysis," which eliminated certain presumptions related to a general partner interest in a master limited partnership. As a result of adopting this new accounting standard, our consolidated master limited partnership is now a VIE. We are the primary beneficiary of WPZ because we have the power to direct the activities that most significantly impact WPZ’s economic performance.

99

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

The following table presents amounts included in our Consolidated Balance Sheet that are for the use or obligation of WPZ and/or its subsidiaries, and which comprise a significant portion of our consolidated assets and liabilities:

	December 31,
	2016			2015			Classification
	(Millions)
Assets (liabilities):
Cash and cash equivalents	$	145		$	73		Cash and cash equivalents
Trade accounts and other receivables – net	925			1,026			Trade accounts and other receivables
Inventories	138			127			Inventories
Other current assets	205			190			Other current assets and deferred charges
Investments	6,701			7,336			Investments
Property, plant, and equipment – net	28,021			28,593			Property, plant, and equipment – net
Intangible assets – net	9,662			10,016			Intangible assets – net of accumulated amortization
Regulatory assets, deferred charges, and other noncurrent assets	467			479			Regulatory assets, deferred charges, and other
Accounts payable	(589		)	(625		)	Accounts payable
Accrued liabilities including current asset retirement obligations	(1,122		)	(757		)	Accrued liabilities
Commercial paper	(93		)	(499		)	Commercial paper
Long-term debt due within one year	(785		)	(176		)	Long-term debt due within one year
Long-term debt	(17,685		)	(19,001		)	Long-term debt
Deferred income tax liabilities	(20		)	(119		)	Deferred income tax liabilities
Noncurrent asset retirement obligations	(798		)	(857		)	Regulatory liabilities, deferred income, and other
Regulatory liabilities, deferred income, and other noncurrent liabilities	(1,860		)	(1,066		)	Regulatory liabilities, deferred income, and other

The assets and liabilities presented in the table above also include the consolidated interests of the following individual VIEs within WPZ:

Gulfstar One

WPZ owns a 51 percentinterest in Gulfstar One LLC (Gulfstar One), a subsidiary that, due to certain risk-sharing provisions in its customer contracts, is a VIE. Gulfstar One includes a proprietary floating-production system, Gulfstar FPS, and associated pipelines which provide production handling and gathering services for the Tubular Bells oil and gas discovery in the eastern deepwater Gulf of Mexico. WPZ is the primary beneficiary because it has the power to direct the activities that most significantly impact Gulfstar One’s economic performance.

Constitution

WPZ owns a 41 percent interest in Constitution, a subsidiary that, due to shipper fixed-payment commitments under its long-term firm transportation contracts, is a VIE. WPZ is the primary beneficiary because it has the power to direct the activities that most significantly impact Constitution’s economic performance. WPZ, as construction manager for Constitution, is responsible for constructing the proposed pipeline connecting its gathering system in Susquehanna County, Pennsylvania, to the Iroquois Gas Transmission and the Tennessee Gas Pipeline systems. The total remaining

100

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

cost of the project is estimated to be approximately $687 million, which is expected to be funded with capital contributions from WPZ and the other equity partners on a proportional basis.

In December 2014, we received approval from the FERC to construct and operate the Constitution pipeline. However, in April 2016, the New York State Department of Environmental Conservation (NYSDEC) denied a necessary water quality certification for the New York portion of the Constitution pipeline. We remain steadfastly committed to the project, and in May 2016, Constitution appealed the NYSDEC's denial of the certification and filed an action in federal court seeking a declaration that the State of New York's authority to exercise permitting jurisdiction over certain other environmental matters is preempted by federal law. The oral argument before the Second Circuit Court of Appeals regarding the NYSDEC’s denial of Constitution’s application for water quality certification under Section 401 of the Clean Water Act was held on November 16, 2016. We anticipate a decision from the Second Circuit Court of Appeals as early as second quarter 2017. In light of the NYSDEC's denial of the water quality certification and the actions taken to challenge the decision, the project in-service date is targeted as early as the second half of 2018, which assumes that the legal challenge process is satisfactorily and promptly concluded. An unfavorable resolution could result in the impairment of a significant portion of the capitalized project costs, which total $381 million on a consolidated basis at December 31, 2016, and are included within Property, plant, and equipment – netin the Consolidated Balance Sheet. Beginning in April 2016, we discontinued capitalization of development costs related to this project. It is also possible that we could incur certain supplier-related costs in the event of a prolonged delay or termination of the project.

Cardinal

WPZ owns a 66 percent interest in Cardinal Gas Services, L.L.C. (Cardinal), a subsidiary that provides gathering services for the Utica Shale region and is a VIE due to certain risks shared with customers. WPZ is the primary beneficiary because it has the power to direct the activities that most significantly impact Cardinal’s economic performance. Future expansion activity is expected to be funded with capital contributions from WPZ and the other equity partner on a proportional basis.

Jackalope

WPZ owns a 50 percent interest in Jackalope Gas Gathering Services, L.L.C. (Jackalope), a subsidiary that provides gathering and processing services for the Powder River basin and is a VIE due to certain risks shared with customers. WPZ is the primary beneficiary because it has the power to direct the activities that most significantly impact Jackalope’s economic performance. Future expansion activity is expected to be funded with capital contributions from WPZ and the other equity partner on a proportional basis.

Note 5 – Related Party Transactions

Transactions with Equity-Method Investees

We have purchases from our equity-method investees included in Product costs in the Consolidated Statement of Operationsof $180 million, $187 million, and $197 million for the years ended 2016, 2015, and 2014, respectively. We have $19 million and $12 million included in Accounts payablein the Consolidated Balance Sheetwith our equity-method investees at December 31, 2016 and 2015, respectively.

WPZ has operating agreements with certain equity-method investees. These operating agreements typically provide for reimbursement or payment to WPZ for certain direct operational payroll and employee benefit costs, materials, supplies, and other charges and also for management services. We supplied a portion of these services, primarily those related to employees since WPZ does not have any employees, to certain equity-method investees. The total charges to equity-method investees for these fees are $66 million, $64 million, and $65 million for the years ended 2016, 2015, and 2014, respectively.

101

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Board of Directors

A former member of our Board of Directors, who was elected in 2013 and resigned during 2016, is also the current chairman, president, and chief executive officer of an energy services company that is a customer of ours. We recorded $144 million, $111 million, and $115 million in Service revenues in the Consolidated Statement of Operations from this company for transportation and storage of natural gas for the years ended December 31, 2016, 2015, and 2014, respectively.

Note 6 – Investing Activities

Impairment of equity-method investments

The following table presents other-than-temporary impairment charges related to certain equity-method investments (see Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk):

	Years Ended December 31,
	2016		2015
	(Millions)
Williams Partners
Appalachia Midstream Investments	$	294	$	562
DBJV	59		503
Laurel Mountain	50		45
UEOM	—		241
Ranch Westex	24		—
Other	3		8
	$	430	$	1,359

Equity earnings (losses)

Equity earnings (losses) in 2015 includes a loss of $19 million associated with WPZ’s share of underlying property impairments at certain of the Appalachia Midstream Investments. This loss is reported within the Williams Partners segment.

Equity earnings (losses) in 2014 includes:

• Write-offs of capitalized project development costs on our discontinued investments in Bluegrass Pipeline Company LLC (Bluegrass) of $67 million and Moss Lake Fractionation LLC and Moss Lake LPG Terminal LLC (collectively referred to as Moss Lake) of $4 million;

• A $7 million equity loss recognized from our interest in ACMP that was accounted for under the equity-method of accounting for the first six months of the year, including $19 million of equity losses associated with certain compensation-related costs at ACMP that were triggered by the acquisition and $30 million noncash amortization of the difference between the cost of our investment and our underlying share of the net assets for the first six months of the year.

Other investing income (loss) – net

In 2016, we recognized a $27 million gain from the sale of an equity-method investment interest in a gathering system that was part of the Appalachia Midstream Investments within the Williams Partners segment.

Other investing income (loss) – net also includes $36 million, $27 million, and $41 million of interest income for 2016, 2015 and 2014, respectively, associated with a receivable related to the sale of certain former Venezuela assets. Due to changes in circumstances that led to late payments and increased uncertainty regarding the recovery of the receivable, we began accounting for the receivable under a cost recovery model in first quarter 2015. Subsequently,

102

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

we received payments greater than the remaining carrying amount of the receivable, which resulted in the recognition of interest income.

Investments

	Ownership Interest at December 31, 2016	December 31,
		2016		2015
		(Millions)
Equity-method investments:
Appalachia Midstream Investments	(1)	$	2,062	$	2,464
UEOM	62%	1,448		1,525
DBJV	50%	988		977
Discovery	60%	572		602
OPPL	50%	430		445
Caiman II	58%	426		418
Laurel Mountain	69%	324		391
Gulfstream	50%	261		293
Other	Various	190		221
		$	6,701	$	7,336

___________

(1) Includes equity-method investments in multiple gathering systems in the Marcellus Shale with an approximate average 41 percent interest.

We have differences between the carrying value of our equity-method investments and the underlying equity in the net assets of the investees of $1.9 billion at December 31, 2016 and $2.4 billion at December 31, 2015. These differences primarily relate to our investments in Appalachian Midstream Investments, DBJV, and UEOM resulting from property, plant, and equipment, as well as customer-based intangible assets and goodwill.

Purchases of and contributions to equity-method investments

We generally fund our portion of significant expansion or development projects of these investees through additional capital contributions. These transactions increased the carrying value of our investments and included:

	Years Ended December 31,
	2016		2015		2014
	(Millions)
DBJV	$	105	$	57	$	20
Appalachia Midstream Investments	28		93		84
Caiman II	22		—		175
UEOM	—		357		57
Discovery	—		35		106
Other	22		53		40
	$	177	$	595	$	482

103

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Dividends and distributions

The organizational documents of entities in which we have an equity-method interest generally require distribution of available cash to members on at least a quarterly basis. These transactions reduced the carrying value of our investments and included:

	Years Ended December 31,
	2016		2015		2014
	(Millions)
Appalachia Midstream Investments	$	211	$	219	$	130
Discovery	141		116		36
Gulfstream	100		88		81
UEOM	92		42		—
OPPL	69		45		27
Caiman II	40		33		13
DBJV	39		33		—
Laurel Mountain	28		31		39
ACMP	—		—		64
Other	22		26		50
	$	742	$	633	$	440

In addition, on September 24, 2015, WPZ received a special distribution of $396 million from Gulfstream reflecting its proportional share of the proceeds from new debt issued by Gulfstream. The new debt was issued to refinance Gulfstream’s debt maturities. Subsequently, WPZ contributed $248 million and $148 million to Gulfstream for its proportional share of amounts necessary to fund debt maturities of $500 million due on November 1, 2015, and $300 million due on June 1, 2016, respectively.

Summarized Financial Position and Results of Operations of All Equity-Method Investments

	December 31,
	2016			2015
	(Millions)
Assets (liabilities):
Current assets	$	508		$	773
Noncurrent assets	9,695			9,549
Current liabilities	(412		)	(633		)
Noncurrent liabilities	(1,484		)	(1,450		)

	Years Ended December 31,
	2016		2015		2014
	(Millions)
Gross revenue	$	1,883	$	1,707	$	1,623
Operating income	799		690		534
Net income	726		611		460

104

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Note 7 – Other Income and Expenses

The following table presents certain gains or losses reflected in Other (income) expense – net within Costs and expenses in the Consolidated Statement of Operations:

	Years Ended December 31,
	2016			2015			2014
	(Millions)
Williams Partners
Loss on sale of Canadian operations (Note 3)	$	34		$	—		$	—
Amortization of regulatory assets associated with asset retirement obligations	33			33			33
Accrual of regulatory liability related to overcollection of certain employee expenses	25			20			14
Project development costs related to Constitution (Note 4)	28			—			—
Net foreign currency exchange (gains) losses (1)	10			(10		)	(3		)
Contingency gain settlement (2)	—			—			(154		)
Net gain related to partial acreage dedication release	—			—			(12		)
Gain on asset retirement	(11		)	—			—
Loss related to sale of certain assets	—			—			10
Williams NGL & Petchem Services
Loss on sale of Canadian operations (Note 3)	32			—			—
Gain on sale of unused pipe	(10		)	—			—

________________

(1) Primarily relates to gains and losses incurred on foreign currency transactions and the remeasurement of U.S. dollar-denominated current assets and liabilities within our former Canadian operations (see Note 3 – Divestiture).

(2) In November 2014, we settled a claim arising from the resolution of a contingent gain related to claims associated with the purchase of a business in a prior period. Pursuant to the settlement, we received $154 million in cash, all of which was recognized as a gain in the fourth quarter of 2014.

ACMP Acquisition, Merger, and Transition

Certain ACMP acquisition, merger, and transition costs included in the Consolidated Statement of Operations are as follows:

• Selling, general, and administrative expensesincludes $26 million in 2015 and $27 million in 2014 (including $16 million of acquisition costs) primarily related to professional advisory fees within the Williams Partners segment.

• Selling, general, and administrative expensesincludes $9 million in 2015 and $15 million in 2014 of related employee transition costs within the Williams Partners segment and $32 million in 2015 and $10 million in 2014 of general corporate expenses associated with integration and realignment of resources within the Other segment.

• Operating and maintenance expensesincludes $12 million in 2015 and $15 million in 2014 primarily related to employee transition costs within the Williams Partners segment.

• Interest incurredincludes transaction-related financing costs of $2 million in 2015 from the merger and $9 million in 2014 from the acquisition.

105

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Additional Items

Certain additional items included in the Consolidated Statement of Operations are as follows:

• Service revenuesincludes $173 million associated with the amortization of deferred income related to the restructuring of certain gas gathering contracts in the Barnett Shale and Mid-Continent regions within the Williams Partners segment. Service revenues also includes $58 million, $239 million, and $167 million recognized in the fourth quarter of 2016, 2015, and 2014, respectively, from minimum volume commitment feesin the Barnett Shale and Mid-Continent regions within the Williams Partners segment.

• Selling, general, and administrative expensesand Operating and maintenance expenses include $42 million in 2016 of severance and other related costs.

• Other income (expense) – net below Operating income (loss) includes $89 million, $95 million, and $44 million for equity AFUDC for 2016, 2015, and 2014, respectively, primarily within the Williams Partners segment.

• Other income (expense) – net below Operating income (loss) includes a $14 million gain in 2015 resulting from the early retirement of certain debt within the Williams Partners segment.

Note 8 – Provision (Benefit) for Income Taxes

The Provision (benefit) for income taxes includes:

	Years Ended December 31,
	2016			2015			2014
	(Millions)
Current:
Federal	$	—		$	—		$	(9	)
State	2			(7		)	2
Foreign	(1		)	(55		)	10
	1			(62		)	3
Deferred:
Federal	(6		)	(317		)	1,108
State	61			(25		)	119
Foreign	(81		)	5			19
	(26		)	(337		)	1,246
Provision (benefit) for income taxes	$	(25	)	$	(399	)	$	1,249

106

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Reconciliations from the Provision (benefit) at statutory rate to recorded Provision (benefit) for income taxes are as follows:

	Years Ended December 31,
	2016			2015			2014
	(Millions)
Provision (benefit) at statutory rate	$	(131	)	$	(600	)	$	1,255
Increases (decreases) in taxes resulting from:
Impact of nontaxable noncontrolling interests	(22		)	263			(75		)
State income taxes (net of federal benefit)	3			(21		)	82
State deferred income tax rate change	43			—			—
Foreign operations – net (Including tax effect of Canadian Sale)	78			8			(11		)
Taxes on undistributed earnings of foreign subsidiaries – net	—			—			(37		)
Translation adjustment of certain unrecognized tax benefits	(1		)	(71		)	—
Other – net	5			22			35
Provision (benefit) for income taxes	$	(25	)	$	(399	)	$	1,249

Income (loss) from continuing operations before income taxes includes $885 million of foreign loss in 2016, and $20 million and $102 million of foreign income in 2015 and 2014, respectively.

Foreign operations – net (Including tax effect of Canadian Sale) increased in 2016 due to a valuation allowance associated with impairments and losses on the sale of our Canadian operations (see Note 3 – Divestiture) and the reversal of anticipatory foreign tax credits, partially offset by the tax effect of the impairments associated with our Canadian disposition.

The Translation adjustment of certain unrecognized tax benefits in 2016 and 2015 reflects the impact of changes in foreign currency exchange rates on the remeasurement of a foreign currency denominated unrecognized tax benefit, including associated penalties and interest.

The 2015 federal and state income tax provisions include the tax effect of a $2.7 billion impairment loss associated with certain goodwill, equity-method investments, and other assets. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk.) The 2014 federal and state income tax provisions include the tax effect of a $2.5 billion gain associated with remeasuring our equity-method investment to fair value as a result of the ACMP Acquisition. (See Note 2 – Acquisitions.)

Taxes on undistributed earnings of foreign subsidiaries - net decreased in 2014 due to revisions of our estimate of the undistributed earnings, partially offset by an increase of tax expense, which decreased our share of the foreign tax credit due to the Canada Dropdown.

During the course of audits of our business by domestic and foreign tax authorities, we frequently face challenges regarding the amount of taxes due. These challenges include questions regarding the timing and amount of deductions and the allocation of income among various tax jurisdictions. In evaluating the liability associated with our various filing positions, we apply the two-step process of recognition and measurement. In association with this liability, we record an estimate of related interest and tax exposure as a component of our tax provision. The impact of this accrual is included within Other – net in our reconciliation of the Provision (benefit) at statutory rate to recorded Provision (benefit) for income taxes.

107

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Significant components of Deferred income tax liabilities and Deferred income tax assets are as follows:

	December 31,
	2016		2015
	(Millions)
Deferred income tax liabilities:
Property, plant, and equipment	$	—	$	4
Investments	5,300		5,272
Other	29		15
Total deferred income tax liabilities	5,329		5,291
Deferred income tax assets:
Accrued liabilities	145		150
Minimum tax credits	139		139
Foreign tax credit	140		193
Federal loss carryovers	651		485
State losses and credits	313		296
Other	37		42
Total deferred income tax assets	1,425		1,305
Less valuation allowance	334		190
Net deferred income tax assets	1,091		1,115
Overall net deferred income tax liabilities	$	4,238	$	4,176

The valuation allowance at December 31, 2016 and 2015 serves to reduce the available deferred income tax assets to an amount that will, more likely than not, be realized. We consider all available positive and negative evidence, including projected future taxable income and management’s estimate of future reversals of existing taxable temporary differences, and have determined that a portion of our deferred income tax assets related to State losses and credits and Federal loss carryovers may not be realized. The change in Valuation allowance is partially due to this evaluation. The amounts presented in the table above are, with respect to state items, before any federal benefit. The change from prior year for the State losses and creditsis primarily due to increases in losses and credits generated in the current and prior years less losses and/or credits utilized in the current year. We have loss and credit carryovers in multiple state taxing jurisdictions. These attributes generally expire between 2017 and 2036 with some carryovers having indefinite carryforward periods. Federal loss carryovers includes the tax effect of a capital loss carryover of $364 million, incurred with the sale of our Canadian operations, which, if unused, will expire in 2021. The Valuation allowance change from prior year is primarily due to a valuation allowance on the deferred tax asset associated with this capital loss carryover. We reasonably anticipate that this valuation allowance could be released in the near future due to tax impacts of the potential monetization of certain assets as previously announced by management. The federal tax Minimum tax credits of $139 million currently has no expiration date. Foreign tax credit of $140 million is expected to be utilized prior to expiration in 2026.

Federal net operating loss carryovers and charitable contribution carryovers of $1.6 billion at the end of 2016 are expected to be utilized by us prior to expiration between 2018 and 2036. Employee share-based compensation attributable to the exercise of stock options and vesting of restricted stock is deductible by us for tax purposes. To the extent these tax deductions exceed the previously accrued deferred income tax benefit for these items, the additional tax benefit is not recognized until the deduction reduces current income taxes payable. Since the additional tax benefit does not reduce our current income taxes payable for 2014 through 2016, these tax benefits are not included in our Federal loss carryovers deferred income tax assets. The additional tax benefits deductible for tax purposes but not included in our Federal loss carryovers deferred income tax assets were $38 million through 2016.

Cash payments for income taxes (net of refunds) were $5 million and $29 million in 2016 and 2014, respectively. Cash refunds for income taxes (net of payments and discontinued operations) were $136 million in 2015.

108

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

As of December 31, 2016, we had approximately $50 million of unrecognized tax benefits. If recognized, income tax expense would be reduced by $49 million and $51 million for 2016 and 2015, respectively, including the effect of these changes on other tax attributes, with state income tax amounts included net of federal tax effect. A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows:

	2016			2015
	(Millions)
Balance at beginning of period	$	55		$	89
Additions for tax positions of prior years	—			2
Reductions for tax positions of prior years	(4		)	—
Changes due to currency translation	(1		)	(36		)
Balance at end of period	$	50		$	55

We recognize related interest and penalties as a component of Provision (benefit) for income taxes. Total interest and penalties recognized as part of income tax provision were expenses of $300 thousand and $8 million for 2016 and 2014, respectively, and a benefit of $22 million for 2015, including a $35 million benefit due to currency fluctuation. Approximately $3 million and $2 million of interest and penalties primarily relating to uncertain tax positions have been accrued as of December 31, 2016 and 2015, respectively. Changes due to currency translation in 2015 reflects the unrecognized tax benefit portion of the previously described impact of changes in foreign currency exchange rates on the remeasurement of a foreign currency denominated balance.

During the next 12 months, we do not expect ultimate resolution of any unrecognized tax benefit associated with domestic or international matters to have a material impact on our unrecognized tax benefit position.

Consolidated U.S Federal income tax returns are open to Internal Revenue Service (IRS) examination for years after 2010. As of December 31, 2016, examinations of tax returns for 2011 through 2013 are currently in process. We do not expect material changes in our financial position resulting from these examinations. The statute of limitations for most states expires one year after expiration of the IRS statute. Generally, tax returns for our Canadian entities are open to audit for tax years after 2011. Tax years 2013 and 2014 are currently under examination. We have indemnified the purchaser of our Canadian operations for any adjustments to Canadian tax returns for periods prior to the sale of our Canadian operations in September 2016.

In November 2015, the FASB issued ASU 2015-17 “Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes” (ASU 2015-17). The standard requires that deferred income tax liabilities and assets, along with any related valuation allowance, be presented as noncurrent in a classified statement of financial position. The standard is effective for interim and annual periods beginning after December 15, 2016 and early adoption is permitted. We have elected to early adopt ASU 2015-17 prospectively as of December 31, 2016. TheConsolidated Balance Sheetas of December 31, 2015 was not retrospectively adjusted.

On September 13, 2013, the IRS issued final regulations providing guidance on the treatment of amounts paid to acquire, produce, or improve tangible property. On August 18, 2014, the IRS issued final regulations providing guidance on the dispositions of such property. The implementation date for these regulations was January 1, 2014. The IRS is expected to issue additional procedural guidance regarding how the requirements may be implemented for the gas transmission and distribution industry. Pending the issuance of this additional procedural guidance from the IRS, we cannot at this time estimate the impact of implementing the regulations for our gas transmission business, although we anticipate that it will result in an immaterial balance sheet only impact.

109

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Note 9 – Earnings (Loss) Per Common Share from Continuing Operations

	Years Ended December 31,
	2016			2015			2014
	(Dollars in millions, except per-share amounts; shares in thousands)
Income (loss) from continuing operations attributable to The Williams Companies, Inc. available to common stockholders for basic and diluted earnings (loss) per common share	$	(424	)	$	(571	)	$	2,110
Basic weighted-average shares	750,673			749,271			719,325
Effect of dilutive securities:
Nonvested restricted stock units	—			—			2,234
Stock options	—			—			2,064
Convertible debentures	—			—			18
Diluted weighted-average shares (1)	750,673			749,271			723,641
Earnings (loss) per common share from continuing operations:
Basic	$	(.57	)	$	(.76	)	$	2.93
Diluted	$	(.57	)	$	(.76	)	$	2.91

(1) For the years ended December 31, 2016 and December 31, 2015, 0.6 million and 1.7 million weighted-average nonvested restricted stock units, and 0.5 million and 1.5 million weighted-average stock options have been excluded from the computation of diluted earnings (loss) per common share as their inclusion would be antidilutive due to our loss from continuing operations attributable to The Williams Companies, Inc.

Note 10 – Employee Benefit Plans

We have noncontributory defined benefit pension plans in which all eligible employees participate. Currently, eligible employees earn benefits primarily based on a cash balance formula. Various other formulas, as defined in the plan documents, are utilized to calculate the retirement benefits for plan participants not covered by the cash balance formula. At the time of retirement, participants may elect, to the extent they are eligible for the various options, to receive annuity payments, a lump sum payment, or a combination of a lump sum and annuity payments. In addition to our pension plans, we currently provide subsidized retiree medical and life insurance benefits (other postretirement benefits) to certain eligible participants. Generally, employees hired after December 31, 1991, are not eligible for the subsidized retiree medical benefits, except for participants that were employees or retirees of Transco Energy Company on December 31, 1995, and other miscellaneous defined participant groups. Subsidized retiree medical benefits for eligible participants age 65 and older are paid through contributions to health reimbursement accounts. Subsidized retiree medical benefits for eligible participants under age 65 are provided through a self-insured medical plan sponsored by us. The self-insured retiree medical plan provides for retiree contributions and contains other cost-sharing features such as deductibles, co-payments, and co-insurance. The accounting for these plans anticipates estimated future increases to our contribution levels to the health reimbursement accounts for participants age 65 and older, as well as future cost-sharing that is consistent with our expressed intent to increase the retiree contribution level generally in line with health care cost increases for participants under age 65.

110

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Funded Status

The following table presents the changes in benefit obligations and plan assets for pension benefits and other postretirement benefits for the years indicated:

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
	(Millions)
Change in benefit obligation:
Benefit obligation at beginning of year	$	1,464		$	1,544		$	202		$	233
Service cost	54			59			1			2
Interest cost	62			58			8			9
Plan participants’ contributions	—			—			2			2
Benefits paid	(130		)	(101		)	(15		)	(13		)
Actuarial loss (gain)	20			(91		)	(1		)	(31		)
Settlements	(4		)	(5		)	—			—
Net increase (decrease) in benefit obligation	2			(80		)	(5		)	(31		)
Benefit obligation at end of year	1,466			1,464			197			202
Change in plan assets:
Fair value of plan assets at beginning of year	1,241			1,293			201			208
Actual return on plan assets	82			(11		)	13			(1		)
Employer contributions	65			65			7			5
Plan participants’ contributions	—			—			2			2
Benefits paid	(130		)	(101		)	(15		)	(13		)
Settlements	(4		)	(5		)	—			—
Net increase (decrease) in fair value of plan assets	13			(52		)	7			(7		)
Fair value of plan assets at end of year	1,254			1,241			208			201
Funded status — overfunded (underfunded)	$	(212	)	$	(223	)	$	11		$	(1	)
Accumulated benefit obligation	$	1,440		$	1,432

The overfunded (underfunded) status of our pension plans and other postretirement benefit plans presented in the previous table are recognized in the Consolidated Balance Sheet within the following accounts:

	December 31,
	2016			2015
	(Millions)
Underfunded pension plans:
Current liabilities	$	(2	)	$	(2	)
Noncurrent liabilities	(210		)	(221		)
Overfunded (underfunded) other postretirement benefit plans:
Current liabilities	(7		)	(7		)
Noncurrent assets (liabilities)	18			6

The plan assets within our other postretirement benefit plans are intended to be used for the payment of benefits for certain groups of participants. The Current liabilities for the other postretirement benefit plans represent the current portion of benefits expected to be payable in the subsequent year for the groups of participants whose benefits are not expected to be paid from plan assets.

111

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

The pension plans’ benefit obligation Actuarial loss (gain) of $20 million in 2016 is primarily due to the impact of a decrease in the discount rates utilized to calculate the benefit obligation. The pension plans’ benefit obligation Actuarial loss (gain)of$(91) million in 2015 is primarily due to the impact of a decrease in the assumed future interest crediting rate for the cash balance pension formula and an increase in the discount rates utilized to calculate the benefit obligation.

The 2015 benefit obligation Actuarial loss (gain) of $(31) million for our other postretirement benefit plans is primarily due to an increase in the discount rate used to calculate the benefit obligation, tax law changes, and other assumption changes.

At December 31, 2016 and 2015, all of our pension plans had a projected benefit obligation and accumulated benefit obligation in excess of plan assets.

Pre-tax amounts not yet recognized in Net periodic benefit cost at December 31 are as follows:

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
	(Millions)
Amounts included in Accumulated other comprehensive income (loss):
Prior service credit	$	—		$	—		$	5		$	11
Net actuarial loss	(535		)	(544		)	(18		)	(18		)
Amounts included in regulatory liabilities associated with Transco and Northwest Pipeline:
Prior service credit	N/A			N/A			$	10		$	19
Net actuarial gain	N/A			N/A			8			6

In addition to the regulatory liabilities included in the previous table, differences in the amount of actuarially determined Net periodic benefit cost for our other postretirement benefit plans and the other postretirement benefit costs recovered in rates for Transco and Northwest Pipeline are deferred as a regulatory asset or liability. We have regulatory liabilities of $94 million at December 31, 2016 and $78 million at December 31, 2015, related to these deferrals. Additionally, Transco recognizes a regulatory liability for rate collections in excess of its amount funded to the tax-qualified pension plans. At December 31, 2016 and 2015, these regulatory liabilities were $21 million and $8 million, respectively. These pension and other postretirement plans amounts will be reflected in future rates based on the rate structures of these gas pipelines.

112

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Net Periodic Benefit Cost

Net periodic benefit cost for the years ended December 31 consist of the following:

	Pension Benefits									Other Postretirement  Benefits
	2016			2015			2014			2016			2015			2014
	(Millions)
Components of net periodic benefit cost:
Service cost	$	54		$	59		$	40		$	1		$	2		$	2
Interest cost	62			58			62			8			9			10
Expected return on plan assets	(85		)	(75		)	(76		)	(12		)	(12		)	(12		)
Amortization of prior service credit	—			—			—			(15		)	(17		)	(20		)
Amortization of net actuarial loss	30			42			39			—			2			—
Net actuarial (gain) loss from settlements and curtailments	2			2			1			—			—			(1		)
Reclassification to regulatory liability	—			—			—			4			3			4
Net periodic benefit cost	$	63		$	86		$	66		$	(14	)	$	(13	)	$	(17	)

Items Recognized in Other Comprehensive Income (Loss) and Regulatory Assets/Liabilities

Other changes in plan assets and benefit obligations recognized in Other comprehensive income (loss) before taxes for the years ended December 31 consist of the following:

	Pension Benefits								Other Postretirement  Benefits
	2016			2015		2014			2016			2015			2014
	(Millions)
Other changes in plan assets and benefit obligations recognized in Other comprehensive income (loss):
Net actuarial gain (loss)	$	(23	)	$	5	$	(142	)	$	—		$	8		$	(18	)
Prior service (cost) credit	—			—		—			—			—			(1		)
Amortization of prior service credit	—			—		—			(6		)	(6		)	(8		)
Amortization of net actuarial loss	30			42		39			—			2			—
Loss from settlements and curtailments	2			2		1			—			—			1
Other changes in plan assets and benefit obligations recognized in Other comprehensive income (loss)	$	9		$	49	$	(102	)	$	(6	)	$	4		$	(26	)

Other changes in plan assets and benefit obligations for our other postretirement benefit plans associated with Transco and Northwest Pipeline are recognized in regulatory assets/liabilities.Amounts recognized in regulatory assets/ liabilities for the years ended December 31 consist of the following:

	2016			2015			2014
	(Millions)
Other changes in plan assets and benefit obligations recognized in regulatory (assets) liabilities:
Net actuarial gain (loss)	$	2		$	10		$	(2	)
Amortization of prior service credit	(9		)	(11		)	(12		)

113

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Pre-tax amounts expected to be amortized in Net periodic benefit cost in 2017 are as follows:

	Pension Benefits		Other Postretirement Benefits
	(Millions)
Amounts included in Accumulated other comprehensive income (loss):
Prior service credit	$	—	$	(5	)
Net actuarial loss	28		—
Amounts included in regulatory liabilities associated with Transco and Northwest Pipeline:
Prior service credit	N/A		$	(8	)
Net actuarial loss	N/A		—

Key Assumptions

The weighted-average assumptions utilized to determine benefit obligations as of December 31 are as follows:

	Pension Benefits				Other Postretirement Benefits
	2016		2015		2016		2015
Discount rate	4.17	%	4.38	%	4.27	%	4.50	%
Rate of compensation increase	4.87		4.88		N/A		N/A

The weighted-average assumptions utilized to determine Net periodic benefit cost for the years ended December 31 are as follows:

	Pension Benefits						Other Postretirement  Benefits
	2016		2015		2014		2016		2015		2014
Discount rate	4.37	%	3.96	%	4.68	%	4.50	%	4.12	%	4.80	%
Expected long-term rate of return on plan assets	6.85		6.38		6.85		6.11		5.70		6.11
Rate of compensation increase	4.88		4.62		4.56		N/A		N/A		N/A

The mortality assumptions used to determine the benefit obligations for our pension and other postretirement benefit plans reflect generational projection mortality tables.

The assumed health care cost trend rate for 2017 is 7.5 percent. This rate decreases to 4.5 percent by 2025. A one-percentage-point change in assumed health care cost trend rates would have the following effects:

	Point increase		Point decrease
	(Millions)
Effect on total of service and interest cost components	$	—	$	—
Effect on other postretirement benefit obligation	6		(5		)

Plan Assets

Plan assets for our pension and other postretirement benefit plans consist primarily of equity and fixed income securities including mutual funds and commingled investment funds invested in equity and fixed income securities. The plans’ investment policy provides for a strategy in accordance with the Employee Retirement Income Security Act (ERISA), which governs the investment of the assets in a diversified portfolio. The plans follow a policy of diversifying the investments across various asset classes and investment managers. Additionally, the investment returns on

114

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

approximately 38 percent of the other postretirement benefit plan assets are subject to income tax; therefore, certain investments are managed in a tax efficient manner.

The investment policy for the pension plans includes a general target asset allocation at December 31, 2016 of 60 percent equity securities and 40 percent fixed income securities. The target allocation includes the investments in equity and fixed income mutual funds and commingled investment funds. The investment policy allows for a broad range of asset allocations that permit the plans to de-risk in response to changes in the plans’ funded status.

Equity securities may include U.S. equities and non-U.S. equities. Investment in Williams’ securities or an entity in which Williams has a majority ownership is prohibited except where these securities may be owned in a commingled investment fund in which the plans’ trusts invest. No more than 5 percent of the total stock portfolio valued at market may be invested in the common stock of any one corporation.

Fixed income securities may consist of U.S. as well as international instruments, including emerging markets. The fixed income strategies may invest in government, corporate, asset-backed securities, and mortgage-backed obligations. The weighted-average credit rating of the fixed income strategies must be at least “investment grade” including ratings by Moody’s and/or Standard & Poor’s. No more than 5 percent of the total fixed income portfolio may be invested in the fixed income securities of any one issuer with the exception of bond index funds and U.S. government guaranteed and agency securities.

The following securities and transactions are not authorized: unregistered securities, commodities or commodity contracts, short sales or margin transactions, or other leveraging strategies. Investment strategies using direct investments in derivative securities require approval and, historically, have not been used; however, these instruments may be used in mutual funds and commingled investment funds held by the plans’ trusts. Additionally, real estate equity, natural resource property, venture capital, leveraged buyouts, and other high-return, high-risk investments are generally restricted.

There are no significant concentrations of risk within the plans’ investment securities because of the diversity of the types of investments, diversity of the various industries, and the diversity of the fund managers and investment strategies. Generally, the investments held in the plans are publicly traded, therefore, minimizing liquidity risk in the portfolio.

115

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

The fair values of our pension plan assets at December 31, 2016 and 2015 by asset class are as follows:

	2016
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(Millions)
Pension assets:
Cash management fund	$	14	$	—	$	—	$	14
Equity securities:
U.S. large cap	87		—		—		87
U.S. small cap	77		—		—		77
Fixed income securities (1):
U.S. Treasury securities	68		—		—		68
Government and municipal bonds	—		10		—		10
Mortgage and asset-backed securities	—		80		—		80
Corporate bonds	—		148		—		148
Insurance company investment contracts and other	—		5		—		5
	$	246	$	243	$	—	489
Commingled investment funds measured at net asset value practical expedient (3):
Equities — U.S. large cap							369
Equities — International small cap							27
Equities — International emerging markets							50
Equities — International developed markets							149
Fixed income — U.S. long duration							88
Fixed income — Corporate bonds							82
Total assets at fair value at December 31, 2016							$	1,254

116

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

	2015
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(Millions)
Pension assets:
Cash management fund	$	8	$	—	$	—	$	8
Equity securities:
U.S. large cap	83		—		—		83
U.S. small cap	64		—		—		64
Fixed income securities (1):
U.S. Treasury securities	65		—		—		65
Government and municipal bonds	—		8		—		8
Mortgage and asset-backed securities	—		87		—		87
Corporate bonds	—		145		—		145
Insurance company investment contracts and other	—		5		—		5
	$	220	$	245	$	—	465
Commingled investment funds measured at net asset value practical expedient (3):
Equities — U.S. large cap							367
Equities — International small cap							27
Equities — International emerging markets							50
Equities — International developed markets							153
Fixed income — U.S. long duration							95
Fixed income — Corporate bonds							84
Total assets at fair value at December 31, 2015							$	1,241

117

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

The fair values of our other postretirement benefits plan assets at December 31, 2016 and 2015 by asset class are as follows:

	2016
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(Millions)
Other postretirement benefit assets:
Cash management funds	$	11	$	—	$	—	$	11
Equity securities:
U.S. large cap	24		—		—		24
U.S. small cap	15		—		—		15
International developed markets large cap growth	—		5		—		5
Fixed income securities (2):
U.S. Treasury securities	7		—		—		7
Government and municipal bonds	—		1		—		1
Mortgage and asset-backed securities	—		8		—		8
Corporate bonds	—		15		—		15
Mutual fund — Municipal bonds	42		—		—		42
	$	99	$	29	$	—	128
Commingled investment funds measured at net asset value practical expedient (3):
Equities — U.S. large cap							38
Equities — International small cap							3
Equities — International emerging markets							5
Equities — International developed markets							16
Fixed income — U.S. long duration							9
Fixed income — Corporate bonds							9
Total assets at fair value at December 31, 2016							$	208

118

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

	2015
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(Millions)
Other postretirement benefit assets:
Cash management funds	$	11	$	—	$	—	$	11
Equity securities:
U.S. large cap	37		—		—		37
U.S. small cap	20		—		—		20
International developed markets large cap growth	1		9		—		10
Emerging markets growth	—		1		—		1
Fixed income securities (2):
U.S. Treasury securities	7		—		—		7
Government and municipal bonds	—		12		—		12
Mortgage and asset-backed securities	—		9		—		9
Corporate bonds	—		15		—		15
	$	76	$	46	$	—	122
Commingled investment funds measured at net asset value practical expedient (3):
Equities — U.S. large cap							37
Equities — International small cap							3
Equities — International emerging markets							5
Equities — International developed markets							16
Fixed income — U.S. long duration							10
Fixed income — Corporate bonds							8
Total assets at fair value at December 31, 2015							$	201

____________

(1) The weighted-average credit quality rating of the pension assets fixed income security portfolio is investment grade with a weighted-average duration of approximately 8 years for 2016 and 2015.

(2) The weighted-average credit quality rating of the other postretirement benefit assets fixed income security portfolio is investment grade with a weighted-average duration of approximately 8 years for 2016 and 7 years for 2015.

(3) The stated intents of the funds vary based on each commingled fund’s investment objective. These objectives generally include strategies to replicate or outperform various market indices. Certain standard withdrawal restrictions generally apply, which may include redemption notification period restrictions ranging from 10 to 30 days. Additionally, the fund managers retain the right to restrict withdrawals from and/or purchases into the funds so as not to disadvantage other investors in the funds. Generally, the funds also reserve the right to make all or a portion of the redemption in-kind rather than in cash or a combination of cash and in-kind.

The fair value measurement level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement of an asset.

Shares of the cash management funds and mutual funds are valued at fair value based on published market prices as of the close of business on the last business day of the year, which represents the net asset values of the shares held.

119

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

The fair values of equity securities traded on U.S. exchanges are derived from quoted market prices as of the close of business on the last business day of the year. The fair values of equity securities traded on foreign exchanges are also derived from quoted market prices as of the close of business on an active foreign exchange on the last business day of the year. However, the valuation requires translation of the foreign currency to U.S. dollars and this translation is considered an observable input to the valuation.

The fair values of all commingled investment funds are determined based on the net asset values per unit of each of the funds. The net asset values per unit represent the aggregate values of the funds’ assets at fair value less liabilities, divided by the number of units outstanding.

The fair values of fixed income securities, except U.S. Treasury securities, are determined using pricing models. These pricing models incorporate observable inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads for similar securities to determine fair value. The U.S. Treasury securities are valued at fair value based on closing prices on the last business day of the year reported in the active market in which the security is traded.

The investment contracts with insurance companies are valued at fair value by discounting the cash flow of a bond using a yield to maturity based on an investment grade index or comparable index with a similar maturity value, maturity period, and nominal coupon rate.

There have been no significant changes in the preceding valuation methodologies used at December 31, 2016 and 2015. Additionally, there were no transfers or reclassifications of investments between Level 1 and Level 2 from December 2015 to December 2016. If transfers between levels had occurred, the transfers would have been recognized as of the end of the period.

Plan Benefit Payments and Employer Contributions

Following are the expected benefits to be paid by the plans. These estimates are based on the same assumptions previously discussed and reflect future service as appropriate. The actuarial assumptions are based on long-term expectations and include, but are not limited to, assumptions as to average expected retirement age and form of benefit payment. Actual benefit payments could differ significantly from expected benefit payments if near-term participant behaviors differ significantly from the actuarial assumptions.

	Pension Benefits		Other Postretirement Benefits
	(Millions)
2017	$	99	$	13
2018	103		13
2019	103		13
2020	106		13
2021	111		13
2022-2026	562		62

In 2017, we expect to contribute approximately $60 million to our tax-qualified pension plans and approximately $2 million to our nonqualified pension plans, for a total of approximately $62 million, and approximately $7 million to our other postretirement benefit plans.

Defined Contribution Plans

We also maintain defined contribution plans for the benefit of substantially all of our employees. Generally, plan participants may contribute a portion of their compensation on a pre-tax and after-tax basis in accordance with the plans’ guidelines. We match employees’ contributions up to certain limits. Our matching contributions charged to expense were $36 million in 2016, $39 million in 2015, and $39 million in 2014.

120

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Note 11 – Property, Plant, and Equipment

The following table presents nonregulated and regulated Property, plant, and equipment – net as presented on the Consolidated Balance Sheet for the years ended:

	Estimated Useful Life  (1) (Years)	Depreciation Rates (1) (%)	December 31,
			2016			2015
			(Millions)
Nonregulated:
Natural gas gathering and processing facilities	5 - 40		$	20,413		$	20,789
Construction in progress	Not applicable		412			1,366
Other	2 - 45		2,202			2,170
Regulated:
Natural gas transmission facilities		1.20 - 6.97	12,692			12,189
Construction in progress	Not applicable	Not applicable	1,603			941
Other	5 - 45	1.35 - 33.33	1,590			1,584
Total property, plant, and equipment, at cost			38,912			39,039
Accumulated depreciation and amortization			(10,484		)	(9,460		)
Property, plant, and equipment — net			$	28,428		$	29,579

__________

(1) Estimated useful life and depreciation rates are presented as of December 31, 2016. Depreciation rates and estimated useful lives for regulated assets are prescribed by the FERC.

Depreciation and amortization expense forProperty, plant, and equipment – net was $1,407 million, $1,382 million, and $967 million in 2016, 2015, and 2014, respectively.

Regulated Property, plant, and equipment – net includes approximately $665 million and $706 million at December 31, 2016 and 2015, respectively, related to amounts in excess of the original cost of the regulated facilities within our gas pipeline businesses as a result of our prior acquisitions. This amount is being amortized over 40 years using the straight-line amortization method. Current FERC policy does not permit recovery through rates for amounts in excess of original cost of construction.

Asset Retirement Obligations

Our accrued obligations relate to underground storage caverns, offshore platforms and pipelines, fractionation and compression facilities, gas gathering well connections and pipelines, and gas transmission pipelines and facilities. At the end of the useful life of each respective asset, we are legally obligated to plug storage caverns and remove any related surface equipment, to restore land and remove surface equipment at gas processing, fractionation, and compression facilities, to dismantle offshore platforms and appropriately abandon offshore pipelines, to cap certain gathering pipelines at the wellhead connection and remove any related surface equipment, and to remove certain components of gas transmission facilities from the ground.

121

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

The following table presents the significant changes to our ARO, of which $801 million and $858 million are included in Regulatory liabilities, deferred income, and other with the remaining current portion in Accrued liabilities at December 31, 2016 and 2015, respectively.

	December 31,
	2016			2015
	(Millions)
Beginning balance	$	915		$	831
Liabilities incurred	24			42
Liabilities settled	(8		)	(3		)
Accretion expense	69			60
Revisions (1)	(138		)	(15		)
Ending balance	$	862		$	915

___________

(1) Several factors are considered in the annual review process, including inflation rates, current estimates for removal cost, market risk premiums, discount rates, and the estimated remaining useful life of the assets. The 2016 revisions reflect changes in removal cost estimates, increases in the estimated remaining useful life of certain assets, and decreases in the inflation rate and discount rates used in the annual review process. The 2015 revisions reflect changes in removal cost estimates and the estimated remaining useful life of assets, a decrease in the inflation rate, and increases in the discount rates used in the annual review process.

The funds Transco collects through a portion of its rates to fund its ARO are deposited into an external trust account dedicated to funding its ARO (ARO Trust). (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk.) Under its current rate settlement, Transco’s annual funding obligation is approximately $36 million, with installments to be deposited monthly.

Note 12 – Goodwill and Other Intangible Assets

Goodwill

Changes in the carrying amount of goodwill, included in Intangible assets – net of accumulated amortization, by reportable segment for the periods indicated are as follows:

	Williams Partners
	(Millions)
December 31, 2014	$	1,120
Purchase accounting adjustment	25
Impairment	(1,098		)
December 31, 2015	$	47
December 31, 2016	$	47

Our goodwill is not subject to amortization, but is evaluated at least annually for impairment or more frequently if impairment indicators are present. We did not identify or recognize any impairments to goodwill in connection with our annual evaluation of goodwill for impairment (performed as of October 1) during the years ended December 31, 2016 and 2014. During 2015, we performed an interim assessment and an annual assessment as of September 30, 2015 and October 1, 2015, respectively, of certain goodwill within the Williams Partners segment. The estimated fair value of the reporting units evaluated exceeded their carrying amounts, and thus no impairment was identified. We performed an additional goodwill impairment evaluation as of December 31, 2015, of the goodwill recorded within the Williams Partners segment. As a result of this evaluation, we recorded goodwill impairment charges totaling $1.098 billion. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk.)

122

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Other Intangible Assets

The gross carrying amount and accumulated amortization of other intangible assets, included in Intangible assets – net of accumulated amortization, at December 31 are as follows:

	2016					2015
	Gross Carrying Amount		Accumulated Amortization			Gross Carrying Amount		Accumulated Amortization
	(Millions)
Contractual customer relationships	$	10,635	$	(1,019	)	$	10,633	$	(663	)

Other intangible assets primarily relate to gas gathering, processing, and fractionation contractual customer relationships recognized in the ACMP and Eagle Ford acquisitions (see Note 2 – Acquisitions) as well as previous acquisitions. Other intangible assets are being amortized on a straight-line basis over an initial period of 30 years which represents a portion of the term over which the contractual customer relationships are expected to contribute to our cash flows.

We expense costs incurred to renew or extend the terms of our gas gathering, processing, and fractionation contracts with customers. Based on the estimated future revenues during the contract periods (as estimated at the time of the respective acquisition), the weighted-average periods prior to the next renewal or extension of the contractual customer relationships associated with the ACMP and Eagle Ford acquisitions were approximately 17 years and 10 years, respectively. Although a significant portion of the expected future cash flows associated with these contractual customer relationships are dependent on our ability to renew or extend the arrangements beyond the initial contract periods, these expected future cash flows are significantly influenced by the scope and pace of our producer customers’ drilling programs. Once producer customers’ wells are connected to our gathering infrastructure, their likelihood of switching to another provider before the wells are abandoned is reduced due to the significant capital investment required.

The amortization expense related to other intangible assets was $356 million, $353 million, and $209 million in 2016, 2015, and 2014, respectively. The estimated amortization expense for each of the next five succeeding fiscal years is approximately $356 million.

Note 13 – Accrued Liabilities

	December 31,
	2016		2015
	(Millions)
Deferred income	$	338	$	94
Interest on debt	310		284
Employee costs	223		215
Refundable deposits	160		—
Special distribution repayable to Gulfstream (See Note 6 - Investing Activities)	—		149
Asset retirement obligations	61		57
Other, including other loss contingencies	356		279
	$	1,448	$	1,078

Deferred income in 2016 includes cash proceeds associated with restructuring certain gas gathering contracts in the Barnett Shale and Mid-Continent regions. (See Note 1 – General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies.)

Refundable deposits in 2016 includes receipts related to an agreement to resolve several matters in relation to Transco’s Hillabee Expansion Project. In accordance with the agreement, the member–sponsors of Sabal Trail will pay WPZ an aggregate amount of $240 million in three equal installments as certain milestones of the project are met, of

123

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

which $160 million was received in 2016. WPZ expects to recognize income associated with these receipts over the term of an underlying contract once the project is in service.

Note 14 – Debt, Banking Arrangements, and Leases

Long-Term Debt

	December 31,
	2016		2015
	(Millions)
Unsecured:
Transco:
6.4% Notes due 2016 (1)	$	—	$	200
6.05% Notes due 2018	250		250
7.08% Debentures due 2026	8		8
7.25% Debentures due 2026	200		200
7.85% Notes due 2026	1,000		—
5.4% Notes due 2041	375		375
4.45% Notes due 2042	400		400
Northwest Pipeline:
7% Notes due 2016	—		175
5.95% Notes due 2017	185		185
6.05% Notes due 2018	250		250
7.125% Debentures due 2025	85		85
WPZ:
7.25% Notes due 2017	600		600
5.25% Notes due 2020	1,500		1,500
4.125% Notes due 2020	600		600
4% Notes due 2021	500		500
3.6% Notes due 2022	1,250		1,250
3.35% Notes due 2022	750		750
6.125% Notes due 2022	750		750
4.5% Notes due 2023	600		600
4.875% Notes due 2023	1,400		1,400
4.3% Notes due 2024	1,000		1,000
4.875% Notes due 2024	750		750
3.9% Notes due 2025	750		750
4% Notes due 2025	750		750
6.3% Notes due 2040	1,250		1,250
5.8% Notes due 2043	400		400
5.4% Notes due 2044	500		500
4.9% Notes due 2045	500		500
5.1% Notes due 2045	1,000		1,000
Term Loan, variable interest rate, due 2018	850		850
Credit facility loans	—		1,310
WMB:
7.875% Notes due 2021	371		371
3.7% Notes due 2023	850		850
4.55% Notes due 2024	1,250		1,250
7.5% Debentures due 2031	339		339

124

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

	December 31,
	2016			2015
	(Millions)
7.75% Notes due 2031	252			252
8.75% Notes due 2032	445			445
5.75% Notes due 2044	650			650
Various — 5.5% to 10.25% Notes and Debentures due 2019 to 2033	55			55
Credit facility loans	775			650
Capital lease obligations	—			1
Debt issuance costs	(119		)	(123		)
Net unamortized debt premium (discount)	88			110
Total long-term debt, including current portion	23,409			23,988
Long-term debt due within one year	(785		)	(176		)
Long-term debt	$	22,624		$	23,812

___________

(1) Presented as long-term debt at December 31, 2015, due to Transco’s intent and ability to refinance.

Certain of our debt agreements contain covenants that restrict or limit, among other things, our ability to create liens supporting indebtedness, sell assets, and incur additional debt. Default of these agreements could also restrict our ability to make certain distributions or repurchase equity.

The following table presents aggregate minimum maturities of long-term debt, excluding net unamortized debt premium (discount), debt issuance costs, and capital lease obligations, for each of the next five years:

	December 31, 2016
	(Millions)
2017	$	785
2018	1,350
2019	32
2020	2,896
2021	871

Issuances and retirements

WPZ retired $600 million of 7.25 percent senior unsecured notes that matured on February 1, 2017.

Northwest Pipeline retired $175 million of 7 percent senior unsecured notes that matured on June 15, 2016.

Transco retired $200 million of 6.4 percent senior unsecured notes that matured on April 15, 2016.

On January 22, 2016, Transco issued $1 billion of 7.85 percent senior unsecured notes due 2026 to investors in a private debt placement. In January 2017, Transco completed an exchange of these notes for substantially identical new notes that are registered under the Securities Act of 1933, as amended. Transco used the net proceeds to repay debt and to fund capital expenditures.

In December 2015, WPZ borrowed $850 million on a variable interest rate loan with certain lenders due 2018. At December 31, 2016, the interest rate was 2.50 percent. WPZ used the proceeds for working capital, capital expenditures, and for general partnership purposes.

On April 15, 2015, WPZ paid $783 million, including a redemption premium, to early retire $750 million of 5.875 percent senior notes due 2021 with a carrying value of $797 million.

125

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

On March 3, 2015, WPZ completed a public offering of $1.25 billion of 3.6 percent senior unsecured notes due 2022, $750 million of 4 percent senior unsecured notes due 2025, and $1 billion of 5.1 percent senior unsecured notes due 2045. WPZ used the net proceeds to repay amounts outstanding under its commercial paper program and credit facility, to fund capital expenditures, and for general partnership purposes.

WPZ retired $750 million of 3.8 percent senior unsecured notes that matured on February 15, 2015.

Credit Facilities

	December 31, 2016
	Available		Outstanding
	(Millions)
WMB
Long-term credit facility	$	1,500	$	775
Letters of credit under certain bilateral bank agreements			13
WPZ
Long-term credit facility (1)	3,500		—
Letters of credit under certain bilateral bank agreements			1

________________

(1) In managing our available liquidity, we do not expect a maximum outstanding amount in excess of the capacity of our credit facility inclusive of any outstanding amounts under our commercial paper program.

WMB long-term credit facility

On February 2, 2015, we entered into the Second Amended and Restated Credit Agreement. The aggregate commitments available remained at $1.5 billion, with up to an additional $500 million increase in aggregate commitments available under certain circumstances. The maturity date of the credit facility was extended to February 2, 2020. However, we may request up to two extensions of the maturity date each for an additional one year period to allow a maturity date as late as February 2, 2022, under certain circumstances. The agreement also allows for swing line loans up to an aggregate amount of $50 million, subject to available capacity under the credit facility, and the letters of credit up to $675 million.

The agreements governing the credit facilities contain the following terms and conditions:

• Various covenants may limit, among other things, a borrower’s and its material subsidiaries’ ability to grant certain liens supporting indebtedness, merge or consolidate, sell all or substantially all of its assets, enter into certain affiliate transactions, make certain distributions during an event of default, make investments, and allow any material change in the nature of its business.

• If an event of default with respect to a borrower occurs under its respective credit facility, the lenders will be able to terminate the commitments for the respective borrowers and accelerate the maturity of any loans of the defaulting borrower under the respective credit facility agreement and exercise other rights and remedies.

• Each time funds are borrowed under our credit facility, the borrower may choose from two methods of calculating interest: a fluctuating base rate equal to the bank’s alternate base rate plus an applicable margin or a periodic fixed rate equal to LIBOR plus an applicable margin. The borrower is required to pay a commitment fee based on the unused portion of its respective credit facility. The applicable margin and the commitment fee are determined for us by reference to a pricing schedule based on our senior unsecured long-term debt ratings.

Significant financial covenants under the agreement require the ratio of debt to EBITDA (each as defined in the credit agreement) be no greater than 5 to 1, except for the fiscal quarter and the two following fiscal quarters in which one or more acquisitions has been executed, in which case the ratio of debt to EBITDA is to be no greater than 5.5 to 1.

We are in compliance with these financial covenants as measured at December 31, 2016.

126

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

As of February 20, 2017, $235 million is outstanding under our long-term credit facility.

WPZ long-term credit facilities

Prior to their merger both WPZ and ACMP had separate credit facilities that terminated on February 2, 2015.

On February 2, 2015, WPZ along with Transco, Northwest Pipeline, the lenders named therein, and an administrative agent entered into the Second Amended & Restated Credit Agreement with aggregate commitments available of $3.5 billion, with up to an additional $500 million increase in aggregate commitments available under certain circumstances. The maturity date of the credit facility is February 2, 2020. However, the co-borrowers may request up to two extensions of the maturity date each for an additional one year period to allow a maturity date as late as February 2, 2022, under certain circumstances. The agreement allows for swing line loans up to an aggregate amount of $150 million, subject to available capacity under the credit facility, and letters of credit commitments of $1.125 billion. Transco and Northwest Pipeline are each able to borrow up to $500 million under this credit facility to the extent not otherwise utilized by the other co-borrowers. On December 18, 2015, WPZ along with Transco, Northwest Pipeline, the lenders named therein and an administrative agent entered into the Amendment No. 1 to Second Amended & Restated Credit Agreement modifying the thresholds specified in the covenant related to the maximum ratio of WPZ’s debt to EBITDA.

The agreement governing this credit facility contains the following terms and conditions:

• Various covenants may limit, among other things, a borrower’s and its material subsidiaries’ ability to grant certain liens supporting indebtedness, merge or consolidate, sell all or substantially all of its assets, enter into certain affiliate transactions, make certain distributions during an event of default, enter into certain restrictive agreements, and allow any material change in the nature of its business.

• If an event of default with respect to a borrower occurs under the credit facility, the lenders will be able to terminate the commitments for all borrowers and accelerate the maturity of any loans of the defaulting borrower under the credit facility agreement and exercise other rights and remedies.

• Other than swing line loans, each time funds are borrowed, the borrower must choose whether such borrowing will be an alternate base rate borrowing or a Eurodollar borrowing.  If such borrowing is an alternate base rate borrowing, interest is calculated on the basis of the greater of (a) the Prime Rate, (b) the Federal Funds Effective Rate plus one half of 1 percent and (c) a periodic fixed rate equal to the London Interbank Offered Rate (LIBOR) plus 1 percent, plus, in the case of each of (a), (b) and (c), an applicable margin. If the borrowing is a Eurodollar borrowing, interest is calculated on the basis of LIBOR for the relevant period plus an applicable margin.  Interest on swing line loans is calculated as the sum of the alternate base rate plus an applicable margin.  The borrower is required to pay a commitment fee based on the unused portion of the credit facility. The applicable margin and the commitment fee are determined for each borrower by reference to a pricing schedule based on such borrower’s senior unsecured long-term debt ratings.

Significant financial covenants under the agreement require the ratio of debt to EBITDA, each as defined in the credit facility, be no greater than:

• 5.75 to 1, for the quarters ending December 31, 2015, March 31, 2016 and June 30, 2016;

• 5.50 to 1, for the quarters ending September 30, 2016 and December 31, 2016;

• 5.00 to 1, for the quarter ending March 31, 2017 and each subsequent fiscal quarter, except for the the fiscal quarter and the two following fiscal quarters in which one or more acquisitions has been executed, in which case the ratio of debt to EBITDA is to be no greater than 5.5 to 1.00.

127

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

The ratio of debt to capitalization (defined as net worth plus debt) must be no greater than 65 percent for each Transco and Northwest Pipeline. WPZ is in compliance with these financial covenants as measured at December 31, 2016.

As of February 20, 2017, there are no amounts outstanding under the long-term credit facility.

WPZ short-term credit facilities

On August 26, 2015, WPZ entered into a $1.0 billion short-term credit facility. On December 23, 2015, WPZ’s short-term credit facility capacity decreased to $150 million in conjunction with entering into the $850 million term loan. The $150 million short-term credit facility is no longer available as it expired August 24, 2016.

Commercial Paper Program

On February 2, 2015, WPZ amended and restated the commercial paper program for the ACMP Merger and to allow a maximum outstanding amount of unsecured commercial paper notes of $3 billion. The maturities of the commercial paper notes vary but may not exceed 397 days from the date of issuance. The commercial paper notes are sold under customary terms in the commercial paper market and are issued at a discount from par, or, alternatively, are sold at par and bear varying interest rates on a fixed or floating basis. Proceeds from these notes are used for general partnership purposes, including funding capital expenditures, working capital, and partnership distributions. We classify WPZ’s commercial paper outstanding in Current liabilities in the Consolidated Balance Sheet, as the outstanding notes at December 31, 2016 and December 31, 2015, have maturity dates less than three months from the date of issuance. At December 31, 2016, WPZ had $93 million in Commercial paper outstanding at a weighted-average interest rate of 1.06 percent and at December 31, 2015, WPZ had $499 million in Commercial paper outstanding at a weighted-average interest rate of 0.92 percent.

Cash Payments for Interest (Net of Amounts Capitalized)

Cash payments for interest (net of amounts capitalized)were $1.152 billion in 2016, $1.023 billion in 2015, and $681 million in 2014.

Restricted Net Assets of Subsidiaries

We have considered the guidance in the Securities and Exchange Commission’s Regulation S-X related to restricted net assets of subsidiaries. In accordance with Rule 4-08(e) of Regulation S-X, we have determined that certain net assets of our subsidiaries are considered restricted under this guidance and exceed 25 percent of our consolidated net assets. As of December 31, 2016, substantially all of these restricted net assets relate to the net assets of WPZ, which are technically considered restricted under this accounting rule due to terms within WPZ’s partnership agreement that govern the partnerships’ assets. Our interest in WPZ’s net assets that are considered to be restricted at December 31, 2016, was $13 billion.

128

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Leases-Lessee

The future minimum annual rentals under noncancelable operating leases, are payable as follows:

	December 31, 2016
	(Millions)
2017	$	62
2018	58
2019	51
2020	46
2021	35
Thereafter	90
Total	$	342

Total rent expense was $64 million in 2016, $69 million in 2015, and $62 million in 2014 and primarily included in Operating and maintenance expenses and Selling, general, and administrative expenses in the Consolidated Statement of Operations.

Other

On January 25, 2017, WPZ announced that it will redeem all of its $750 million6.125 percent senior notes due 2022 on February 23, 2017.

Note 15 – Stockholders' Equity

Cash dividends declared per common share were $1.68, $2.45, and $1.9575 for 2016, 2015, and 2014, respectively. On February 20, 2017, our board of directors approved a regular quarterly dividend of $0.30 per share payable on March 27, 2017.

In January 2017, we issued 65 million shares of common stock in a public offering at a price of $29.00 per share. In February 2017, we issued 9.75 million shares of common stock pursuant to the full exercise of the underwriter’s option to purchase additional shares. The net proceeds of approximately $2.1 billion were used to purchase newly issued common units in WPZ as part of our Financial Repositioning. (See Note 1 - General, Description of Business, Basis of Presentation and Summary of Significant Accounting Policies.)

On June 23, 2014, we issued 61 million shares of common stock in a public offering at a price of $57.00 per share. That amount includes 8 million shares purchased pursuant to the full exercise of the underwriter’s option to purchase additional shares. The net proceeds of $3.378 billion were used in July 2014 to finance a portion of the ACMP Acquisition. (See Note 2 - Acquisitions.)

129

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

AOCI

The following table presents the changes in AOCI by component, net of income taxes:

	Cash Flow Hedges			Foreign Currency Translation			Pension and Other Post Retirement Benefits			Total
	(Millions)
Balance at December 31, 2015	$	(1	)	$	(103	)	$	(338	)	$	(442	)
Other comprehensive income (loss) before reclassifications	2			25			(15		)	12
Amounts reclassified from accumulated othercomprehensive income (loss)	(1		)	76			16			91
Other comprehensive income (loss)	1			101			1			103
Balance at December 31, 2016	$	—		$	(2	)	$	(337	)	$	(339	)

Reclassifications out of AOCI are presented in the following table by component for the year ended December 31, 2016:

Component	Reclassifications			Classification
	(Millions)
Cash flow hedges:
Energy commodity contracts	$	(3	)	Product sales
Total cash flow hedges	(3		)
Pension and other postretirement benefits:
Amortization of prior service cost (credit) included in net periodic benefit cost	(6		)	Note 10 – Employee Benefit Plans
Amortization of actuarial (gain) loss included in net periodic benefit cost	32			Note 10 – Employee Benefit Plans
Total pension and other postretirement benefits	26
Foreign currency translation:
Reclassification of cumulative foreign currency translation adjustment upon sale of foreign entities	155			Other (income) expense - net
Total before tax	178
Income tax benefit	(45		)	Provision (benefit) for income taxes
Net of income tax	133
Noncontrolling interest	(42		)	Net income (loss) attributable to noncontrolling interests
Reclassifications during the period	$	91

Note 16 – Equity-Based Compensation

Williams’ Plan Information

On May 17, 2007, our stockholders approved The Williams Companies, Inc. 2007 Incentive Plan (the Plan) that provides common-stock-based awards to both employees and nonmanagement directors and reserved 19 million new shares for issuance. On May 20, 2010 and May 22, 2014, our stockholders approved amendments and restatements of the Plan to increase by 11 million and 10 million, respectively, the number of new shares authorized for making awards under the Plan, among other changes. The Plan permits the granting of various types of awards including, but not limited

130

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

to, restricted stock units and stock options. At December 31, 2016, 27 million shares of our common stock were reserved for issuance pursuant to existing and future stock awards, of which 17 million shares were available for future grants.

Additionally, on May 17, 2007, our stockholders approved an Employee Stock Purchase Plan (ESPP) which authorized up to 2 million new shares of our common stock to be available for sale under the ESPP. On May 22, 2014, our stockholders approved an amendment and restatement of the ESPP to increase by 1.6 million the number of new shares authorized for sale under the ESPP. The ESPP enables eligible participants to purchase our common stock through payroll deductions not exceeding an annual amount of $15,000 per participant. The ESPP provides for offering periods during which shares may be purchased and continues until the earliest of (1) the Board of Directors terminates the ESPP, (2) the sale of all shares available under the ESPP, or (3) the tenth anniversary of the date the amended and restated ESPP was approved by the stockholders. Offering periods are from January through June and from July through December. Generally, all employees are eligible to participate in the ESPP, with the exception of executives and international employees. The number of shares eligible for an employee to purchase during each offering period is limited to 750 shares. The purchase price of the stock is 85 percent of the lower closing price of either the first or the last day of the offering period. The ESPP requires a one-year holding period before the stock can be sold. The plan was suspended during the period from January 1, 2016 to August 31, 2016, and was reinstated effective September 1, 2016. Employees purchased111 thousand shares at an average price of $23.93 per share during the period from September 1, 2016 to December 31, 2016. Approximately 1.4 million shares were available for purchase under the ESPP at December 31, 2016.

Operating and maintenance expenses and Selling, general and administrative expenses include equity-based compensation expense for the years ended December 31, 2016, 2015, and 2014 of $53 million, $56 million, and $44 million, respectively. Income tax benefit recognized related to the stock-based compensation expense for the years ended December 31, 2016, 2015, and 2014 was $20 million, $21 million, and $17 million, respectively. Measured but unrecognized stock-based compensation expense at December 31, 2016, was $67 million, which does not include the effect of estimated forfeitures of $2 million. Unrecognized stock-based compensation expense is comprised of $5 million related to stock options and $62 million related to restricted stock units. These amounts are expected to be recognized over a weighted-average period of 1.9 years.

Stock Options

Stock options are valued at the date of award, which does not precede the approval date. The purchase price per share for stock options may not be less than the market price of the underlying stock on the date of grant. Stock options generally become exercisable over a three-year period from the date of grant. Stock options generally expire ten years after the grant.

The following summary reflects stock option activity and related information for the year ended December 31, 2016:

Stock Options	Options		Weighted- Average Exercise Price		Aggregate Intrinsic Value
	(Millions)				(Millions)
Outstanding at December 31, 2015	5.7		$	31.51
Granted	0.9		$	24.99
Exercised	(0.3	)	$	17.84
Cancelled	(0.1	)	$	24.04
Outstanding at December 31, 2016	6.2		$	31.32	$	28
Exercisable at December 31, 2016	5.0		$	29.75	$	23

131

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

The following table summarizes additional information related to stock option activity during each of the last three years:

	Years Ended December 31,
	2016		2015		2014
	(Millions)
Total intrinsic value of options exercised	$	2	$	37	$	48
Tax benefits realized on options exercised	$	1	$	13	$	18
Cash received from the exercise of options	$	4	$	20	$	31

The weighted-average remaining contractual life for stock options outstanding and exercisable at December 31, 2016, was 5.5 years and 4.2 years, respectively.

The estimated fair value at date of grant of options for our common stock granted in each respective year, using the Black-Scholes option pricing model, is as follows: 

	2016			2015			2014
Weighted-average grant date fair value of options for our common stock granted during the year, per share	$	7.90		$	7.61		$	7.50
Weighted-average assumptions:
Dividend yield	3.2		%	4.8		%	4.2		%
Volatility	44.7		%	27.8		%	28.0		%
Risk-free interest rate	1.2		%	1.8		%	2.2		%
Expected life (years)	6.0			6.0			6.5

The 2016 expected dividend yield is based on the 2016 dividend forecast and the grant-date market price of our stock. Expected volatility is based on the average of our peer group 10-year historical volatility adjusted by a ratio of our implied volatility to the adjusted average of our peer group’s implied volatility. The adjustment is made because the difference in implied volatility between our peer group and us may indicate that we are expected to be more volatile than our peer group average. The risk-free interest rate is based on the U.S. Treasury Constant Maturity rates as of the grant date. The expected life of the option is based on historical exercise behavior and expected future experience.

Nonvested Restricted Stock Units

The following summary reflects nonvested restricted stock unit activity and related information for the year ended December 31, 2016:

Restricted Stock Units Outstanding	Shares		Weighted- Average Fair Value (1)
	(Millions)
Nonvested at December 31, 2015	3.4		$	39.38
Granted	1.5		$	26.51
Forfeited	(0.1	)	$	38.18
Vested	(0.9	)	$	35.49
Nonvested at December 31, 2016	3.9		$	35.19

______________

(1) Performance-based restricted stock units are valued utilizing a Monte Carlo valuation method using measures of total shareholder return. Certain of the performance-based restricted stock units are subject to a holding period of up to two years after the vesting date. Discounts for the restrictions of liquidity were applied to the estimated fair value at the date of certain awards and ranged from 5.83 percent to 15.58 percent. The discounts were developed using the Chaffe model and the Finnerty model. All other restricted stock units are valued at the grant-date market price. Restricted stock units generally vest after three years.

132

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Value of Restricted Stock Units	2016		2015		2014
Weighted-average grant date fair value of restricted stock units granted during the year, per share	$	26.51	$	40.15	$	42.79
Total fair value of restricted stock units vested during the year ($’s in millions)	$	32	$	42	$	27

Performance-based restricted stock units granted under the Plan represent40 percent of nonvested restricted stock units outstanding at December 31, 2016. These grants may be earned at the end of the vesting period based on actual performance against a performance target. Based on the extent to which certain financial targets are achieved, vested shares may range from zero percent to 500 percent of the original grant amount.

WPZ’s Plan Information

During 2014, certain employees of ACMP’s general partner received equity-based compensation through ACMP’s equity-based compensation program. The fair value of the awards issued was based on the fair market value of the common units on the date of grant. This value is being amortized over the vesting period, which is one to four years from the date of grant. These awards were converted to WPZ equity-based awards in accordance with the terms of the ACMP Merger. No additional grants of restricted common units were awarded through WPZ’s equity-based compensation programs in 2016 or 2015, and no additional grants are expected in the future. Equity-based compensation expense of $20 million, $29 million, and $11 million related to WPZ’s equity-based compensation program is included in Operating and maintenance expenses andSelling, general, and administrative expenses for the years ended December 31, 2016, 2015, and 2014, respectively. As of December 31, 2016, there was $11 million of unrecognized compensation expense attributable to the outstanding awards, which does not include the effect of estimated forfeitures of $1 million. These amounts are expected to be recognized over a weighted average period of 1.2 years.

The following summary reflects nonvested WPZ restricted common unit activity and related information for the year ended December 31, 2016:

Restricted Common Units Outstanding	Units		Weighted- Average Fair Value
	(Millions)
Nonvested at December 31, 2015	1.2		$	55.93
Forfeited	(0.1	)	$	52.85
Vested	(0.5	)	$	59.09
Nonvested at December 31, 2016	0.6		$	52.97

133

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk

The following table presents, by level within the fair value hierarchy, certain of our financial assets and liabilities. The carrying values of cash and cash equivalents, accounts receivable, commercial paper, and accounts payable approximate fair value because of the short-term nature of these instruments. Therefore, these assets and liabilities are not presented in the following table.

							Fair Value Measurements Using
	Carrying Amount			Fair Value			Quoted Prices In Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
	(Millions)
Assets (liabilities) at December 31, 2016:
Measured on a recurring basis:
ARO Trust investments	$	96		$	96		$	96	$	—		$	—
Energy derivatives assets designated as hedging instruments	2			2			—		2			—
Energy derivatives assets not designated as hedging instruments	1			1			—		—			1
Energy derivatives liabilities not designated as hedging instruments	(6		)	(6		)	—		—			(6		)
Additional disclosures:
Other receivables	15			15			15		—			—
Long-term debt, including current portion	(23,409		)	(24,090		)	—		(24,090		)	—
Guarantees	(44		)	(30		)	—		(14		)	(16		)
Assets (liabilities) at December 31, 2015:
Measured on a recurring basis:
ARO Trust investments	$	67		$	67		$	67	$	—		$	—
Energy derivatives assets not designated as hedging instruments	5			5			—		3			2
Energy derivatives liabilities not designated as hedging instruments	(2		)	(2		)	—		—			(2		)
Additional disclosures:
Other receivables	12			30			10		2			18
Long-term debt, including current portion (1)	(23,987		)	(19,606		)	—		(19,606		)	—
Guarantee	(29		)	(16		)	—		(16		)	—

___________

(1) Excludes capital leases.

Fair Value Methods

We use the following methods and assumptions in estimating the fair value of our financial instruments:

Assets and liabilities measured at fair value on a recurring basis

ARO Trust investments: Transco deposits a portion of its collected rates, pursuant to its rate case settlement, into an external trust that is specifically designated to fund future asset retirement obligations. The ARO Trust invests in a

134

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

portfolio of actively traded mutual funds that are measured at fair value on a recurring basis based on quoted prices in an active market, is classified as available-for-sale, and is reported in Regulatory assets, deferred charges, and other in the Consolidated Balance Sheet. Both realized and unrealized gains and losses are ultimately recorded as regulatory assets or liabilities.

Energy derivatives: Energy derivatives include commodity based exchange-traded contracts and over-the-counter contracts, which consist of physical forwards, futures, and swaps that are measured at fair value on a recurring basis. The fair value amounts are presented on a gross basis and do not reflect the netting of asset and liability positions permitted under the terms of our master netting arrangements. Further, the amounts do not include cash held on deposit in margin accounts that we have received or remitted to collateralize certain derivative positions. Energy derivatives assets are reported in Other current assets and deferred charges and Regulatory assets, deferred charges, and other in the Consolidated Balance Sheet. Energy derivatives liabilities are reported in Accrued liabilities and Regulatory liabilities, deferred income, and other in the Consolidated Balance Sheet.

Reclassifications of fair value between Level 1, Level 2, and Level 3 of the fair value hierarchy, if applicable, are made at the end of each quarter. No transfers between Level 1 and Level 2 occurred during the years ended December 31, 2016 or 2015.

Additional fair value disclosures

Other receivables: Other receivables primarily consist of margin deposits, which are reported in Other current assets and deferred charges in the Consolidated Balance Sheet. The disclosed fair value of our margin deposits is considered to approximate the carrying value generally due to the short-term nature of these items.

Other receivables also include a receivable related to the sale of certain former Venezuela assets. The disclosed fair value of this receivable is determined by an income approach. We calculated the net present value of a probability-weighted set of cash flows utilizing assumptions based on contractual terms, historical payment patterns by the counterparty, future probabilities of default, our likelihood of using arbitration if the counterparty does not perform, and discount rates. We determined the fair value of the receivable to be $18 million at December 31, 2015. We received two payments in 2016. The carrying value of this receivable iszero at December 31, 2016 and December 31, 2015.

Long-term debt: The disclosed fair value of our long-term debt is determined by a market approach using broker quoted indicative period-end bond prices. The quoted prices are based on observable transactions in less active markets for our debt or similar instruments.

Guarantees: Guarantees primarily consist of a guarantee we have provided in the event of nonpayment by our previously owned communications subsidiary, Williams Communications Group (WilTel), on a lease performance obligation that extends through 2042. Guarantees also include an indemnification related to a disposed operation.

To estimate the disclosed fair value of the WilTel guarantee, an estimated default rate is applied to the sum of the future contractual lease payments using an income approach. The estimated default rate is determined by obtaining the average cumulative issuer-weighted corporate default rate based on the credit rating of WilTel’s current owner and the term of the underlying obligation. The default rate is published by Moody’s Investors Service. The carrying value of the WilTel guarantee is reported in Accrued liabilities in the Consolidated Balance Sheet. The maximum potential undiscounted exposure is approximately $32 million at December 31, 2016. Our exposure declines systematically through the remaining term of WilTel’s obligation.

The fair value of the guarantee associated with the indemnification related to a disposed operation was estimated using an income approach that considered probability-weighted scenarios of potential levels of future performance. The terms of the indemnification do not limit the maximum potential future payments associated with the guarantee. The carrying value of this guarantee is reported in Regulatory liabilities, deferred income, and other in the Consolidated Balance Sheet.

135

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

We are required by our revolving credit agreements to indemnify lenders for certain taxes required to be withheld from payments due to the lenders and for certain tax payments made by the lenders. The maximum potential amount of future payments under these indemnifications is based on the related borrowings and such future payments cannot currently be determined. These indemnifications generally continue indefinitely unless limited by the underlying tax regulations and have no carrying value. We have never been called upon to perform under these indemnifications and have no current expectation of a future claim.

Nonrecurring fair value measurements

We performed an interim assessment of the goodwill associated with our Central and Northeast G&P reporting units as of September 30, 2015, and the annual assessment of goodwill associated with our Northeast G&P and West reporting units as of October 1, 2015. No impairment charges were required following these evaluations.

During the fourth quarter of 2015, we observed a significant decline in the market values of WPZ and comparable midstream companies within the industry. This served to reduce our estimate of enterprise value and increased our estimates of discount rates. As a result, we performed an impairment assessment as of December 31, 2015, of the goodwill associated with these reporting units, all within the Williams Partners segment.

We estimated the fair value of each reporting unit based on an income approach utilizing discount rates specific to the underlying businesses of each reporting unit. These discount rates considered variables unique to each business area, including equity yields of comparable midstream businesses, expectations for future growth, and customer performance considerations. Weighted-average discount rates utilized ranged from approximately 10 percent to 13 percent across the three reporting units.

As a result of the increases in discount rates during the fourth quarter of 2015, coupled with certain reductions in estimated future cash flows determined during the same period, the fair values of the Central and Northeast G&P reporting units were determined to be below their respective carrying values. For these measurements, the book basis of each reporting unit was reduced by the associated deferred tax liabilities. We then calculated the implied fair value of goodwill by performing a hypothetical application of the acquisition method wherein the estimated fair value was allocated to the underlying assets and liabilities of each reporting unit. As a result of these Level 3 measurements, we determined that the previously recorded goodwill associated with each reporting unit was fully impaired, resulting in a fourth-quarter 2015 noncash charge of $1,098 million, reflected in Impairment of goodwill in the Consolidated Statement of Operations. For the West reporting unit, the estimated fair value exceeded the carrying value and no impairment was recorded.

136

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

The following table presents impairments of assets and investments associated with certain nonrecurring fair value measurements within Level 3 of the fair value hierarchy.

						Impairments
						Years Ended December 31,
	Classification	Segment	Date of Measurement	Fair Value		2016		2015		2014
				(Millions)
Surplus equipment (1)	Property, plant, and equipment – net	Williams Partners	June 30, 2014	$	46					$	17
Surplus equipment (1)	Property, plant, and equipment – net	Williams Partners	December 31, 2014	32						13
Surplus equipment (1)	Property, plant, and equipment – net	Williams Partners	June 30, 2015	17				$	20
Surplus equipment (1)	Assets held for sale	Williams Partners	December 31, 2014	1						12
Previously capitalized project development costs (2)	Property, plant, and equipment – net	Williams Partners	December 31, 2015	13				94
Previously capitalized project development costs (3)	Property, plant, and equipment – net	Williams NGL & Petchem Services	December 31, 2015	40				64
Canadian operations (4)	Assets held for sale	Williams Partners	June 30, 2016	924		$	341
Canadian operations (4)	Assets held for sale	Williams NGL & Petchem Services	June 30, 2016	206		406
Certain gathering operations (5)	Property, plant, and equipment – net	Williams Partners	June 30, 2016	18		48
Certain idle assets	Property, plant, and equipment – net	Williams NGL & Petchem Services	December 31, 2016	73		8
Level 3 fair value measurements of certain assets						803		178		42
Other impairments and write-downs (6)						70		31		10
Impairment of certain assets						$	873	$	209	$	52
Equity-method investments (7)	Investments	Williams Partners	September 30, 2015	$	1,203			$	461
Equity-method investments (8)	Investments	Williams Partners	December 31, 2015	4,017				890
Equity-method investments (9)	Investments	Williams Partners	March 31, 2016	1,294		$	109
Equity-method investments (10)	Investments	Williams Partners	December 31, 2016	1,295		318
Other equity-method investment	Investments	Williams Partners	December 31, 2015	58				8
Other equity-method investment	Investments	Williams Partners	March 31, 2016	—		3
Impairment of equity-method investments						$	430	$	1,359

______________

(1) Relates to certain surplus equipment. The estimated fair value was determined by a market approach based on our analysis of observable inputs in the principal market.

137

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

(2) Relates to a gas processing plant, the completion of which is considered remote due to unfavorable impact of low natural gas prices on customer drilling activities. The assessed fair value primarily represents the estimated salvage value of certain equipment measured using a market approach based on our analysis of observable inputs in the principal market.

(3) Relates to an olefins pipeline project, the completion of which is considered remote due to lack of customer interest. The assessed fair value primarily represents the estimated fair value of unused pipeline measured using a market approach based on our analysis of observable inputs in the principal market.

(4) Relates to our Canadian operations. We designated these operations as held for sale as of June 30, 2016. As a result, we measured the fair value of the disposal group, resulting in an impairment charge. The estimated fair value was determined by a market approach based primarily on inputs received in the marketing process and reflected our estimate of the potential assumed proceeds. We disposed of our Canadian operations through a sale during the third quarter of 2016. See Note 3 – Divestiture.

(5) Relates to certain gathering assets within the Mid-Continent region. The estimated fair value was determined by a market approach based on our analysis of observable inputs in the principal market.

(6) Reflects multiple individually insignificant impairments and write-downs of other certain assets that may no longer be in use or are surplus in nature for which the fair value was determined to be zero or an insignificant salvage value.

(7) Relates to equity-method investments in DBJV and certain of the Appalachia Midstream Investments. The historical carrying value of these investments was initially recorded based on estimated fair value during the third quarter of 2014 in conjunction with the acquisition of ACMP. We estimated the fair value of these investments using an income approach based on expected future cash flows and appropriate discount rates. The determination of estimated future cash flows involved significant assumptions regarding gathering volumes and related capital spending. Discount rates utilized were 11.8 percent and 8.8 percent for DBJV and certain of the Appalachia Midstream Investments, respectively, and reflected our cost of capital as impacted by market conditions, and risks associated with the underlying businesses.

(8) Relates to equity-method investments in DBJV, certain of the Appalachia Midstream Investments, UEOM, and Laurel Mountain. We estimated the fair value of these investments using an income approach based on expected future cash flows and appropriate discount rates. The determination of estimated future cash flows involved significant assumptions regarding gathering volumes and related capital spending. Discount rates utilized ranged from 10.8 percent to 14.4 percent and reflected further fourth-quarter 2015 increases in our cost of capital, revised estimates of expected future cash flows, and risks associated with the underlying businesses.

(9) Relates to equity-method investments in DBJV and Laurel Mountain. Our carrying values in these equity-method investments had been written down to fair value at December 31, 2015. Our first-quarter 2016 analysis reflected higher discount rates for both of these investments, along with lower natural gas prices for Laurel Mountain. We estimated the fair value of these investments using an income approach based on expected future cash flows and appropriate discount rates. The determination of estimated future cash flows involved significant assumptions regarding gathering volumes and related capital spending. Discount rates utilized ranged from 13.0 percent to 13.3 percent and reflected increases in our cost of capital, revised estimates of expected future cash flows, and risks associated with the underlying businesses.

(10) Relates to equity-method investments in Ranch Westex and multiple Appalachia Midstream Investments. The historical carrying value of these investments was initially recorded based on estimated fair value during the third quarter of 2014 in conjunction with the acquisition of ACMP. We estimated the fair value of these Appalachia Midstream Investments using an income approach based on expected future cash flows and appropriate discount

138

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

rates. The determination of estimated future cash flows involved significant assumptions regarding gathering volumes, rates, and related capital spending. The discount rate utilized for the Appalachia Midstream Investments evaluation was 10.2 percent and reflected our cost of capital as impacted by market conditions and risks associated with the underlying businesses. In addition to utilizing an income approach, we also considered a market approach for certain Appalachia Midstream Investments and Ranch Westex based on an agreement reached in February 2017 to exchange our interests in DBJV and Ranch Westex for additional interests in certain Appalachia Midstream Investments and cash.

Concentration of Credit Risk

Cash equivalents

Our cash equivalents are primarily invested in funds with high-quality, short-term securities and instruments that are issued or guaranteed by the U.S. government.

Trade accounts and other receivables

The following table summarizes concentration of receivables, net of allowances:

	December 31,
	2016		2015
	(Millions)
NGLs, natural gas, and related products and services	$	736	$	823
Transportation of natural gas and related products	187		202
Other	15		16
Total	$	938	$	1,041

Customers include producers, distribution companies, industrial users, gas marketers, and pipelines primarily located in the continental United States. As a general policy, collateral is not required for receivables, but customers’ financial condition and credit worthiness are evaluated regularly. Based upon this evaluation, we may obtain collateral to support receivables. As of December 31, 2016 and 2015, Chesapeake Energy Corporation, and its affiliates (Chesapeake), a customer within our Williams Partners segment, accounted for$133 million and $364 million, respectively, of the consolidated Trade accounts and other receivables balances.

Revenues

In 2016 and 2015, Chesapeake accounted for 14 percent and 18 percent, respectively, of our consolidated revenues.

Note 18 – Contingent Liabilities and Commitments

Reporting of Natural Gas-Related Information to Trade Publications

Direct and indirect purchasers of natural gas in various states filed an individual and class actions against us, our former affiliate WPX and its subsidiaries, and others alleging the manipulation of published gas price indices and seeking unspecified amounts of damages. Such actions were transferred to the Nevada federal district court for consolidation of discovery and pre-trial issues. We have agreed to indemnify WPX and its subsidiaries related to this matter.

In the individual action, filed by Farmland Industries Inc. (Farmland), the court issued an order on May 24, 2016, granting one of our co-defendant’s motion for summary judgment as to Farmland’s claims. On January 5, 2017, the court extended such ruling to us, entering final judgment in our favor. Farmland has appealed.

Because of the uncertainty around the remaining pending unresolved issues, including an insufficient description of the purported classes and other related matters, we cannot reasonably estimate a range of potential exposure at this

139

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

time. However, it is reasonably possible that the ultimate resolution of these actions and our related indemnification obligation could result in a potential loss that may be material to our results of operations. In connection with this indemnification, we have an accrued liability balance associated with this matter, and as a result, have exposure to future developments in this matter.

Geismar Incident

On June 13, 2013, an explosion and fire occurred at our Geismar olefins plant and rendered the facility temporarily inoperable (Geismar Incident). As a result, there were two fatalities and numerous individuals (including employees and contractors) reported injuries. We are addressing the following contingent liabilities in connection with the Geismar Incident.

On October 21, 2013, the U.S. Environmental Protection Agency (EPA) issued an Inspection Report pursuant to the Clean Air Act’s Risk Management Program following its inspection of the facility on June 24 through June 28, 2013. The report notes the EPA’s preliminary determinations about the facility’s documentation regarding process safety, process hazard analysis, as well as operating procedures, employee training, and other matters. On June 16, 2014, we received a request for information related to the Geismar Incident from the EPA under Section 114 of the Clean Air Act to which we responded on August 13, 2014. The EPA could issue penalties pertaining to final determinations.

Multiple lawsuits, including class actions for alleged offsite impacts, property damage, customer claims, and personal injury, have been filed against us. To date, we have settled certain of the personal injury claims for an aggregate immaterial amount that we have recovered from our insurers. The first two trials, for nine plaintiffs claiming personal injury, were held in Louisiana state court in Iberville Parish, Louisiana in September and November 2016. The juries returned adverse verdicts against us, our subsidiary Williams Olefins, LLC, and other defendants. The defendants, including us, intend to appeal the verdicts. Trial dates for additional plaintiffs are scheduled in April 2017 and August 2017. We believe it is probable that additional losses will be incurred on some lawsuits, while for others we believe it is only reasonably possible that losses will be incurred. However, due to ongoing litigation involving defenses to liability, the number of individual plaintiffs, limited information as to the nature and extent of all plaintiffs’ damages, and the ultimate outcome of all appeals, we are unable to reliably estimate any such losses at this time. We believe that it is probable that any ultimate losses incurred will be covered by our general liability insurance policy, which has an aggregate limit of $610 million applicable to this event and retention (deductible) of $2 million per occurrence.

Alaska Refinery Contamination Litigation

In 2010, James West filed a class action lawsuit in state court in Fairbanks, Alaska on behalf of individual property owners whose water contained sulfolane contamination allegedly emanating from the Flint Hills Oil Refinery in North Pole, Alaska. The suit named our subsidiary, Williams Alaska Petroleum Inc. (WAPI), and Flint Hills Resources Alaska, LLC (FHRA), a subsidiary of Koch Industries, Inc., as defendants. We owned and operated the refinery until 2004 when we sold it to FHRA. We and FHRA made claims under the pollution liability insurance policy issued in connection with the sale of the North Pole refinery to FHRA. We and FHRA also filed claims against each other seeking, among other things, contractual indemnification alleging that the other party caused the sulfolane contamination.

In 2011, we and FHRA settled the James West claim. We and FHRA subsequently filed motions for summary judgment on the other’s claims. On July 8, 2014, the court dismissed all FHRA’s claims and entered judgment for us. On August 6, 2014, FHRA appealed the court’s decision to the Alaska Supreme Court, which heard oral arguments in October of 2015, and issued a decision on August 26, 2016. The Alaska Supreme Court affirmed dismissal of FHRA’s equitable claims and statutory claims for damages related to sulfolane located on the refinery property. The Alaska Supreme Court remanded FHRA’s claims against us for contractual indemnification and statutory claims for damages related to off-site sulfolane for further resolution by the trial court. We currently estimate that our reasonably possible loss exposure in this matter could range from an insignificant amount up to $32 million, although uncertainties inherent in the litigation process, expert evaluations, and jury dynamics might cause our exposure to exceed that amount.

140

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

On March 6, 2014, the State of Alaska filed suit against FHRA, WAPI, and us in state court in Fairbanks seeking injunctive relief and damages in connection with sulfolane contamination of the water supply near the Flint Hills Oil Refinery in North Pole, Alaska. On May 5, 2014, FHRA filed cross-claims against us in the State of Alaska suit. FHRA also seeks injunctive relief and damages.

On November 26, 2014, the City of North Pole (North Pole) filed suit in Alaska state court in Fairbanks against FHRA, WAPI, and us alleging nuisance and violations of municipal and state statutes based upon the same alleged sulfolane contamination of the water supply. North Pole claims an unspecified amount of past and future damages as well as punitive damages against WAPI. FHRA filed cross-claims against us.

In October of 2015, the court consolidated the State of Alaska and North Pole cases. On February 29, 2016, we and WAPI filed Amended Answers in the consolidated cases. Both we and WAPI asserted counter claims against both the State of Alaska and North Pole, and cross claims against FHRA. A trial is scheduled to commence May 30, 2017. All or a portion of the exposure in this consolidated State of Alaska and North Pole action may duplicate exposure in the James West case. As such, on February 9, 2017, the remanded claims in the James West case were consolidated into the State of Alaska and North Pole action. Due to the ongoing assessment of the level and extent of sulfolane contamination, the lack of an articulated cleanup level for sulfolane, and the lack of a concrete remedial proposal and cost estimate, we are unable to estimate a range of exposure for the consolidated action at this time.

Independent of the litigation matter described in the preceding paragraphs, in 2013, the Alaska Department of Environmental Conservation indicated that it views FHRA and us as responsible parties, and that it intended to enter a compliance order to address the environmental remediation of sulfolane and other possible contaminants including cleanup work outside the refinery’s boundaries. Due to the ongoing assessment of the level and extent of sulfolane contamination and the ultimate cost of remediation and division of costs among the potentially responsible parties, we are unable to estimate a range of exposure at this time.

Royalty Matters

Certain of our customers, including one major customer, have been named in various lawsuits alleging underpayment of royalties and claiming, among other things, violations of anti-trust laws and the Racketeer Influenced and Corrupt Organizations Act. We have also been named as a defendant in certain of these cases in Texas, Pennsylvania, and Ohio based on allegations that we improperly participated with that major customer in causing the alleged royalty underpayments. We have also received subpoenas from the United States Department of Justice and the Pennsylvania Attorney General requesting documents relating to the agreements between us and our major customer and calculations of the major customer’s royalty payments. On December 9, 2015, the Pennsylvania Attorney General filed a civil suit against one of our major customers and us alleging breaches of the Pennsylvania Unfair Trade Practices and Consumer Protection Law, and on February 8, 2016, the Pennsylvania Attorney General filed an amended complaint in such civil suit, which omitted us as a party. We believe that the claims asserted are subject to indemnity obligations owed to us by that major customer. Our customer and plaintiffs in the Texas cases reached a settlement, and therefore all claims asserted (or possibly asserted) by any such plaintiffs against us in the Texas cases have been fully dismissed with prejudice. On February 7, 2017, the plaintiffs in the Ohio case voluntarily dismissed the case without prejudice. Due to the preliminary status of the remaining cases, we are unable to estimate a range of potential loss at this time.

Shareholder Litigation

Between October 2015 and December 2015, purported shareholders of us filed six putative class action lawsuits in the Delaware Court of Chancery that were consolidated into a single suit on January 13, 2016. This consolidated putative class action lawsuit relates to our terminated merger with Energy Transfer Equity, L.P. (Energy Transfer). The complaint asserts various claims against the individual members of our Board of Directors, including that they breached their fiduciary duties by agreeing to sell us through an allegedly unfair process and for an allegedly unfair price and by allegedly failing to disclose allegedly material information about the merger. The complaint seeks, among other things, an injunction against the merger and an award of costs and attorneys’ fees. On March 22, 2016, the court granted

141

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

the parties’ proposed order in the consolidated action to stay the proceedings pending the close of the transaction with Energy Transfer. The plaintiffs have not filed an amended complaint.

A purported shareholder filed a separate class action lawsuit in the Delaware Court of Chancery on January 15, 2016. The putative class action complaint alleged that the individual members of our Board of Directors breached their fiduciary duties by, among other things, agreeing to the WPZ Merger Agreement, which purportedly reduced the merger consideration to have been received in the subsequently proposed but now terminated merger with Energy Transfer. The plaintiff filed a motion to voluntarily dismiss, which the court granted on January 13, 2017. On September 2, 2016, the same purported shareholder filed a derivative action claiming that the members of our Board of Directors breached their fiduciary duties by executing the WPZ Merger Agreement as a defensive measure against Energy Transfer. On September 28, 2016, we requested the court dismiss this action also.

On March 7, 2016, a purported unitholder of WPZ filed a putative class action on behalf of certain purchasers of WPZ units in U.S. District Court in Oklahoma. The action names as defendants us, WPZ, Williams Partners GP LLC, Alan S. Armstrong, and Donald R. Chappel and alleges violations of certain federal securities laws for failure to disclose Energy Transfer’s intention to pursue a purchase of us conditioned on us not closing the WPZ Merger Agreement when announcing the WPZ Merger Agreement. The complaint seeks, among other things, damages and an award of costs and attorneys’ fees. The plaintiff filed an amended complaint on August 31, 2016. On October 17, 2016, we requested the court dismiss the action. We cannot reasonably estimate a range of potential loss at this time.

Litigation against Energy Transfer and related parties

On April 6, 2016, we filed suit in Delaware Chancery Court against Energy Transfer and LE GP, LLC (the general partner for Energy Transfer) alleging willful and material breaches of the Agreement and Plan of Merger (Merger Agreement) with Energy Transfer resulting from the private offering by Energy Transfer on March 8, 2016, of Series A Convertible Preferred Units (Special Offering) to certain Energy Transfer insiders and other accredited investors. The suit seeks, among other things, an injunction ordering the defendants to unwind the Special Offering and to specifically perform their obligations under the Merger Agreement. On April 19, 2016, we filed an amended complaint seeking the same relief. On May 3, 2016, Energy Transfer and LE GP, LLC filed an answer and counterclaims.

On May 13, 2016, we filed a separate complaint in Delaware Chancery Court against Energy Transfer, LE GP, LLC, and the other Energy Transfer affiliates that are parties to the Merger Agreement, alleging material breaches of the Merger Agreement for failing to cooperate and use necessary efforts to obtain a tax opinion required under the Merger Agreement (Tax Opinion) and for otherwise failing to use necessary efforts to consummate the merger under the Merger Agreement wherein we would be merged with and into the newly formed Energy Transfer Corp LP (ETC) (ETC Merger). The suit sought, among other things, a declaratory judgment and injunction preventing Energy Transfer from terminating or otherwise avoiding its obligations under the Merger Agreement due to any failure to obtain the Tax Opinion.

The Court of Chancery coordinated the Special Offering and Tax Opinion suits. On May 20, 2016, the Energy Transfer defendants filed amended affirmative defenses and verified counterclaims in the Special Offering and Tax Opinion suits, alleging certain breaches of the Merger Agreement by us and seeking, among other things, a declaration that we were not entitled to specific performance, that Energy Transfer could terminate the ETC Merger, and that Energy Transfer is entitled to a $1.48 billion termination fee. On June 24, 2016, following a two-day trial, the court issued a Memorandum Opinion and Order denying our requested relief in the Tax Opinion suit. The court did not rule on the substance of our claims related to the Special Offering or on the substance of Energy Transfer’s counterclaims. On June 27, 2016, we filed an appeal of the court’s decision with the Supreme Court of Delaware, seeking reversal and remand to pursue damages. The appeal has been fully briefed for consideration by the Supreme Court of Delaware, and oral argument occurred on January 11, 2017.

On September 16, 2016, we filed an amended complaint with the Court of Chancery seeking damages for breaches of the Merger Agreement by defendants.  On September 23, 2016, Energy Transfer filed a second amended and supplemental affirmative defenses and verified counterclaim with the Court of Chancery seeking, among other things,

142

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

payment of the $1.48 billion termination fee due to our alleged breaches of the Merger Agreement. We filed a motion to dismiss Energy Transfer’s counterclaims, which was fully briefed on November 14, 2016, and oral argument occurred on November 30, 2016.

Environmental Matters

We are a participant in certain environmental activities in various stages including assessment studies, cleanup operations, and remedial processes at certain sites, some of which we currently do not own. We are monitoring these sites in a coordinated effort with other potentially responsible parties, the EPA, and other governmental authorities. We are jointly and severally liable along with unrelated third parties in some of these activities and solely responsible in others. Certain of our subsidiaries have been identified as potentially responsible parties at various Superfund and state waste disposal sites. In addition, these subsidiaries have incurred, or are alleged to have incurred, various other hazardous materials removal or remediation obligations under environmental laws. As of December 31, 2016, we have accrued liabilities totaling $38 million for these matters, as discussed below. Our accrual reflects the most likely costs of cleanup, which are generally based on completed assessment studies, preliminary results of studies, or our experience with other similar cleanup operations. Certain assessment studies are still in process for which the ultimate outcome may yield significantly different estimates of most likely costs. Any incremental amount in excess of amounts currently accrued cannot be reasonably estimated at this time due to uncertainty about the actual number of contaminated sites ultimately identified, the actual amount and extent of contamination discovered, and the final cleanup standards mandated by the EPA and other governmental authorities.

The EPA and various state regulatory agencies routinely promulgate and propose new rules, and issue updated guidance to existing rules. More recent rules and rulemakings include, but are not limited to, rules for reciprocating internal combustion engine maximum achievable control technology, new air quality standards for one hour nitrogen dioxide emissions, and volatile organic compound and methane new source performance standards impacting design and operation of storage vessels, pressure valves, and compressors. On October 1, 2015, the EPA issued its new rule regarding National Ambient Air Quality Standards for ground-level ozone, setting a new standard of 70 parts per billion. We are monitoring the rule’s implementation and evaluating potential impacts to our operations. For these and other new regulations, we are unable to estimate the costs of asset additions or modifications necessary to comply due to uncertainty created by the various legal challenges to these regulations and the need for further specific regulatory guidance.

Continuing operations

Our interstate gas pipelines are involved in remediation activities related to certain facilities and locations for polychlorinated biphenyls, mercury, and other hazardous substances. These activities have involved the EPA and various state environmental authorities, resulting in our identification as a potentially responsible party at various Superfund waste sites. At December 31, 2016, we have accrued liabilities of $9 million for these costs. We expect that these costs will be recoverable through rates.

We also accrue environmental remediation costs for natural gas underground storage facilities, primarily related to soil and groundwater contamination. At December 31, 2016, we have accrued liabilities totaling $7 million for these costs.

Former operations, including operations classified as discontinued

We have potential obligations in connection with assets and businesses we no longer operate. These potential obligations include remediation activities at the direction of federal and state environmental authorities and the indemnification of the purchasers of certain of these assets and businesses for environmental and other liabilities existing at the time the sale was consummated. Our responsibilities relate to the operations of the assets and businesses described below.

• Former agricultural fertilizer and chemical operations and former retail petroleum and refining operations;

143

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

• Former petroleum products and natural gas pipelines;

• Former petroleum refining facilities;

• Former exploration and production and mining operations;

• Former electricity and natural gas marketing and trading operations.

At December 31, 2016, we have accrued environmental liabilities of $22 million related to these matters.

Other Divestiture Indemnifications

Pursuant to various purchase and sale agreements relating to divested businesses and assets, we have indemnified certain purchasers against liabilities that they may incur with respect to the businesses and assets acquired from us. The indemnities provided to the purchasers are customary in sale transactions and are contingent upon the purchasers incurring liabilities that are not otherwise recoverable from third parties. The indemnities generally relate to breach of warranties, tax, historic litigation, personal injury, property damage, environmental matters, right of way, and other representations that we have provided.

At December 31, 2016, other than as previously disclosed, we are not aware of any material claims against us involving the indemnities; thus, we do not expect any of the indemnities provided pursuant to the sales agreements to have a material impact on our future financial position. Any claim for indemnity brought against us in the future may have a material adverse effect on our results of operations in the period in which the claim is made.

In addition to the foregoing, various other proceedings are pending against us which are incidental to our operations.

Summary

We have disclosed our estimated range of reasonably possible losses for certain matters above, as well as all significant matters for which we are unable to reasonably estimate a range of possible loss. We estimate that for all other matters for which we are able to reasonably estimate a range of loss, our aggregate reasonably possible losses beyond amounts accrued are immaterial to our expected future annual results of operations, liquidity, and financial position. These calculations have been made without consideration of any potential recovery from third parties.

Commitments

Commitments for construction and acquisition of property, plant, and equipment are approximately $244 million at December 31, 2016.

Note 19 – Segment Disclosures

Our reportable segments are Williams Partners and Williams NGL & Petchem Services. All remaining business activities are included in Other. (See Note 1 – General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies.)

Our segment presentation of Williams Partners, which includes our consolidated master limited partnership, is reflective of the parent-level focus by our chief operating decision-maker, considering the resource allocation and governance provisions associated with the master limited partnership structure. This partnership maintains capital and cash management structures that are separate from ours. It is self-funding and maintains its own lines of bank credit and cash management accounts. These factors, coupled with different costs of capital from our other businesses, serve to differentiate the management of this entity as a whole.

144

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

Performance Measurement

We evaluate segment operating performance based upon Modified EBITDA (earnings before interest, taxes, depreciation, and amortization). This measure represents the basis of our internal financial reporting and is the primary performance measure used by our chief operating decision maker in measuring performance and allocating resources among our reportable segments.

We define Modified EBITDA as follows:

•Net income (loss) before:

◦Income (loss) from discontinued operations;

◦Provision (benefit) for income taxes;

◦Interest incurred, net of interest capitalized;

◦Equity earnings (losses);

◦Gain on remeasurement of equity-method investment;

◦Impairment of equity-method investments;

◦Other investing income (loss) – net;

◦Impairment of goodwill;

◦Depreciation and amortization expenses;

◦Accretion expense associated with asset retirement obligations for nonregulated operations.

• This measure is further adjusted to include our proportionate share (based on ownership interest) of Modified EBITDA from our equity-method investments calculated consistently with the definition described above.

The following geographic area data includes Revenues from external customers based on product shipment origin and Long-lived assets based upon physical location:

		United States		Canada		Total
		(Millions)
Revenues from external customers:
	2016	$	7,425	$	74	$	7,499
	2015	7,247		113		7,360
	2014	7,229		408		7,637
Long-lived assets:
	2016	$	38,091	$	—	$	38,091
	2015	38,016		1,580		39,596
	2014	38,290		1,364		39,654

Long-lived assets are comprised of property, plant, and equipment, goodwill, and other intangible assets.

145

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

The following table reflects the reconciliation of Segment revenues to Total revenues as reported in the Consolidated Statement of Operations and Other financial information:

	Williams Partners		Williams NGL & Petchem Services			Other		Eliminations			Total
	(Millions)
2016
Segment revenues:
Service revenues
External	$	5,140	$	2		$	29	$	—		$	5,171
Internal	33		—			19		(52		)	—
Total service revenues	5,173		2			48		(52		)	5,171
Product sales
External	2,318		10			—		—			2,328
Internal	—		16			—		(16		)	—
Total product sales	2,318		26			—		(16		)	2,328
Total revenues	$	7,491	$	28		$	48	$	(68	)	$	7,499
Other financial information:
Additions to long-lived assets	$	2,102	$	33		$	11	$	(1	)	$	2,145
Proportional Modified EBITDA of equity-method investments	754		—			—		—			754
2015
Segment revenues:
Service revenues
External	$	5,134	$	2		$	28	$	—		$	5,164
Internal	1		—			158		(159		)	—
Total service revenues	5,135		2			186		(159		)	5,164
Product sales
External	2,196		—			—		—			2,196
Internal	—		—			—		—			—
Total product sales	2,196		—			—		—			2,196
Total revenues	$	7,331	$	2		$	186	$	(159	)	$	7,360
Other financial information:
Additions to long-lived assets	$	2,960	$	360		$	28	$	(12	)	$	3,336
Proportional Modified EBITDA of equity-method investments	699		—			—		—			699
2014
Segment revenues:
Service revenues
External	$	3,887	$	—		$	229	$	—		$	4,116
Internal	1		—			30		(31		)	—
Total service revenues	3,888		—			259		(31		)	4,116
Product sales
External	3,521		—			—		—			3,521
Internal	—		—			—		—			—
Total product sales	3,521		—			—		—			3,521
Total revenues	$	7,409	$	—		$	259	$	(31	)	$	7,637
Other financial information:
Additions to long-lived assets (1)	$	20,413	$	291		$	54	$	(2	)	$	20,756
Proportional Modified EBITDA of equity-method investments	431		(78		)	85		—			438

_______________

(1) 2014 Additions to long-lived assets within our Williams Partners segment primarily includes the acquisition-date fair value of long-lived assets from the ACMP Acquisition. (See Note 2 - Acquisitions.)

146

The Williams Companies, Inc.

Notes to Consolidated Financial Statements – (Continued)

The following table reflects the reconciliation of Modified EBITDA to Net income (loss) as reported in the Consolidated Statement of Operations:

	Years Ended December 31,
	2016			2015			2014
	(Millions)
Modified EBITDA by segment:
Williams Partners	$	3,864		$	4,003		$	3,244
Williams NGL & Petchem Services	(540		)	(83		)	(115		)
Other	(2		)	(29		)	103
	3,322			3,891			3,232
Accretion expense associated with asset retirement obligations for nonregulated operations	(31		)	(28		)	(18		)
Depreciation and amortization expenses	(1,763		)	(1,738		)	(1,176		)
Impairment of goodwill	—			(1,098		)	—
Equity earnings (losses)	397			335			144
Gain on remeasurement of equity-method investment	—			—			2,544
Impairment of equity-method investments	(430		)	(1,359		)	—
Other investing income (loss) – net	63			27			43
Proportional Modified EBITDA of equity-method investments	(754		)	(699		)	(438		)
Interest expense	(1,179		)	(1,044		)	(747		)
(Provision) benefit for income taxes	25			399			(1,249		)
Income (loss) from discontinued operations, net of tax	—			—			4
Net income (loss)	$	(350	)	$	(1,314	)	$	2,339

The following table reflects Total assets and Equity-method investments by reportable segments:

	Total Assets						Equity-Method Investments
	December 31, 2016			December 31, 2015			December 31, 2016		December 31, 2015
	(Millions)
Williams Partners	$	46,265		$	47,870		$	6,701	$	7,336
Williams NGL & Petchem Services	249			835			—		—
Other	674			850			—		—
Eliminations	(353		)	(535		)	—		—
Total	$	46,835		$	49,020		$	6,701	$	7,336

147

The Williams Companies Inc.

Quarterly Financial Data

(Unaudited)

Summarized quarterly financial data are as follows:

	First Quarter			Second Quarter			Third Quarter			Fourth Quarter
	(Millions, except per-share amounts)
2016
Revenues	$	1,660		$	1,736		$	1,905		$	2,198
Product costs	318			401			461			545
Net income (loss)	(13		)	(505		)	131			37
Amounts attributable to The Williams Companies, Inc.:
Net income (loss)	(65		)	(405		)	61			(15		)
Basic and diluted earnings (loss) per common share	(.09		)	(.54		)	.08			(.02		)
2015
Revenues	$	1,716		$	1,839		$	1,799		$	2,006
Product costs	462			494			426			397
Net income (loss)	13			183			(173		)	(1,337		)
Amounts attributable to The Williams Companies, Inc.:
Net income (loss)	70			114			(40		)	(715		)
Basic and diluted earnings (loss) per common share:	.09			.15			(.05		)	(.95		)

The sum of earnings (loss) per share for the four quarters may not equal the total earnings (loss) per share for the year due to changes in the average number of common shares outstanding and rounding.

2016

Net income (loss) for fourth-quarter 2016 includes the following pretax items:

• $173 million of income associated with the amortization of deferred income related to the restructuring of certain gas gathering contracts in the Barnett Shale and Mid-Continent regions and $58 million of related minimum volume commitment fees (see Note 7 – Other Income and Expensesof Notes to Consolidated Financial Statements);

• $318 million impairment loss on certain equity-method investments (see Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk).

Net income (loss) for second-quarter 2016 includes a $747 million impairment loss on Canadian assets (see Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk).

Net income (loss) for first-quarter 2016 includes a $112 million impairment loss on certain equity-method investments (see Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk).

2015

Net income (loss) for fourth-quarter 2015 includes the following pretax items:

• $239 million in revenue associated with minimum volume commitment fees in the Barnett Shale and Mid-Continent regions (see Note 7 – Other Income and Expenses);

• $180 million impairment loss on certain assets (see Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk);

148

The Williams Companies Inc.

Quarterly Financial Data – (Continued)

(Unaudited)

• $898 million impairment loss on certain equity-method investments (see Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk);

• $1,098 million impairment of goodwill (see Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk).

Net income (loss) for third-quarter 2015 includes a $461 million impairment loss on certain equity-method investments (see Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk).

Net income (loss) for second-quarter 2015 includes a $126 million gain associated with insurance recoveries related to the Geismar Incident.

149

The Williams Companies, Inc.

Schedule I — Condensed Financial Information of Registrant

Statement of Comprehensive Income (Loss) (Parent)

	Years Ended December 31,
	2016			2015			2014
	(Millions, except per-share amounts)
Equity in earnings of consolidated subsidiaries	$	522		$	232		$	1,799
Equity earnings (losses) from investment in Access Midstream Partners	—			—			(7		)
Interest incurred — external	(268		)	(255		)	(206		)
Interest incurred — affiliate	(568		)	(828		)	(797		)
Interest income — affiliate	—			6			10
Gain on remeasurement of equity-method investment	—			—			2,544
Other income (expense) — net	(53		)	(75		)	(13		)
Income (loss) from continuing operations before income taxes	(367		)	(920		)	3,330
Provision (benefit) for income taxes	57			(349		)	1,220
Income (loss) from continuing operations	(424		)	(571		)	2,110
Income (loss) from discontinued operations	—			—			4
Net income (loss)	$	(424	)	$	(571	)	$	2,114
Basic earnings (loss) per common share:
Income (loss) from continuing operations	$	(.57	)	$	(.76	)	$	2.93
Income (loss) from discontinued operations	—			—			.01
Net income (loss)	$	(.57	)	$	(.76	)	$	2.94
Weighted-average shares (thousands)	750,673			749,271			719,325
Diluted earnings (loss) per common share:
Income (loss) from continuing operations	$	(.57	)	$	(.76	)	$	2.91
Income (loss) from discontinued operations	—			—			.01
Net income (loss)	$	(.57	)	$	(.76	)	$	2.92
Weighted-average shares (thousands)	750,673			749,271			723,641
Other comprehensive income (loss):
Equity in other comprehensive income (loss) of consolidated subsidiaries	$	171		$	(204	)	$	(96	)
Other comprehensive income (loss) attributable to The Williams Companies, Inc.	1			33			(80		)
Other comprehensive income (loss)	172			(171		)	(176		)
Less: Other comprehensive income (loss) attributable to noncontrolling interests	69			(70		)	(19		)
Comprehensive income (loss) attributable to The Williams Companies, Inc.	$	(321	)	$	(672	)	$	1,957

See accompanying notes.

150

The Williams Companies, Inc.

Schedule I — Condensed Financial Information of Registrant – (Continued)

Balance Sheet (Parent)

	December 31,
	2016		2015
	(Millions)
ASSETS
Current assets:
Cash and cash equivalents	$	14	$	12
Other current assets and deferred charges	16		62
Total current assets	30		74
Investments in and advances to consolidated subsidiaries	22,359		30,927
Property, plant, and equipment — net	77		99
Other noncurrent assets	8		12
Total assets	$	22,474	$	31,112
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	27	$	27
Other current liabilities	169		163
Total current liabilities	196		190
Long-term debt	4,939		4,811
Notes payable — affiliates	8,171		15,506
Pension, other postretirement, and other noncurrent liabilities	287		336
Deferred income tax liabilities	4,238		4,121
Contingent liabilities and commitments
Equity:
Common stock	785		784
Other stockholders’ equity	3,858		5,364
Total stockholders’ equity	4,643		6,148
Total liabilities and stockholders’ equity	$	22,474	$	31,112

See accompanying notes.

151

The Williams Companies, Inc.

Schedule I — Condensed Financial Information of Registrant – (Continued)

Statement of Cash Flows (Parent)

	Years Ended December 31,
	2016			2015			2014
	(Millions)
NET CASH FLOWS PROVIDED (USED) BY OPERATING ACTIVITIES	$	(833	)	$	(1,209	)	$	(500	)
FINANCING ACTIVITIES:
Proceeds from long-term debt	2,280			2,097			2,935
Payments of long-term debt	(2,155		)	(1,817		)	(671		)
Changes in notes payable to affiliates	9			2,211			2,465
Tax benefit of stock-based awards	—			—			25
Proceeds from issuance of common stock	9			27			3,416
Dividends paid	(1,261		)	(1,836		)	(1,412		)
Other — net	—			(2		)	(17		)
Net cash provided (used) by financing activities	(1,118		)	680			6,741
INVESTING ACTIVITIES:
Capital expenditures	(13		)	(29		)	(54		)
Purchase of Access Midstream Partners	—			—			(5,995		)
Changes in investments in and advances to consolidated subsidiaries	1,966			521			(450		)
Other — net	—			—			25
Net cash provided (used) by investing activities	1,953			492			(6,474		)
Increase (decrease) in cash and cash equivalents	2			(37		)	(233		)
Cash and cash equivalents at beginning of year	12			49			282
Cash and cash equivalents at end of year	$	14		$	12		$	49

See accompanying notes.

152

The Williams Companies, Inc.

Schedule I — Condensed Financial Information of Registrant – (Continued)

Notes to Financial Information (Parent)

Note 1. Guarantees

In addition to the guarantees disclosed in the accompanying consolidated financial statements in Item 8, we have financially guaranteed the performance of certain consolidated subsidiaries. The duration of these guarantees varies, and we estimate the maximum undiscounted potential future payment obligation related to these guarantees as of December 31, 2016, is approximately $305 million.

Note 2. Cash Dividends Received

We receive dividends and distributions either directly from our subsidiaries or indirectly through dividends received by subsidiaries and subsequent transfers of cash to us through our corporate cash management system. The total of such receipts ultimately related to dividends and distributions for the years ended December 31, 2016, 2015, and 2014 was approximately $1.7 billion, $1.8 billion, and $1.9 billion, respectively.

153

The Williams Companies, Inc.

Schedule II — Valuation and Qualifying Accounts

			Additions
	Beginning Balance		Charged (Credited) To Costs and Expenses			Other		Deductions		Ending Balance
	(Millions)
2016
Allowance for doubtful accounts — accounts and notes receivable (1)	$	3	$	6		$	—	$	3	$	6
Deferred tax asset valuation allowance (1)	190		144			—		—		334
2015
Allowance for doubtful accounts — accounts and notes receivable (1)	—		3			—		—		3
Deferred tax asset valuation allowance (1)	206		(16		)	—		—		190
2014
Allowance for doubtful accounts — accounts and notes receivable (1)	—		—			—		—		—
Deferred tax asset valuation allowance (1)	181		25			—		—		206

__________

(1)    Deducted from related assets.

154

Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

None.

Item 9A. Controls and Procedures

Disclosure Controls and Procedures

Our management, including our Chief Executive Officer and Chief Financial Officer, does not expect that our disclosure controls and procedures (as defined in Rules 13a - 15(e) and 15d - 15(e) of the Securities Exchange Act) (Disclosure Controls) will prevent all errors and all fraud. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within the company have been detected. These inherent limitations include the realities that judgments in decision-making can be faulty, and that breakdowns can occur because of simple error or mistake. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control. The design of any system of controls also is based in part upon certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions. Because of the inherent limitations in a cost-effective control system, misstatements due to error or fraud may occur and not be detected. We monitor our Disclosure Controls and make modifications as necessary; our intent in this regard is that the Disclosure Controls will be modified as systems change and conditions warrant.

Evaluation of Disclosure Controls and Procedures

An evaluation of the effectiveness of the design and operation of our Disclosure Controls was performed as of the end of the period covered by this report. This evaluation was performed under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer. Based upon that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that these Disclosure Controls are effective at a reasonable assurance level.

Changes in Internal Control Over Financial Reporting

There have been no changes during the fourth quarter of 2016 that have materially affected, or are reasonably likely to materially affect, our Internal Control over Financial Reporting.

Management’s Annual Report on Internal Control over Financial Reporting

Management is responsible for establishing and maintaining adequate internal control over financial reporting (as defined in Rules 13a - 15(f) and 15d - 15(f) under the Securities Exchange Act of 1934). Our internal control over financial reporting is designed to provide reasonable assurance to our management and board of directors regarding the preparation and fair presentation of financial statements in accordance with accounting principles generally accepted in the United States. Our internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of our assets; (ii) provide reasonable assurance that transactions are recorded as to permit preparation of financial statements in accordance with generally accepted accounting principles, and that our receipts and expenditures are being made only in accordance with authorization of our management and board of directors; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of our assets that could have a material effect on our financial statements.

All internal control systems, no matter how well designed, have inherent limitations including the possibility of human error and the circumvention or overriding of controls. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.

155

Under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, we assessed the effectiveness of our internal control over financial reporting as of December 31, 2016, based on the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in Internal Control — Integrated Framework (2013). Based on our assessment, we concluded that, as of December 31, 2016, our internal control over financial reporting was effective.

Ernst & Young LLP, our independent registered public accounting firm, has audited our internal control over financial reporting, as stated in their report which is included in this Annual Report on Form 10-K.

156

Report of Independent Registered Public Accounting Firm

On Internal Control Over Financial Reporting

The Board of Directors and Stockholders of

The Williams Companies, Inc.

We have audited The Williams Companies, Inc.’s internal control over financial reporting as of December 31, 2016, based on criteria established in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) (the COSO criteria). The Williams Companies, Inc.’s management is responsible for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting included in the accompanying Management’s Annual Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, The Williams Companies, Inc.maintained, in all material respects, effective internal control over financial reporting as of December 31, 2016, based on the COSO criteria.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet of The Williams Companies, Inc. as of December 31, 2016 and 2015, and the related consolidated statements of operations, comprehensive income (loss), changes in equity and cash flows for each of the three years in the period ended December 31, 2016, and our report datedFebruary 22, 2017,expressed an unqualified opinion thereon.

/s/ Ernst & Young LLP

Tulsa, Oklahoma

February 22, 2017

157

Item 9B. Other Information

None.

PART III

Item 10. Directors, Executive Officers and Corporate Governance

The information regarding our directors and nominees for director required by Item 401 of Regulation S-K will be presented under the heading “Election of Directors” in our definitive proxy statement prepared for the solicitation of proxies in connection with our Annual Meeting of Stockholders to be held May 18, 2017, which shall be filed no later than April 30, 2017 (Proxy Statement), which information is incorporated by reference herein.

Information regarding our executive officers required by Item 401(b) of Regulation S-K is presented at the end of Part I herein and captioned “Executive Officers of the Registrant” as permitted by General Instruction G(3) to and Instruction 3 to Item 401(b) of Regulation S-K.

Information required by Item 405 of Regulation S-K will be included under the heading “Section 16(a) Beneficial Ownership Reporting Compliance” in our Proxy Statement, which information is incorporated by reference herein.

Information required by paragraphs (c)(3), (d)(4) and (d)(5) of Item 407 of Regulation S-K will be included under the heading “Questions and Answers About the Annual Meeting and Voting” and “Corporate Governance and Board Matters” in our Proxy Statement, which information is incorporated by reference herein.

We have adopted a Code of Ethics for Senior Officers that applies to our Chief Executive Officer, Chief Financial Officer, and Controller, or persons performing similar functions. The Code of Ethics for Senior Officers, together with our Corporate Governance Guidelines, the charters for each of our board committees, and our Code of Business Conduct applicable to all employees are available on our Internet website at www.williams.com. We will provide, free of charge, a copy of our Code of Ethics or any of our other corporate documents listed above upon written request to our Corporate Secretary at Williams, One Williams Center, Suite 4700, Tulsa, Oklahoma 74172. We intend to disclose any amendments to or waivers of the Code of Ethics on behalf of our Chief Executive Officer, Chief Financial Officer, Controller, and persons performing similar functions on the corporate governance section of our Internet website at www.williams.com, promptly following the date of any such amendment or waiver.

Item 11. Executive Compensation

The information required by Item 402 and paragraphs (e)(4) and (e)(5) of Item 407 of Regulation S-K regarding executive compensation will be presented under the headings “Compensation Discussion and Analysis,” “Executive Compensation and Other Information,” “Compensation of Directors,” “Compensation and Management Development Committee Report on Executive Compensation,” and “Compensation Committee Interlocks and Insider Participation” in our Proxy Statement, which information is incorporated by reference herein. Notwithstanding the foregoing, the information provided under the heading “Compensation Committee Report on Executive Compensation” in our Proxy Statement is furnished and shall not be deemed to be filed for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, is not subject to the liabilities of that section and is not deemed incorporated by reference in any filing under the Securities Act of 1933, as amended.

Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

The information regarding securities authorized for issuance under equity compensation plans required by Item 201

(d) of Regulation S-K and the security ownership of certain beneficial owners and management required by Item 403 of Regulation S-K will be presented under the headings “Equity Compensation Stock Plans” and “Security Ownership

158

of Certain Beneficial Owners and Management” in our Proxy Statement, which information is incorporated by reference herein.

Item 13. Certain Relationships and Related Transactions, and Director Independence

The information regarding certain relationships and related transactions required by Item 404 and Item 407(a) of Regulation S-K will be presented under the heading “Corporate Governance and Board Matters” in our Proxy Statement, which information is incorporated by reference herein.

Item 14. Principal Accountant Fees and Services

The information regarding our principal accounting fees and services required by Item 9(e) of Schedule 14A will be presented under the heading “Principal Accountant Fees and Services” in our Proxy Statement, which information is incorporated by reference herein.

159

PART IV

Item 15. Exhibits and Financial Statement Schedules

(a) 1 and 2.

	Page
Covered by report of independent auditors:
Consolidated statement of operations for each year in the three-year period ended December 31, 2016	80
Consolidated statement of comprehensive income (loss) for each year in the three-year period ended December 31, 2016	81
Consolidated balance sheet at December 31, 2016 and 2015	82
Consolidated statement of changes in equity for each year in the three-year period ended December 31, 2016	83
Consolidated statement of cash flows for each year in the three-year period ended December 31, 2016	84
Notes to consolidated financial statements	85
Schedule for each year in the three-year period ended December 31, 2016:
I — Condensed financial information of registrant	150
II — Valuation and qualifying accounts	154
Not covered by report of independent auditors:
Quarterly financial data (unaudited)	148

All other schedules have been omitted since the required information is not present or is not present in amounts sufficient to require submission of the schedule, or because the information required is included in the financial statements and notes thereto.

(a) 3 and (b). The exhibits listed below are filed as part of this annual report.

INDEX TO EXHIBITS

Exhibit No.		Description
2.1+	—	Agreement and Plan of Merger dated as of May 12, 2015, by and among The Williams Companies, Inc., SCMS LLC, Williams Partners L.P., and WPZ GP LLC (filed on May 13, 2015 as Exhibit 2.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
2.2	—	Amendment No 1. to Agreement and Plan of Merger dated as of May 1, 2016, by and among The Williams Companies, Inc., Energy Transfer Corp LP, Energy Transfer Corp GP, LLC, Energy Transfer Equity, L.P., LE GP, LLC and Energy Transfer Equity GP, LLC  (filed on May 3, 2016 as Exhibit 2.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
2.3+	—	Agreement and Plan of Merger dated as of September 28, 2015, by and among The Williams Companies, Inc., Energy Transfer Corp LP, Energy Transfer Corp GP, LLC, Energy Transfer Equity, L.P., LE GP, LLC and Energy Transfer Equity GP, LLC (filed on October 1, 2015 as Exhibit 2.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).

160

Exhibit No.		Description
2.4	—	Share Purchase Agreement by and between The Williams Companies International Holdings B.V. and Inter Pipeline Ltd. and The Williams Companies, Inc., dated August 8, 2016 (filed on August 12, 2016 as Exhibit 2.1 to The Williams Companies, Inc.’s current report on Form 8-K (file No. 001-04174) and incorporated herein by reference).
2.5	—	Share Purchase Agreement by and between Williams Energy Canada LP and Inter Pipeline Ltd. and Williams Partners L.P., dated August 8, 2016 (filed on August 12, 2016 as Exhibit 2.2 to The Williams Companies, Inc.’s current report on Form 8-K (file No. 001-04174) and incorporated herein by reference).
2.6+	—	Interest Swap and Purchase Agreement by and among Western Gas Partners, LP, WGR Operating, LP, Delaware Basin JV Gathering LLC, Williams Partners L.P., Williams Midstream Gas Services LLC, and Appalachia Midstream Services, L.L.C., dated February 9, 2017 (filed on February 10, 2017 as exhibit 2.1 to The Williams Companies Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
3.1	—	Amended and Restated Certificate of Incorporation, as supplemented (filed on May 26, 2010 as Exhibit 3.1 to The Williams Companies Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
3.2	—	By-Laws (filed on January 20, 2017, as Exhibit 3.1 to The Williams Companies Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
4.1	—	Senior Indenture dated February 25, 1997, between MAPCO Inc. and Bank One Trust Company, N.A. (formerly The First National Bank of Chicago), as Trustee (filed February 25, 1997 as Exhibit 4.5.1 to MAPCO Inc.’s Amendment No. l to registration statement on Form S-3 (File No. 333-20837) and incorporated herein by reference).
4.2	—	Supplemental Indenture No. 1 dated March 5, 1997, between MAPCO Inc. and Bank One Trust Company, N.A. (formerly The First National Bank of Chicago), as Trustee (filed as Exhibit 4(o) to MAPCO Inc.’s annual report on Form 10-K for the fiscal year ended December 31, 1997 (File No. 001-05254) and incorporated herein by reference).
4.3	—	Supplemental Indenture No. 2 dated March 5, 1997, between MAPCO Inc. and Bank One Trust Company, N.A. (formerly The First National Bank of Chicago), as Trustee (filed as Exhibit 4(p) to MAPCO Inc.’s annual report on Form 10-K for the fiscal year ended December 31, 1997 (File No. 001-05254) and incorporated herein by reference).
4.4	—	Supplemental Indenture No. 3 dated March 31, 1998, among MAPCO Inc., Williams Holdings of Delaware, Inc. and Bank One Trust Company, N.A. (formerly The First National Bank of Chicago), as Trustee (filed as Exhibit 4(J) to Williams Holdings of Delaware, Inc.’s annual report on Form 10­ K for the fiscal year ended December 31, 1998 (File No. 000-20555) and incorporated herein by reference).
4.5	—	Supplemental Indenture No. 4 dated as of July 31, 1999, among Williams Holdings of Delaware, Inc., Williams and Bank One Trust Company, N.A. (formerly The First National Bank of Chicago), as Trustee (filed on March 28, 2000 as Exhibit 4(q) to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
4.6	—	Fifth Supplemental Indenture between Williams and Bank One Trust Company, N.A., as Trustee, dated as of January 17, 2001 (filed on March 12, 2001 as Exhibit 4(k) to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
4.7	—	Seventh Supplemental Indenture dated March 19, 2002, between The Williams Companies, Inc. as Issuer and Bank One Trust Company, National Association, as Trustee (filed on May 9, 2002 as Exhibit 4.1 to The Williams Companies, Inc.’s quarterly report on Form 10-Q (File No. 001-04174) and incorporated herein by reference).

161

Exhibit No.		Description
4.8	—	Indenture dated as of May 28, 2003, by and between The Williams Companies, Inc. and JPMorgan Chase Bank, as Trustee for the issuance of the 5.50% Junior Subordinated Convertible Debentures due 2033 (filed on August 12, 2003 as Exhibit 4.2 to The Williams Companies, Inc.’s quarterly report on Form 10-Q (File No. 001-04174) and incorporated herein by reference).
4.9	—	Indenture dated as of March 5, 2009, among The Williams Companies, Inc. and The Bank of New York Mellon Trust Company, N.A., as Trustee (filed on March 11, 2009 as Exhibit 4.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
4.10	—	Eleventh Supplemental Indenture dated as of February 1, 2010 between The Williams Companies, Inc. and The Bank of New York Mellon Trust Company, N.A. (filed on February 2, 2010 as Exhibit 4.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
4.11	—	First Supplemental Indenture dated as of February 1, 2010 between The Williams Companies, Inc. and The Bank of New York Mellon Trust Company, N.A. (filed on February 2, 2010 as Exhibit 4.2 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
4.12	—	Fifth Supplemental Indenture dated as of February 1, 2010 between The Williams Companies, Inc. and The Bank of New York Mellon Trust Company, N.A. (filed on February 2, 2010 as Exhibit 4.3 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
4.13	—	Indenture, dated December 18, 2012 between The Williams Companies, Inc. and The Bank of New York Mellon Trust Company, N.A. as trustee (filed on December 20, 2012 as Exhibit 4.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
4.14	—	First Supplemental Indenture, dated December 18, 2012, between The Williams Companies, Inc. and The Bank of New York Mellon Trust Company, N.A. as trustee (filed on December 20, 2012 as Exhibit 4.2 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
4.15	—	Second Supplemental Indenture, dated as of June 24, 2014, between The Williams Companies, Inc. and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on June 24, 2014 as Exhibit 4.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
4.16	—	Indenture, dated December 13, 2006, by and among Williams Partners L.P., Williams Partners Finance Corporation and The Bank of New York (filed on December 19, 2006 as Exhibit 4.1 to Pre-merger WPZ’s report on Form 8-K (File No. 001-32599) and incorporated herein by reference).
4.17	—	First Supplemental Indenture, dated as of February 2, 2015, among Williams Partners L.P., Williams Partners Finance Corporation and The Bank of New York Mellon Trust Company, N.A. (filed on February 3, 2015, as Exhibit 4.6 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
4.18	—	Indenture dated as of February 9, 2010, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A. (filed on February 10, 2010 as Exhibit 4.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).

162

Exhibit No.		Description
4.19	—	First Supplemental Indenture, dated as of February 2, 2015, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A. (filed on February 3, 2015, as Exhibit 4.5 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
4.20	—	Indenture, dated as of November 9, 2010, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on November 12, 2010 as Exhibit 4.1 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-32599) and incorporated herein by reference).
4.21	—	First Supplemental Indenture, dated as of November 9, 2010, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on November 12, 2010 as Exhibit 4.2 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-32599) and incorporated herein by reference).
4.22	—	Second Supplemental Indenture, dated as of November 17, 2011, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A., as trustee (filed November 18, 2011 as Exhibit 4.1 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-32599) and incorporated herein by reference).
4.23	—	Third Supplemental Indenture (including Form of 3.35% Senior Notes due 2022), dated as of August 14, 2012, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on August 14, 2012 as Exhibit 4.1 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-32599) and incorporated herein by reference).
4.24	—	Fourth Supplemental Indenture, dated as of November 15, 2013, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N .A., as trustee (filed on November 18, 2013 as Exhibit 4.1 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-32599) and incorporated herein by reference).
4.25	—	Fifth Supplemental Indenture, dated as of March 4, 2014, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on March 4, 2014 as Exhibit 4.1 to Williams Partners L.P.’s report on Form 8-K (File No. 001-32599) and incorporated herein by reference).
4.26	—	Sixth Supplemental Indenture, dated as of June 27, 2014, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on June 27, 2014 as Exhibit 4.1 to Williams Partners L.P.’s report on Form 8-K (File No. 001-32599) and incorporated herein by reference).
4.27	—	Seventh Supplemental Indenture, dated as of February 2, 2015, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A. (filed on February 3, 2015, as Exhibit 4.4 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
4.28	—	Eighth Supplemental Indenture, dated as of March 3, 2015, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on March 3, 2015 as Exhibit 4.1 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
4.29	—	Indenture, dated as of January 11, 2012, by and among the Chesapeake Midstream Partners, L.P., CHKM Finance Corp, the Guarantors named therein and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on January 11, 2012 as Exhibit 4.1 to Williams Partners L.P.’s (then known as Access Midstream Partners L.P.) current report on 8-K (File No. 001-34831) and incorporated herein by reference).

163

Exhibit No.		Description
4.30	—	First Supplemental Indenture, dated as of January 7, 2013, by and among Access Midstream Partners, L.P., ACMP Finance Corp., the guarantors named therein and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on February 21, 2014 as Exhibit 4.5 to Williams Partners L.P.’s (then known as Access Midstream Partners L.P.) annual report on 10-K (File No. 001-34831) and incorporated herein by reference).
4.31	—	Second Supplemental Indenture and Amendment - Subsidiary Guarantee, dated as of April 18, 2014 among the Access Midstream Partners, L.P., ACMP Finance Corp, the Guarantors named therein and The Bank of New York Mellon Trust Company, N.A., as trustee filed on May 1, 2014 as Exhibit 4.4 to Williams Partners L.P.’s (then known as Access Midstream Partners L.P.) quarterly report on 10-Q (File No. 001-34831) and incorporated herein by reference).
4.32	—	Third Supplemental Indenture among Williams Partners L.P., ACMP Finance Corp. and The Bank of New York Mellon Trust Company, N.A. (filed on February 3, 2015, as Exhibit 4.2 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
4.33	—	Indenture, dated as of December 19, 2012, by and among Access Midstream Partners, L.P., ACMP Finance Corp., the guarantors listed therein and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on December 19, 2012 as Exhibit 4.1 to Williams Partners L.P.’s (formerly known as Access Midstream Partners L.P.) current report on 8-K (File No. 001-34831) and incorporated herein by reference).
4.34	—	First Supplemental Indenture, dated as of December 19, 2012, among Access Midstream Partners, L.P., ACMP Finance Corp., the guarantors listed therein and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on December 19, 2012 as Exhibit 4.2 to Williams Partners L.P.’s (formerly known as Access Midstream Partners L.P.) current report on 8-K (File No. 001-34831) and incorporated herein by reference).
4.35	—	Second Supplemental Indenture and Amendment - Subsidiary Guarantee, dated as of January 7, 2013, by among Access Midstream Partners, L.P., ACMP Finance Corp., the guarantors named therein and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on February 21, 2014 as Exhibit 4.9 to Williams Partners L.P.’s (formerly known as Access Midstream Partners L.P.) annual report on 10-K (File No. 001-34831) and incorporated herein by reference).
4.36	—	Third Supplemental Indenture, dated as of March 7, 2014, among the Access Midstream Partners, L.P., ACMP Finance Corp, the Guarantors named therein and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on March 7, 2014 as Exhibit 4.2 to Williams Partners L.P.’s (formerly known as Access Midstream Partners L.P.) current report on 8-K (File No. 001-34831) and incorporated herein by reference).
4.37	—	Third Supplemental Indenture and Amendment - Subsidiary Guarantee, dated as of April 18, 2014, among the Access Midstream Partners, L.P., ACMP Finance Corp, the Guarantors named therein and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on May 1, 2014 as Exhibit 4.3 to Williams Partners L.P.’s (formerly known as Access Midstream Partners L.P.) quarterly report on 10-Q (File No. 001-34831) and incorporated herein by reference).
4.38	—	Fifth Supplemental Indenture dated as of February 2, 2015 among Williams Partners L.P., ACMP Finance Corp. and The Bank of New York Mellon Trust Company, N.A. (filed on February 3, 2015, as Exhibit 4.3 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
4.39	—	Senior Indenture dated as of November 30, 1995, between Northwest Pipeline Corporation and Chemical Bank, Trustee (filed September 14, 1995 as Exhibit 4.1 to Northwest Pipeline’s registration statement on Form S-3 (File No. 033-62639) and incorporated herein by reference).

164

Exhibit No.		Description
4.40	—	Indenture dated as of June 22, 2006, between Northwest Pipeline Corporation and JPMorgan Chase Bank, N.A., as Trustee (filed on June 23, 2006 as Exhibit 4.1 to Northwest Pipeline’s current report on Form 8-K (File No. 001-07414) and incorporated herein by reference).
4.41	—	Indenture dated as of April 5, 2007, between Northwest Pipeline Corporation and The Bank of New York (filed on April 5, 2007 as Exhibit 4.1 to Northwest Pipeline Corporation’s current report on Form 8-K (File No. 001-07414) and incorporated herein by reference).
4.42	—	Indenture dated May 22, 2008, between Northwest Pipeline GP and The Bank of New York Trust Company, N.A., as Trustee (filed on May 23, 2008 as Exhibit 4.1 to Northwest Pipeline GP’s current report on Form 8-K (File No. 001-07414) and incorporated herein by reference).
4.43	—	Senior Indenture dated as of July 15, 1996 between Transcontinental Gas Pipe Line Corporation and Citibank, N.A., as Trustee (filed on April 2, 1996 as Exhibit 4.1 to Transcontinental Gas Pipe Line Corporation’s registration statement on Form S-3 (File No. 333-02155) and incorporated herein by reference).
4.44	—	Indenture dated as of April 11, 2006 between Transcontinental Gas Pipe Line Corporation and JPMorgan Chase Bank, N.A., as Trustee (filed on April 11, 2006 as Exhibit 4.1 to Transcontinental Gas Pipe Line Corporation’s current report on Form 8-K (File No. 001-07584) and incorporated herein by reference).
4.45	—	Indenture dated May 22, 2008, between Transcontinental Gas Pipe Line Corporation and The Bank of New York Trust Company, N.A., as Trustee (filed on May 23, 2008 as Exhibit 4.1 to Transcontinental Gas Pipe Line Corporation’s current report on Form 8-K (File No. 001-07584) and incorporated herein by reference).
4.46	—	Indenture dated as of August 12, 2011, between Transcontinental Gas Pipe Line Company, LLC and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on August 12, 2011 as Exhibit 4.1 to Transcontinental Gas Pipe Line Company, LLC’s current report on Form 8K (File No. 001-07584) and incorporated herein by reference).
4.47	—	Indenture, dated as of July 13, 2012, between Transcontinental Gas Pipe Line Company, LLC and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on July 16, 2012 as Exhibit 4.1 to Transcontinental Gas Pipe Line Company, LLC’s current report on Form 8-K (File No. 001-07584) and incorporated herein by reference).
4.48	—	Indenture, dated as of January 22, 2016, between Transcontinental Gas Pipe Line Company, LLC and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on January 22, 2016 as Exhibit 4.1 to The Williams Company, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
10.1§	—	The Williams Companies Amended and Restated Retirement Restoration Plan effective January l, 2008 (filed on February 25, 2009 as Exhibit 10.1 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.2§	—	Form of Director and Officer Indemnification Agreement (filed on September 24, 2008 as Exhibit 10.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
10.3§	—	Form of 2013 Performance-Based Restricted Stock Unit Agreement among Williams and certain employees and officers (filed on February 27, 2013 as Exhibit 10.4 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).

165

Exhibit No.		Description
10.4§	—	Form of 2013 Restricted Stock Unit Agreement among Williams and certain employees and officers (filed on February 27, 2013 as Exhibit 10.5 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.5§	—	Form of 2013 Nonqualified Stock Option Agreement among Williams and certain employees and officers (filed on February 27, 2013 as Exhibit 10.6 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.6§	—	Form of 2013 Restricted Stock Unit Agreement among Williams and certain nonmanagement directors (filed on February 26, 2014 as Exhibit 10.11 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.7§	—	Form of 2014 Performance-Based Restricted Stock Unit Agreement among Williams and certain employees and officers (filed on February 26, 2014 as Exhibit 10.6 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.8§	—	Form of 2014 Restricted Stock Unit Agreement among Williams and certain employees and officers (filed on February 26, 2014 as Exhibit 10.7 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.9§	—	Form of 2014 Nonqualified Stock Option Agreement among Williams and certain employees and officers (filed on February 26, 2014 as Exhibit 10.8 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.10§	—	Form of 2014 Restricted Stock Unit Agreement among Williams and certain nonmanagement directors (filed on February 25, 2015 as Exhibit 10.12 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.11§	—	Form of October 2014 Leveraged Performance Unit Award Agreement among Williams and certain officers (filed on February 25, 2015 as Exhibit 10.13 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.12§	—	Form of Leveraged Performance Unit Award Agreement dated January 1, 2015 between Williams and Walter Bennett (filed on February 25, 2015 as Exhibit 10.14 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.13§	—	Form of 2015 Performance-Based Restricted Stock Unit Agreement among Williams and certain employees and officers (filed on February 25, 2015 as Exhibit 10.15 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.14§	—	Form of 2015 Time-Based Restricted Stock Unit Agreement among Williams and certain employees and officers (filed on February 25, 2015 as Exhibit 10.16 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.15§	—	Form of 2015 Nonqualified Stock Option Agreement among Williams and certain employees and officers (filed on February 25, 2015 as Exhibit 10.17 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.16§	—	Form of 2015 Short-Term Non-Equity Incentive Award Agreement among The Williams Companies Inc. and certain employees and officers (filed on October 29, 2015 as Exhibit 10.2 to The Williams Companies, Inc. quarterly report on Form 10-Q (File No. 001-04174) and incorporated herein by reference).
10.17§	—	Form of 2015 Non-Equity Incentive Award Agreement among The Williams Companies Inc. and certain employees and officers (filed on October 29, 2015 as Exhibit 10.3 to The Williams Companies, Inc. quarterly report on Form 10-Q (File No. 001-04174) and incorporated herein by reference).

166

Exhibit No.		Description
10.18*§	—	Form of 2016 Performance-Based Restricted Stock Unit Agreement among Williams and certain employees and officers.
10.19*§	—	Form of 2016 Time-Based Restricted Stock Unit Agreement among Williams and certain employees and officers.
10.20*§	—	Form of 2016 Time-Based Restricted Stock Unit Agreement among Williams and certain employees and officers vesting February 22, 2019.
10.21*§	—	Form of 2016 Time-Based Restricted Stock Unit Agreement among Williams and certain non-management directors.
10.22*§	—	Form of 2016 Nonqualified Stock Option Agreement among Williams and certain employees and officers.
10.23*§	—	Form of 2017 Time-Based Restricted Stock Unit Agreement among Williams and certain employees and officers.
10.24*§	—	Form of 2017 Time-Based Restricted Stock Unit Agreement among Williams and certain non-management directors.
10.25*§	—	Form of 2017 Nonqualified Stock Option Agreement among Williams and certain employees and officers.
10.26§	—	The Williams Companies, Inc. 1996 Stock Plan for Nonemployee Directors (filed on March 27, 1996 as Exhibit B to The Williams Companies, Inc.’s Proxy Statement (File No. 002-27038) and incorporated herein by reference).
10.27§	—	The Williams Companies, Inc. 2002 Incentive Plan as amended and restated effective as of January 23, 2004 (filed on August 5, 2004 as Exhibit 10.1 to The Williams Companies, Inc.’s quarterly report on Form 10-Q (File No. 001-04174) and incorporated herein by reference).
10.28§	—	Amendment No. 1 to The Williams Companies, Inc. 2002 Incentive Plan (filed on February 25, 2009 as Exhibit 10.11 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.29§	—	Amendment No. 2 to The Williams Companies, Inc. 2002 Incentive Plan (filed on February 25, 2009 as Exhibit 10.12 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.30§	—	Amended and Restated Change-in-Control Severance Agreement between the Company and certain executive officers (Tier I Executives) (filed on February 27, 2013 as Exhibit 10.14 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.31§	—	Amended and Restated Change-in-Control Severance Agreement between the Company and certain executive officers (Tier II Executives) (filed on February 28, 2012, as Exhibit 10.14 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.32	—	The Williams Companies, Inc. Executive Severance Pay Plan, dated November 14, 2012 (filed July 20, 2016, as Exhibit 10.2 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).

167

Exhibit No.		Description
10.33	—	First Amendment to The Williams Companies Inc. Executive Severance Pay Plan (filed July 20, 2016, as Exhibit 10.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
10.34	—	Separation and Distribution Agreement dated as of December 30, 2011, between The Williams Companies, Inc. and WPX Energy, Inc. (Filed on February 27, 2012 as Exhibit 10.19 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.35	—	Tax Sharing Agreement, dated as of December 30, 2011, between The Williams Companies, Inc. and WPX Energy, Inc. (filed on January 6, 2012 as Exhibit 10.3 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
10.36	—	Letter Agreement, dated January 27, 2014, with James E. Scheel, Senior Vice President - Northeast G&P, regarding Relocation from Pennsylvania Benefits (filed on May 1, 2014 as Exhibit 10.2 to The Williams Companies, Inc.’s quarterly report on Form 10-Q (File No. 001-04174) and incorporated herein by reference).
10.37§	—	The Williams Companies, Inc. 2007 Incentive Plan as amended and restated effective May 22, 2014 (filed April 11, 2014 as Appendix A to The Williams Companies, Inc.’s Definitive Proxy Statement on Schedule 14A (File No. 001-04174) and incorporated herein by reference).
10.38*§	—	The Williams Companies, Inc. 2007 Incentive Plan as amended and restated effective July 14, 2016.
10.39	—	Termination Agreement and Release, dated as of September 28, 2015, by and among The Williams Companies, Inc., SCMS LLC, Williams Partners L.P. and WPZ GP LLC (filed on September 28, 2015 as Exhibit 10.1 to Williams Companies, Inc.’s Current Report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
10.40	—	Second Amended and Restated Credit Agreement dated as of February 2, 2015, between The Williams Companies, Inc., the lenders named therein, and Citibank, N.A. as Administrative Agent (filed on February 3, 2015 as Exhibit 10.1 to The Williams Companies, Inc.’s current report on Form 8-K (File 001-04174) and incorporated herein by reference).
10.41	—	Credit Agreement dated as of August 26, 2015, by and among Williams Partners L.P., the lenders named therein, and Barclays Bank PLC as Administrative Agent (filed on August 28, 2015 as Exhibit 10.1 to Williams Partners L.P.’s Current Report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
10.42	—	Credit Agreement dated as of December 23, 2015, between Williams Partners L.P., the lenders named therein, and Barclays Bank PLC as Administrative Agent (filed on December 23, 2015 as Exhibit 10.2 to Williams Companies, Inc.’s Current Report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
10.43	—	Second Amended and Restated Credit Agreement dated as of February 2, 2015, between Williams Partners L.P. (formerly known as Access Midstream Partners, L.P.), Northwest Pipeline LLC, Transcontinental Gas Pipeline Company, LLC, as co-borrowers, the lenders named therein, and Citibank, N.A. as Administrative Agent (filed on February 3, 2015 as Exhibit 10.1 to Williams Partners L.P.’s Current Report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
10.44	—	Amendment No. 1 to Second Amended and Restated Credit Agreement dated as of December 18, 2015, between Williams Partners L.P., Northwest Pipeline LLC, Transcontinental Gas Pipe Line Company, LLC, as co-borrowers, the lenders named therein, and Citibank, N.A. as Administrative Agent (filed on December 23, 2015 as Exhibit 10.1 to Williams Companies, Inc.’s Current Report on Form 8-K (File No. 001-04174) and incorporated herein by reference).

168

Exhibit No.		Description
10.45	—	Form of Amended and Restated Commercial Paper Dealer Agreement, dated as of February 2, 2015, between Williams Partners L.P., as Issuer, and the Dealer party thereto(filed on February 3, 2015 as Exhibit 10.3 to Williams Partners L.P.’s Current Report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
10.46	—	Registration Rights Agreement, dated January 22, 2016, between Transcontinental Gas Pipe Line Company, LLC and each of the initial purchasers listed therein (filed on January 22, 2016 as Exhibit 10.1 to The Williams Companies, Inc.’s Form 8-K (File No. 001-04174) and incorporated herein by reference).
10.47	—	Common Unit Issuance Agreement, dated January 9, 2017 (filed on January 10, 2017, as Exhibit 2 to Schedule 13D/A (File No. 005-86017) by The Williams Companies, Inc. relating to the common units representing limited partner interests of Williams Partners L.P. and incorporated herein by reference.)
10.48	—	Common Unit Purchase Agreement, dated January 9, 2017 (filed on January 10, 2017, as Exhibit 3 to Schedule 13D/A (File No. 005-86017) by The Williams Companies, Inc. relating to the common units representing limited partner interests of Williams Partners L.P. and incorporated herein by reference.)
12*	—	Computation of Ratio of Earnings to Combined Fixed Charges.
14	—	Code of Ethics for Senior Officers (filed on March 15, 2004 as Exhibit 14 to The Williams Companies, Inc.’s Form 10-K and incorporated herein by reference).
21*	—	Subsidiaries of the registrant.
23.1*	—	Consent of Independent Registered Public Accounting Firm, Ernst & Young LLP.
23.2*	—	Consent of Independent Registered Public Accounting Firm, Deloitte & Touche LLP.
24*	—	Power of Attorney.
31.1*	—	Certification of the Chief Executive Officer pursuant to Rules 13a-l 4(a) and 15d-14(a) promulgated under the Securities Exchange Act of 1934, as amended, and Item 601(b)(3 l) of Regulation S-K, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*	—	Certification of the Chief Financial Officer pursuant to Rules 13a-14(a) and l 5d-l 4(a) promulgated under the Securities Exchange Act of 1934, as amended, and Item 601(b)(31) of Regulation S-K, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32**	—	Certification of the Chief Executive Officer and the Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS*	—	XBRL Instance Document.
101.SCH*	—	XBRL Taxonomy Extension Schema.
101.CAL*	—	XBRL Taxonomy Extension Calculation Linkbase.
101.DEF*	—	XBRL Taxonomy Extension Definition Linkbase.

169

Exhibit No.		Description
101.LAB*	—	XBRL Taxonomy Extension Label Linkbase.
101.PRE*	—	XBRL Taxonomy Extension Presentation Linkbase.

______________
*	Filed herewith
**	Furnished herewith
§	Management contract or compensatory plan or arrangement
+	Pursuant to item 601(6)(2) of Regulation S-K, the registrant agrees to furnish supplementally a copy of any omitted exhibit or schedule to the SEC upon request.

170

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

THE WILLIAMS COMPANIES, INC. (Registrant)
By:	/s/    TED T. TIMMERMANS
	Ted T. Timmermans Vice President, Controller and Chief Accounting Officer

Date: February 22, 2017

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.

Signature	Title	Date
/s/    ALAN S. ARMSTRONG	President, Chief Executive Officer and Director	February 22, 2017
Alan S. Armstrong	(Principal Executive Officer)
/s/    DONALD R. CHAPPEL	Senior Vice President and Chief Financial Officer	February 22, 2017
Donald R. Chappel	(Principal Financial Officer)
/s/    TED T. TIMMERMANS	Vice President, Controller and Chief Accounting Officer	February 22, 2017
Ted T. Timmermans	(Principal Accounting Officer)
/s/    STEPHEN W. BERGSTROM*	Director	February 22, 2017
Stephen W. Bergstrom*
/s/    STEPHEN I. CHAZEN*	Director	February 22, 2017
Stephen I. Chazen*
/s/    CHARLES I. COGUT*	Director	February 22, 2017
Charles I. Cogut*

/s/    KATHLEEN B. COOPER*	Chairman of the Board	February 22, 2017
Kathleen B. Cooper*
/s/    MICHAEL A. CREEL*	Director	February 22, 2017
Michael A. Creel*
/s/    PETER A. RAGAUSS*	Director	February 22, 2017
Peter A. Ragauss*

171

Signature	Title	Date
/s/    SCOTT D. SHEFFIELD*	Director	February 22, 2017
Scott D. Sheffield*
/s/    MURRAY D. SMITH*	Director	February 22, 2017
Murray D. Smith*
/S/    WILLIAM H. SPENCE*	Director	February 22, 2017
William H. Spence
/S/    JANICE D. STONEY*	Director	February 22, 2017
Janice D. Stoney*

*By:	/s/ Sarah C. Miller	February 22, 2017
	Sarah C. Miller           Attorney-in-Fact

172

INDEX TO EXHIBITS

Exhibit No.		Description
2.1+	—	Agreement and Plan of Merger dated as of May 12, 2015, by and among The Williams Companies, Inc., SCMS LLC, Williams Partners L.P., and WPZ GP LLC (filed on May 13, 2015 as Exhibit 2.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
2.2	—	Amendment No 1. to Agreement and Plan of Merger dated as of May 1, 2016, by and among The Williams Companies, Inc., Energy Transfer Corp LP, Energy Transfer Corp GP, LLC, Energy Transfer Equity, L.P., LE GP, LLC and Energy Transfer Equity GP, LLC  (filed on May 3, 2016 as Exhibit 2.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
2.3+	—	Agreement and Plan of Merger dated as of September 28, 2015, by and among The Williams Companies, Inc., Energy Transfer Corp LP, Energy Transfer Corp GP, LLC, Energy Transfer Equity, L.P., LE GP, LLC and Energy Transfer Equity GP, LLC (filed on October 1, 2015 as Exhibit 2.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
2.4	—	Share Purchase Agreement by and between The Williams Companies International Holdings B.V. and Inter Pipeline Ltd. and The Williams Companies, Inc., dated August 8, 2016 (filed on August 12, 2016 as Exhibit 2.1 to The Williams Companies, Inc.’s current report on Form 8-K (file No. 001-04174) and incorporated herein by reference).
2.5	—	Share Purchase Agreement by and between Williams Energy Canada LP and Inter Pipeline Ltd. and Williams Partners L.P., dated August 8, 2016 (filed on August 12, 2016 as Exhibit 2.2 to The Williams Companies, Inc.’s current report on Form 8-K (file No. 001-04174) and incorporated herein by reference).
2.6+	—	Interest Swap and Purchase Agreement by and among Western Gas Partners, LP, WGR Operating, LP, Delaware Basin JV Gathering LLC, Williams Partners L.P., Williams Midstream Gas Services LLC, and Appalachia Midstream Services, L.L.C., dated February 9, 2017 (filed on February 10, 2017 as exhibit 2.1 to The Williams Companies Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
3.1	—	Amended and Restated Certificate of Incorporation, as supplemented (filed on May 26, 2010 as Exhibit 3.1 to The Williams Companies Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
3.2	—	By-Laws (filed on January 20, 2017, as Exhibit 3.1 to The Williams Companies Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
4.1	—	Senior Indenture dated February 25, 1997, between MAPCO Inc. and Bank One Trust Company, N.A. (formerly The First National Bank of Chicago), as Trustee (filed February 25, 1997 as Exhibit 4.5.1 to MAPCO Inc.’s Amendment No. l to registration statement on Form S-3 (File No. 333-20837) and incorporated herein by reference).
4.2	—	Supplemental Indenture No. 1 dated March 5, 1997, between MAPCO Inc. and Bank One Trust Company, N.A. (formerly The First National Bank of Chicago), as Trustee (filed as Exhibit 4(o) to MAPCO Inc.’s annual report on Form 10-K for the fiscal year ended December 31, 1997 (File No. 001-05254) and incorporated herein by reference).
4.3	—	Supplemental Indenture No. 2 dated March 5, 1997, between MAPCO Inc. and Bank One Trust Company, N.A. (formerly The First National Bank of Chicago), as Trustee (filed as Exhibit 4(p) to MAPCO Inc.’s annual report on Form 10-K for the fiscal year ended December 31, 1997 (File No. 001-05254) and incorporated herein by reference).

173

Exhibit No.		Description
4.4	—	Supplemental Indenture No. 3 dated March 31, 1998, among MAPCO Inc., Williams Holdings of Delaware, Inc. and Bank One Trust Company, N.A. (formerly The First National Bank of Chicago), as Trustee (filed as Exhibit 4(J) to Williams Holdings of Delaware, Inc.’s annual report on Form 10­ K for the fiscal year ended December 31, 1998 (File No. 000-20555) and incorporated herein by reference).
4.5	—	Supplemental Indenture No. 4 dated as of July 31, 1999, among Williams Holdings of Delaware, Inc., Williams and Bank One Trust Company, N.A. (formerly The First National Bank of Chicago), as Trustee (filed on March 28, 2000 as Exhibit 4(q) to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
4.6	—	Fifth Supplemental Indenture between Williams and Bank One Trust Company, N.A., as Trustee, dated as of January 17, 2001 (filed on March 12, 2001 as Exhibit 4(k) to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
4.7	—	Seventh Supplemental Indenture dated March 19, 2002, between The Williams Companies, Inc. as Issuer and Bank One Trust Company, National Association, as Trustee (filed on May 9, 2002 as Exhibit 4.1 to The Williams Companies, Inc.’s quarterly report on Form 10-Q (File No. 001-04174) and incorporated herein by reference).
4.8	—	Indenture dated as of May 28, 2003, by and between The Williams Companies, Inc. and JPMorgan Chase Bank, as Trustee for the issuance of the 5.50% Junior Subordinated Convertible Debentures due 2033 (filed on August 12, 2003 as Exhibit 4.2 to The Williams Companies, Inc.’s quarterly report on Form 10-Q (File No. 001-04174) and incorporated herein by reference).
4.9	—	Indenture dated as of March 5, 2009, among The Williams Companies, Inc. and The Bank of New York Mellon Trust Company, N.A., as Trustee (filed on March 11, 2009 as Exhibit 4.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
4.10	—	Eleventh Supplemental Indenture dated as of February 1, 2010 between The Williams Companies, Inc. and The Bank of New York Mellon Trust Company, N.A. (filed on February 2, 2010 as Exhibit 4.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
4.11	—	First Supplemental Indenture dated as of February 1, 2010 between The Williams Companies, Inc. and The Bank of New York Mellon Trust Company, N.A. (filed on February 2, 2010 as Exhibit 4.2 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
4.12	—	Fifth Supplemental Indenture dated as of February 1, 2010 between The Williams Companies, Inc. and The Bank of New York Mellon Trust Company, N.A. (filed on February 2, 2010 as Exhibit 4.3 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
4.13	—	Indenture, dated December 18, 2012 between The Williams Companies, Inc. and The Bank of New York Mellon Trust Company, N.A. as trustee (filed on December 20, 2012 as Exhibit 4.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
4.14	—	First Supplemental Indenture, dated December 18, 2012, between The Williams Companies, Inc. and The Bank of New York Mellon Trust Company, N.A. as trustee (filed on December 20, 2012 as Exhibit 4.2 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).

174

Exhibit No.		Description
4.15	—	Second Supplemental Indenture, dated as of June 24, 2014, between The Williams Companies, Inc. and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on June 24, 2014 as Exhibit 4.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
4.16	—	Indenture, dated December 13, 2006, by and among Williams Partners L.P., Williams Partners Finance Corporation and The Bank of New York (filed on December 19, 2006 as Exhibit 4.1 to Pre-merger WPZ’s report on Form 8-K (File No. 001-32599) and incorporated herein by reference).
4.17	—	First Supplemental Indenture, dated as of February 2, 2015, among Williams Partners L.P., Williams Partners Finance Corporation and The Bank of New York Mellon Trust Company, N.A. (filed on February 3, 2015, as Exhibit 4.6 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
4.18	—	Indenture dated as of February 9, 2010, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A. (filed on February 10, 2010 as Exhibit 4.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
4.19	—	First Supplemental Indenture, dated as of February 2, 2015, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A. (filed on February 3, 2015, as Exhibit 4.5 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
4.20	—	Indenture, dated as of November 9, 2010, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on November 12, 2010 as Exhibit 4.1 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-32599) and incorporated herein by reference).
4.21	—	First Supplemental Indenture, dated as of November 9, 2010, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on November 12, 2010 as Exhibit 4.2 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-32599) and incorporated herein by reference).
4.22	—	Second Supplemental Indenture, dated as of November 17, 2011, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A., as trustee (filed November 18, 2011 as Exhibit 4.1 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-32599) and incorporated herein by reference).
4.23	—	Third Supplemental Indenture (including Form of 3.35% Senior Notes due 2022), dated as of August 14, 2012, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on August 14, 2012 as Exhibit 4.1 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-32599) and incorporated herein by reference).
4.24	—	Fourth Supplemental Indenture, dated as of November 15, 2013, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N .A., as trustee (filed on November 18, 2013 as Exhibit 4.1 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-32599) and incorporated herein by reference).
4.25	—	Fifth Supplemental Indenture, dated as of March 4, 2014, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on March 4, 2014 as Exhibit 4.1 to Williams Partners L.P.’s report on Form 8-K (File No. 001-32599) and incorporated herein by reference).
4.26	—	Sixth Supplemental Indenture, dated as of June 27, 2014, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on June 27, 2014 as Exhibit 4.1 to Williams Partners L.P.’s report on Form 8-K (File No. 001-32599) and incorporated herein by reference).

175

Exhibit No.		Description
4.27	—	Seventh Supplemental Indenture, dated as of February 2, 2015, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A. (filed on February 3, 2015, as Exhibit 4.4 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
4.28	—	Eighth Supplemental Indenture, dated as of March 3, 2015, between Williams Partners L.P. and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on March 3, 2015 as Exhibit 4.1 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
4.29	—	Indenture, dated as of January 11, 2012, by and among the Chesapeake Midstream Partners, L.P., CHKM Finance Corp, the Guarantors named therein and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on January 11, 2012 as Exhibit 4.1 to Williams Partners L.P.’s (then known as Access Midstream Partners L.P.) current report on 8-K (File No. 001-34831) and incorporated herein by reference).
4.30	—	First Supplemental Indenture, dated as of January 7, 2013, by and among Access Midstream Partners, L.P., ACMP Finance Corp., the guarantors named therein and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on February 21, 2014 as Exhibit 4.5 to Williams Partners L.P.’s (then known as Access Midstream Partners L.P.) annual report on 10-K (File No. 001-34831) and incorporated herein by reference).
4.31	—	Second Supplemental Indenture and Amendment - Subsidiary Guarantee, dated as of April 18, 2014 among the Access Midstream Partners, L.P., ACMP Finance Corp, the Guarantors named therein and The Bank of New York Mellon Trust Company, N.A., as trustee filed on May 1, 2014 as Exhibit 4.4 to Williams Partners L.P.’s (then known as Access Midstream Partners L.P.) quarterly report on 10-Q (File No. 001-34831) and incorporated herein by reference).
4.32	—	Third Supplemental Indenture among Williams Partners L.P., ACMP Finance Corp. and The Bank of New York Mellon Trust Company, N.A. (filed on February 3, 2015, as Exhibit 4.2 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
4.33	—	Indenture, dated as of December 19, 2012, by and among Access Midstream Partners, L.P., ACMP Finance Corp., the guarantors listed therein and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on December 19, 2012 as Exhibit 4.1 to Williams Partners L.P.’s (formerly known as Access Midstream Partners L.P.) current report on 8-K (File No. 001-34831) and incorporated herein by reference).
4.34	—	First Supplemental Indenture, dated as of December 19, 2012, among Access Midstream Partners, L.P., ACMP Finance Corp., the guarantors listed therein and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on December 19, 2012 as Exhibit 4.2 to Williams Partners L.P.’s (formerly known as Access Midstream Partners L.P.) current report on 8-K (File No. 001-34831) and incorporated herein by reference).
4.35	—	Second Supplemental Indenture and Amendment - Subsidiary Guarantee, dated as of January 7, 2013, by among Access Midstream Partners, L.P., ACMP Finance Corp., the guarantors named therein and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on February 21, 2014 as Exhibit 4.9 to Williams Partners L.P.’s (formerly known as Access Midstream Partners L.P.) annual report on 10-K (File No. 001-34831) and incorporated herein by reference).
4.36	—	Third Supplemental Indenture, dated as of March 7, 2014, among the Access Midstream Partners, L.P., ACMP Finance Corp, the Guarantors named therein and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on March 7, 2014 as Exhibit 4.2 to Williams Partners L.P.’s (formerly known as Access Midstream Partners L.P.) current report on 8-K (File No. 001-34831) and incorporated herein by reference).

176

Exhibit No.		Description
4.37	—	Third Supplemental Indenture and Amendment - Subsidiary Guarantee, dated as of April 18, 2014, among the Access Midstream Partners, L.P., ACMP Finance Corp, the Guarantors named therein and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on May 1, 2014 as Exhibit 4.3 to Williams Partners L.P.’s (formerly known as Access Midstream Partners L.P.) quarterly report on 10-Q (File No. 001-34831) and incorporated herein by reference).
4.38	—	Fifth Supplemental Indenture dated as of February 2, 2015 among Williams Partners L.P., ACMP Finance Corp. and The Bank of New York Mellon Trust Company, N.A. (filed on February 3, 2015, as Exhibit 4.3 to Williams Partners L.P.’s current report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
4.39	—	Senior Indenture dated as of November 30, 1995, between Northwest Pipeline Corporation and Chemical Bank, Trustee (filed September 14, 1995 as Exhibit 4.1 to Northwest Pipeline’s registration statement on Form S-3 (File No. 033-62639) and incorporated herein by reference).
4.40	—	Indenture dated as of June 22, 2006, between Northwest Pipeline Corporation and JPMorgan Chase Bank, N.A., as Trustee (filed on June 23, 2006 as Exhibit 4.1 to Northwest Pipeline’s current report on Form 8-K (File No. 001-07414) and incorporated herein by reference).
4.41	—	Indenture dated as of April 5, 2007, between Northwest Pipeline Corporation and The Bank of New York (filed on April 5, 2007 as Exhibit 4.1 to Northwest Pipeline Corporation’s current report on Form 8-K (File No. 001-07414) and incorporated herein by reference).
4.42	—	Indenture dated May 22, 2008, between Northwest Pipeline GP and The Bank of New York Trust Company, N.A., as Trustee (filed on May 23, 2008 as Exhibit 4.1 to Northwest Pipeline GP’s current report on Form 8-K (File No. 001-07414) and incorporated herein by reference).
4.43	—	Senior Indenture dated as of July 15, 1996 between Transcontinental Gas Pipe Line Corporation and Citibank, N.A., as Trustee (filed on April 2, 1996 as Exhibit 4.1 to Transcontinental Gas Pipe Line Corporation’s registration statement on Form S-3 (File No. 333-02155) and incorporated herein by reference).
4.44	—	Indenture dated as of April 11, 2006 between Transcontinental Gas Pipe Line Corporation and JPMorgan Chase Bank, N.A., as Trustee (filed on April 11, 2006 as Exhibit 4.1 to Transcontinental Gas Pipe Line Corporation’s current report on Form 8-K (File No. 001-07584) and incorporated herein by reference).
4.45	—	Indenture dated May 22, 2008, between Transcontinental Gas Pipe Line Corporation and The Bank of New York Trust Company, N.A., as Trustee (filed on May 23, 2008 as Exhibit 4.1 to Transcontinental Gas Pipe Line Corporation’s current report on Form 8-K (File No. 001-07584) and incorporated herein by reference).
4.46	—	Indenture dated as of August 12, 2011, between Transcontinental Gas Pipe Line Company, LLC and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on August 12, 2011 as Exhibit 4.1 to Transcontinental Gas Pipe Line Company, LLC’s current report on Form 8K (File No. 001-07584) and incorporated herein by reference).
4.47	—	Indenture, dated as of July 13, 2012, between Transcontinental Gas Pipe Line Company, LLC and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on July 16, 2012 as Exhibit 4.1 to Transcontinental Gas Pipe Line Company, LLC’s current report on Form 8-K (File No. 001-07584) and incorporated herein by reference).
4.48	—	Indenture, dated as of January 22, 2016, between Transcontinental Gas Pipe Line Company, LLC and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on January 22, 2016 as Exhibit 4.1 to The Williams Company, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).

177

Exhibit No.		Description
10.1§	—	The Williams Companies Amended and Restated Retirement Restoration Plan effective January l, 2008 (filed on February 25, 2009 as Exhibit 10.1 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.2§	—	Form of Director and Officer Indemnification Agreement (filed on September 24, 2008 as Exhibit 10.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
10.3§	—	Form of 2013 Performance-Based Restricted Stock Unit Agreement among Williams and certain employees and officers (filed on February 27, 2013 as Exhibit 10.4 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.4§	—	Form of 2013 Restricted Stock Unit Agreement among Williams and certain employees and officers (filed on February 27, 2013 as Exhibit 10.5 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.5§	—	Form of 2013 Nonqualified Stock Option Agreement among Williams and certain employees and officers (filed on February 27, 2013 as Exhibit 10.6 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.6§	—	Form of 2013 Restricted Stock Unit Agreement among Williams and certain nonmanagement directors (filed on February 26, 2014 as Exhibit 10.11 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.7§	—	Form of 2014 Performance-Based Restricted Stock Unit Agreement among Williams and certain employees and officers (filed on February 26, 2014 as Exhibit 10.6 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.8§	—	Form of 2014 Restricted Stock Unit Agreement among Williams and certain employees and officers (filed on February 26, 2014 as Exhibit 10.7 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.9§	—	Form of 2014 Nonqualified Stock Option Agreement among Williams and certain employees and officers (filed on February 26, 2014 as Exhibit 10.8 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.10§	—	Form of 2014 Restricted Stock Unit Agreement among Williams and certain nonmanagement directors (filed on February 25, 2015 as Exhibit 10.12 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.11§	—	Form of October 2014 Leveraged Performance Unit Award Agreement among Williams and certain officers (filed on February 25, 2015 as Exhibit 10.13 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.12§	—	Form of Leveraged Performance Unit Award Agreement dated January 1, 2015 between Williams and Walter Bennett (filed on February 25, 2015 as Exhibit 10.14 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.13§	—	Form of 2015 Performance-Based Restricted Stock Unit Agreement among Williams and certain employees and officers (filed on February 25, 2015 as Exhibit 10.15 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.14§	—	Form of 2015 Time-Based Restricted Stock Unit Agreement among Williams and certain employees and officers (filed on February 25, 2015 as Exhibit 10.16 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).

178

Exhibit No.		Description
10.15§	—	Form of 2015 Nonqualified Stock Option Agreement among Williams and certain employees and officers (filed on February 25, 2015 as Exhibit 10.17 to The Williams Companies, Inc. annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.16§	—	Form of 2015 Short-Term Non-Equity Incentive Award Agreement among The Williams Companies Inc. and certain employees and officers (filed on October 29, 2015 as Exhibit 10.2 to The Williams Companies, Inc. quarterly report on Form 10-Q (File No. 001-04174) and incorporated herein by reference).
10.17§	—	Form of 2015 Non-Equity Incentive Award Agreement among The Williams Companies Inc. and certain employees and officers (filed on October 29, 2015 as Exhibit 10.3 to The Williams Companies, Inc. quarterly report on Form 10-Q (File No. 001-04174) and incorporated herein by reference).
10.18*§	—	Form of 2016 Performance-Based Restricted Stock Unit Agreement among Williams and certain employees and officers.
10.19*§	—	Form of 2016 Time-Based Restricted Stock Unit Agreement among Williams and certain employees and officers.
10.20*§	—	Form of 2016 Time-Based Restricted Stock Unit Agreement among Williams and certain employees and officers vesting February 22, 2019.
10.21*§	—	Form of 2016 Time-Based Restricted Stock Unit Agreement among Williams and certain non-management directors.
10.22*§	—	Form of 2016 Nonqualified Stock Option Agreement among Williams and certain employees and officers.
10.23*§	—	Form of 2017 Time-Based Restricted Stock Unit Agreement among Williams and certain employees and officers.
10.24*§	—	Form of 2017 Time-Based Restricted Stock Unit Agreement among Williams and certain non-management directors.
10.25*§	—	Form of 2017 Nonqualified Stock Option Agreement among Williams and certain employees and officers.
10.26§	—	The Williams Companies, Inc. 1996 Stock Plan for Nonemployee Directors (filed on March 27, 1996 as Exhibit B to The Williams Companies, Inc.’s Proxy Statement (File No. 002-27038) and incorporated herein by reference).
10.27§	—	The Williams Companies, Inc. 2002 Incentive Plan as amended and restated effective as of January 23, 2004 (filed on August 5, 2004 as Exhibit 10.1 to The Williams Companies, Inc.’s quarterly report on Form 10-Q (File No. 001-04174) and incorporated herein by reference).
10.28§	—	Amendment No. 1 to The Williams Companies, Inc. 2002 Incentive Plan (filed on February 25, 2009 as Exhibit 10.11 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.29§	—	Amendment No. 2 to The Williams Companies, Inc. 2002 Incentive Plan (filed on February 25, 2009 as Exhibit 10.12 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).

179

Exhibit No.		Description
10.30§	—	Amended and Restated Change-in-Control Severance Agreement between the Company and certain executive officers (Tier I Executives) (filed on February 27, 2013 as Exhibit 10.14 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.31§	—	Amended and Restated Change-in-Control Severance Agreement between the Company and certain executive officers (Tier II Executives) (filed on February 28, 2012, as Exhibit 10.14 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.32	—	The Williams Companies, Inc. Executive Severance Pay Plan, dated November 14, 2012 (filed July 20, 2016, as Exhibit 10.2 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
10.33	—	First Amendment to The Williams Companies Inc. Executive Severance Pay Plan (filed July 20, 2016, as Exhibit 10.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
10.34	—	Separation and Distribution Agreement dated as of December 30, 2011, between The Williams Companies, Inc. and WPX Energy, Inc. (Filed on February 27, 2012 as Exhibit 10.19 to The Williams Companies, Inc.’s annual report on Form 10-K (File No. 001-04174) and incorporated herein by reference).
10.35	—	Tax Sharing Agreement, dated as of December 30, 2011, between The Williams Companies, Inc. and WPX Energy, Inc. (filed on January 6, 2012 as Exhibit 10.3 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
10.36	—	Letter Agreement, dated January 27, 2014, with James E. Scheel, Senior Vice President - Northeast G&P, regarding Relocation from Pennsylvania Benefits (filed on May 1, 2014 as Exhibit 10.2 to The Williams Companies, Inc.’s quarterly report on Form 10-Q (File No. 001-04174) and incorporated herein by reference).
10.37§	—	The Williams Companies, Inc. 2007 Incentive Plan as amended and restated effective May 22, 2014 (filed April 11, 2014 as Appendix A to The Williams Companies, Inc.’s Definitive Proxy Statement on Schedule 14A (File No. 001-04174) and incorporated herein by reference).
10.38*§	—	The Williams Companies, Inc. 2007 Incentive Plan as amended and restated effective July 14, 2016.
10.39	—	Termination Agreement and Release, dated as of September 28, 2015, by and among The Williams Companies, Inc., SCMS LLC, Williams Partners L.P. and WPZ GP LLC (filed on September 28, 2015 as Exhibit 10.1 to Williams Companies, Inc.’s Current Report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
10.40	—	Second Amended and Restated Credit Agreement dated as of February 2, 2015, between The Williams Companies, Inc., the lenders named therein, and Citibank, N.A. as Administrative Agent (filed on February 3, 2015 as Exhibit 10.1 to The Williams Companies, Inc.’s current report on Form 8-K (File 001-04174) and incorporated herein by reference).
10.41	—	Credit Agreement dated as of August 26, 2015, by and among Williams Partners L.P., the lenders named therein, and Barclays Bank PLC as Administrative Agent (filed on August 28, 2015 as Exhibit 10.1 to Williams Partners L.P.’s Current Report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
10.42	—	Credit Agreement dated as of December 23, 2015, between Williams Partners L.P., the lenders named therein, and Barclays Bank PLC as Administrative Agent (filed on December 23, 2015 as Exhibit 10.2 to Williams Companies, Inc.’s Current Report on Form 8-K (File No. 001-04174) and incorporated herein by reference).

180

Exhibit No.		Description
10.43	—	Second Amended and Restated Credit Agreement dated as of February 2, 2015, between Williams Partners L.P. (formerly known as Access Midstream Partners, L.P.), Northwest Pipeline LLC, Transcontinental Gas Pipeline Company, LLC, as co-borrowers, the lenders named therein, and Citibank, N.A. as Administrative Agent (filed on February 3, 2015 as Exhibit 10.1 to Williams Partners L.P.’s Current Report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
10.44	—	Amendment No. 1 to Second Amended and Restated Credit Agreement dated as of December 18, 2015, between Williams Partners L.P., Northwest Pipeline LLC, Transcontinental Gas Pipe Line Company, LLC, as co-borrowers, the lenders named therein, and Citibank, N.A. as Administrative Agent (filed on December 23, 2015 as Exhibit 10.1 to Williams Companies, Inc.’s Current Report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
10.45	—	Form of Amended and Restated Commercial Paper Dealer Agreement, dated as of February 2, 2015, between Williams Partners L.P., as Issuer, and the Dealer party thereto(filed on February 3, 2015 as Exhibit 10.3 to Williams Partners L.P.’s Current Report on Form 8-K (File No. 001-34831) and incorporated herein by reference).
10.46	—	Registration Rights Agreement, dated January 22, 2016, between Transcontinental Gas Pipe Line Company, LLC and each of the initial purchasers listed therein (filed on January 22, 2016 as Exhibit 10.1 to The Williams Companies, Inc.’s Form 8-K (File No. 001-04174) and incorporated herein by reference).
10.47	—	Common Unit Issuance Agreement, dated January 9, 2017 (filed on January 10, 2017, as Exhibit 2 to Schedule 13D/A (File No. 005-86017) by The Williams Companies, Inc. relating to the common units representing limited partner interests of Williams Partners L.P. and incorporated herein by reference.)
10.48	—	Common Unit Purchase Agreement, dated January 9, 2017 (filed on January 10, 2017, as Exhibit 3 to Schedule 13D/A (File No. 005-86017) by The Williams Companies, Inc. relating to the common units representing limited partner interests of Williams Partners L.P. and incorporated herein by reference.)
12*	—	Computation of Ratio of Earnings to Combined Fixed Charges.
14	—	Code of Ethics for Senior Officers (filed on March 15, 2004 as Exhibit 14 to The Williams Companies, Inc.’s Form 10-K and incorporated herein by reference).
21*	—	Subsidiaries of the registrant.
23.1*	—	Consent of Independent Registered Public Accounting Firm, Ernst & Young LLP.
23.2*	—	Consent of Independent Registered Public Accounting Firm, Deloitte & Touche LLP.
24*	—	Power of Attorney.
31.1*	—	Certification of the Chief Executive Officer pursuant to Rules 13a-l 4(a) and 15d-14(a) promulgated under the Securities Exchange Act of 1934, as amended, and Item 601(b)(3 l) of Regulation S-K, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*	—	Certification of the Chief Financial Officer pursuant to Rules 13a-14(a) and l 5d-l 4(a) promulgated under the Securities Exchange Act of 1934, as amended, and Item 601(b)(31) of Regulation S-K, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

181

Exhibit No.		Description
32**	—	Certification of the Chief Executive Officer and the Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS*	—	XBRL Instance Document.
101.SCH*	—	XBRL Taxonomy Extension Schema.
101.CAL*	—	XBRL Taxonomy Extension Calculation Linkbase.
101.DEF*	—	XBRL Taxonomy Extension Definition Linkbase.
101.LAB*	—	XBRL Taxonomy Extension Label Linkbase.
101.PRE*	—	XBRL Taxonomy Extension Presentation Linkbase.

______________
*	Filed herewith
**	Furnished herewith
§	Management contract or compensatory plan or arrangement
+	Pursuant to item 601(6)(2) of Regulation S-K, the registrant agrees to furnish supplementally a copy of any omitted exhibit or schedule to the SEC upon request.

182

EX-10.18

Exhibit 10.18

Date=Grant Date

TO:        <@Name@>

FROM:    Alan S. Armstrong

SUBJECT:    2016 Performance-Based Restricted Stock Unit Award

You have been selected to receive a performance-based restricted stock unit award to be paid if the Company exceeds the Threshold goal for Total Shareholder Return, as established by the Committee, over the Performance Period. This award is subject to the terms and conditions of The Williams Companies, Inc. 2007 Incentive Plan, as amended and restated from time to time, and the 2016 Performance-Based Restricted Stock Unit Agreement (the “Agreement”).

This award is granted to you in recognition of your role as an employee whose responsibilities and performance are critical to the attainment of long-term goals. This award and similar awards are made on a selective basis and are, therefore, to be kept confidential.

Subject to all of the terms of the Agreement, you will generally become entitled to payment of the award if you are an active employee of the Company on February 22, 2019 and if performance measures set forth in the Agreement are certified for the Performance Period beginning August 1, 2016. The adjustment and termination provisions associated with this award are included in the Agreement.

If you have any questions about this award, you may contact a dedicated Fidelity Stock Plan Representative at 1-800-544-9354.

1

2016 PERFORMANCE-BASED RESTRICTED STOCK UNIT AGREEMENT

THIS 2016 PERFORMANCE-BASED RESTRICTED STOCK UNIT AGREEMENT (this “Agreement”), which contains the terms and conditions for the restricted stock units (“Restricted Stock Units” or “RSUs”) referred to in the 2016 Performance-Based Restricted Stock Unit Award Letter delivered in hard copy or electronically to the Participant (“2016 Award Letter”), is by and between THE WILLIAMS COMPANIES, INC., a Delaware corporation (the “Company”), and the individual identified on the last page hereof (the “Participant”).

1.    Grant of RSUs. Subject to the terms and conditions of The Williams Companies, Inc. 2007 Incentive Plan, as amended and restated from time to time (the “Plan”), this Agreement, and the 2016 Award Letter, the Company hereby grants to the Participant an award (the “Award) of <@Num+C @> RSUs effective <@GrDt+C@> (the “Effective Date”). The Award, which is subject to adjustment under the terms of this Agreement, gives the Participant the opportunity to earn the right to receive the number ofshares of the Common Stock of the Company equal to the number of RSUs shown in the prior sentence if the Target goal, as established by the Committee, is achieved by the Company over the Performance Period. These shares, together with any other shares that are payable under this Agreement, are referred to in the Agreement as “Shares.” Until the Participant both becomes vested in the Shares under the terms of Paragraph 5 and is paid such Shares under the terms of Paragraph 6, the Participant shall have no rights as a stockholder of the Company with respect to the Shares.

2.    Incorporation of Plan and Acceptance of Documents. The Plan is hereby incorporated herein by reference, and all capitalized terms used herein which are not defined in this Agreement shall have the meaning set forth in the Plan. The Participant acknowledges that he or she has received a copy of, or has online access to, the Plan, and hereby automatically accepts the RSUs subject to all the terms and provisions of the Plan and this Agreement. The Participant hereby further agrees that he or she has received a copy of, or has online access to, the Plan prospectus, as updated from time to time, and hereby acknowledges his or her automatic acceptance and receipt of such prospectus electronically.

3.    Committee Decisions and Interpretations; Committee Discretion. The Participant hereby agrees to accept as binding, conclusive and final all actions, decisions and/or interpretations of the Committee, its delegates, or agents, upon any questions or other matters arising under the Plan or this Agreement.

4.    Performance Measures; Number of Shares Payable to the Participant.

(a)    Performance measures established by the Committee shall be based on targeted levels of both absolute and relative Total Shareholder Return. The Committee establishes (i) “Threshold,” “Target” and “Stretch” goals for Total Shareholder Return (both for absolute and relative Total Shareholder Return) during the Performance Period and (ii) the designated numbers of Shares that may be received by a Participant based upon the achievement of each such goal during the Performance Period, all as more fully described in Subparagraphs 4(b) through 4(c) below. The number of Shares that may be received by the Participant if the Target goal is reached is equal to the number of RSUs set forth in Paragraph 1 above.

(b)    The RSUs awarded to Participant and subject to this Agreement as reflected in Paragraph 1 above represent Participant’s opportunity to earn the right to payment of an equal number of Shares (“Target Number of Shares”) upon (i) certification by the Committee that 100% of the Target goal for Total Shareholder Return for the Performance Period has been met and (ii) satisfaction of all the other conditions set forth in Paragraph 5 below.

(c)    Subject to the Committee’s discretion as set forth in Subparagraph 4(d) below and to satisfaction of all other conditions set forth in Paragraph 5 below, the actual number of Shares earned by and payable to Participant upon certification of Total Shareholder Return results and satisfaction of all other conditions set forth in Paragraph 5 below will be determined on a continuum ranging from 0% (at the Threshold goal) to 200% (at the Stretch goal) of the Target Number of Shares depending on the level of Total Shareholder Return certified by the Committee at the end of the Performance Period.

2

(d)    Notwithstanding (i) any other provision of this Agreement or the Plan or (ii) certification by the Committee that targets for Total Shareholder Return above the Threshold goal have been achieved during the Performance Period, the Committee may in its sole and absolute discretion reduce, but not below zero (0), the number of Shares payable to the Participant based on such factors as it deems appropriate, including but not limited to the Company’s performance. Accordingly, any reference in this Agreement to Shares that (i) become payable, (ii) may be received by a Participant or (iii) are earned by a Participant, and any similar reference, shall be understood to mean the number of Shares that are received, payable or earned after any such reduction is made.

5.     Vesting; Legally Binding Rights.

(a)    Notwithstanding any other provision of this Agreement, a Participant shall not be entitled to any payment of Shares under this Agreement unless and until such Participant obtains a legally binding right to such Shares and satisfies applicable vesting conditions for such payment.

(b)    Except as otherwise provided in Subparagraphs 5(c) – 5(h) below and subject to the provisions of Subparagraph 4(d) above, the Participant shall vest in Shares under this Agreement only if and at the time that both of the following conditions are fully satisfied:

(i)    The Participant remains an active employee of the Company or any of its Affiliates on February 22, 2019 (the “Maturity Date”); and

(ii)    The Committee certifies that the Company has met Total Shareholder Return targets above the Threshold goal as defined by the Committee for the performance period beginning August 1, 2016 and ending December 31, 2018 (the “Performance Period”). Certification, if any, by the Committee for the Performance Period shall be made by the Maturity Date or as soon thereafter as is administratively practicable.

(c)    If a Participant dies, becomes Disabled (as defined below) or qualifies for Retirement (as defined below) prior to the Maturity Date while an active employee of the Company or any of its Affiliates, at but not prior to the Maturity Date, and only to the extent and at the time that the Committee certifies that the performance measures for the Performance Period are satisfied under Subparagraph 5(b)(ii) above, upon such certification, the Participant shall vest in that number of Shares the Participant might otherwise have received for the Performance Period in accordance with Subparagraphs 4(a) through 4(d) above prorated to reflect that portion of the Performance Period prior to such Participant’s ceasing to be an active employee of the Company and its Affiliates. The pro rata number of Shares in which the Participant may become vested in such case shall equal that number determined by multiplying (i) the number of Shares the Participant might otherwise have received for the Performance Period in accordance with Subparagraphs 4(a) to 4(d) above times (ii) a fraction, the numerator of which is the number of full and partial months in the period that begins the month following the month that contains the Effective Date and ends on (and includes) the date the Participant ceases being an active employee of the Company and its Affiliates, and the denominator of which is the total number of full and partial months in the period that begins the month following the month that contains the Effective Date and ends on (and includes) the Maturity Date.

(d)    As used in this Agreement, the terms “Disabled,” “qualify for Retirement,” “Separation from Service” and “Affiliate” shall have the following respective meanings:

(i)    A Participant shall be considered Disabled if such Participant (A) is unable to engage in any substantial gainful activity by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than twelve (12) months, or (B) is, by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than twelve (12) months, receiving income replacement benefits for a period of not less than three (3) months under an accident and health plan covering employees of the Participant’s employer. Notwithstanding the forgoing, all determinations of whether a Participant is Disabled shall

3

be made in accordance with Section 409A of the Internal Revenue Code of 1986, as amended (the “Code”), and guidance thereunder.

(ii)    A Participant “qualifies for Retirement” only if such Participant experiences a Separation from Service (as defined in (iii) below) after attaining age fifty-five (55) and completing at least three (3) years of service with the Company or any of its Affiliates.

(iii)     “Separation from Service” means a Participant’s termination or deemed termination from employment with the Company and its Affiliates (as defined in (iv) below). For purposes of determining whether a Separation from Service has occurred, the employment relationship is treated as continuing intact while the Participant is on military leave, sick leave or other bona fide leave of absence if the period of such leave does not exceed six (6) months, or if longer, so long as the Participant retains a right to reemployment with his or her employer under an applicable statute or by contract. For this purpose, a leave of absence constitutes a bona fide leave of absence only if there is a reasonable expectation that the Participant will return to perform services for his or her employer. If the period of leave exceeds six (6) months and the Participant does not retain a right to reemployment under an applicable statute or by contract, the employment relationship will be deemed to terminate on the first date immediately following such six (6) month period. Notwithstanding the foregoing, if a leave of absence is due to any medically determinable physical or mental impairment that can be expected to result in death or can be expected to last for a continuous period of not less than six (6) months, and such impairment causes the Participant to be unable to perform the duties of the Participant’s position of employment or any substantially similar position of employment, a twenty-nine (29) month period of absence shall be substituted for such six (6) month period. For purposes of this Agreement, a Separation from Service occurs at the date as of which the facts and circumstances indicate either that, after such date: (A) the Participant and the Company reasonably anticipate the Participant will perform no further services for the Company and its Affiliates (whether as an employee or an independent contractor) or (B) that the level of bona fide services the Participant will perform for the Company and its Affiliates (whether as an employee or independent contractor) will permanently decrease to no more than twenty (20%) of the average level of bona fide services performed over the immediately preceding thirty-six (36) month period or, if the Participant has been providing services to the Company and its Affiliates for less than thirty-six (36) months, the full period over which the Participant has rendered services, whether as an employee or independent contractor. The determination of whether a Separation from Service has occurred shall be governed by the provisions of Treasury Regulation § 1.409A-1, as amended, taking into account the objective facts and circumstances with respect to the level of bona fide services performed by the Participant after a certain date.

(iv)     As used in this Agreement, “Affiliate” means all persons with whom the Company would be considered a single employer under Section 414(b) of the Code, and all persons with whom such person would be considered a single employer under Section 414(c) of the Code.

(e)    If a Participant experiences a Separation from Service prior to the Maturity Date and within two years following a Change in Control, either voluntarily for Good Reason or involuntarily (other than due to Cause), the Participant shall vest in that number of Shares equal to the number of Shares that might otherwise be received by the Participant upon achievement of the Target goal.

(f)    If the Participant experiences an involuntary Separation from Service prior to the Maturity Date and the Participant either receives benefits under a severance pay plan or program maintained by the Company or receives benefits under a separation agreement with the Company, at but not prior to the Maturity Date and only to the extent the Committee certifies that the performance measures for the Performance Period are satisfied under Subparagraph 5(b)(ii) above, the Participant shall, on the date of such certification, become vested in that number of Shares the Participant might otherwise have received for the Performance Period in accordance with Paragraph 4 above pro rated to reflect that portion of the Performance Period prior to the Participant’s ceasing to be an active employee of the Company and its Affiliates. The pro rata number of Shares which may be payable to the Participant on but not prior to the Maturity Date in such case shall equal that

4

number determined by multiplying (i) the number of Shares the Participant might otherwise have received for the Performance Period in accordance with Paragraph 4 above times (ii) a fraction, the numerator of which is the number of full and partial months in the period that begins the month following the month that includes the Effective Date and ends on (and includes) the date the Participant ceases being an active employee of the Company and its Affiliates, and the denominator of which is the number of full and partial months in the period that begins the month following the month that contains the Effective Date and ends on (and includes) the Maturity Date.

(g)    If (i) the Participant experiences an involuntary Separation from Service prior to the Maturity Date due to a sale of a business or the outsourcing of any portion of a business, and (ii) the Company or any of its Affiliates fails to make an offer of comparable employment, as defined in a severance plan or program maintained by the Company, to the Participant, then at the time and to the extent the Committee certifies that the performance measures for the Performance Period are satisfied under Subparagraph 5(b)(ii) above, upon such certification, the Participant shall become vested in that number of Shares the Participant might otherwise have received for the Performance Period in accordance with Paragraph 4 above pro rated to reflect that portion of the Performance Period prior to the Participant’s ceasing to be an active employee of the Company and its Affiliates. The pro rata number of Shares in which the Participant may become vested on, but not prior to, the Maturity Date in such case shall equal that number of Shares determined by multiplying (i) the number of Shares the Participant might otherwise have received for the Performance Period in accordance with Paragraph 4 above times (ii) a fraction, the numerator of which is the number of full and partial months in the period that begins the month following the month that contains the Effective Date and ends on (and includes) the date the Participant ceases being an active employee of the Company and its Affiliates, and the denominator of which is the total number of full and partial months in the period that begins the month following the month that contains the Effective Date and ends on (and includes) the Maturity Date. For purposes of this Subparagraph 5(g), a Termination of Affiliation shall constitute an involuntary Separation from Service.

(h)    If in the event of a Change in Control, the acquiring or surviving company does not assume or continue this Award or does not provide equivalent awards of substantially the same value, the Participant shall, immediately prior to the Change in Control, vest in that number of Shares equal to the number of Shares that might otherwise be received by the Participant upon achievement of the Target goal.

6.    Payment of Shares.

(a) (i) The payment date for all Shares in which a Participant becomes vested pursuant to Subparagraph 5(e) above shall be no more than thirty (30) days after such Participant’s Separation from Service. If such 30-day period spans two calendar years, then payment will be made in the later calendar year. However, if the Participant was a “key employee” within the meaning of Section 409A(a)(B)(i) of the Code immediately prior to his or her Separation from Service, payment shall not be made sooner than the earlier to occur of the following: (i) six (6) months following the date of such Separation from Service; and (ii) the Participant’s death.

(ii) For purposes of this Subparagraph 6(a), “key employee” means an employee designated on an annual basis by the Company as of December 31 (the “Key Employee Designation Date”) as an employee meeting the requirements of Section 416(i) of the Code utilizing the definition of compensation under Treasury Regulation § 1.415(c)-2(d)(2). A Participant designated as a “key employee” shall be a “key employee” for the entire twelve (12) month period beginning on April 1 following the Key Employee Designation Date.

(b)    The payment date for all Shares in which the Participant becomes vested pursuant to Paragraph 5 above, other than Subparagraph 5(e) (as to which the payment date is determined in accordance with Subparagraph 6(a) above), shall be the calendar year containing the Maturity Date.

(c)    Upon conversion of RSUs into Shares under this Agreement, such RSUs shall be cancelled. Shares that become payable under this Agreement will be paid by the Company by the delivery to the Participant, or the Participant’s beneficiary or legal representative, one or more certificates (or other indicia of ownership)

5

representing Shares of Williams Common Stock equal in number to the number of Shares otherwise payable under this Agreement less the number of Shares having a Fair Market Value, as of the date the withholding tax obligation arises, equal to the minimum statutory withholding requirements. Notwithstanding the foregoing, to the extent permitted by Section 409A of the Code and the guidance thereunder, if federal employment taxes become due upon the Participant’s becoming entitled to payment of Shares, the number of Shares necessary to cover minimum statutory withholding requirements may be used to satisfy such requirements upon such entitlement.

7.    Other Provisions.

(a)    The Participant understands and agrees that payments under this Agreement shall not be used for, or in the determination of, any other payment or benefit under any continuing agreement, plan, policy, practice or arrangement providing for the making of any payment or the provision of any benefits to or for the Participant or the Participant’s beneficiaries or representatives, including, without limitation, any employment agreement, any change of control severance protection plan or any employee benefit plan as defined in Section 3(3) of ERISA, including, but not limited to qualified and non-qualified retirement plans.

(b)    The Participant agrees and understands that, subject to the limit expressed in clause (iii) of the following sentence, stock certificates (or other indicia of ownership) issued may be held as collateral for monies he/she owes to Company or any of its Affiliates, including but not limited to personal loan(s), Company credit card debt, relocation repayment obligations or benefits from any plan that provides for pre-paid educational assistance. In addition, the Company may accelerate the time or schedule of a payment of vested Shares and/or deduct from any payment of Shares to the Participant under this Agreement, or to his or her beneficiaries in the case of the Participant’s death, that number of Shares having a Fair Market Value at the date of such deduction equal to the amount of such debt as satisfaction of any such debt, provided that (i) such debt is incurred in the ordinary course of the employment relationship between the Company or any of its Affiliates and the Participant, (ii) the aggregate amount of any such debt-related collateral held or deduction made in any taxable year of the Company with respect to the Participant does not exceed $5,000, and (iii) the deduction of Shares is made at the same time and in the same amount as the debt otherwise would have been due and collected from the Participant.

(c)    Except as provided in Subparagraphs 5(c) through 5(g) above, in the event that the Participant’s employment with the Company or any of its Affiliates terminates prior to the Maturity Date, RSUs subject to this Agreement and any right to Shares issuable hereunder shall be forfeited.

(d)    The Participant acknowledges that this Award and similar awards are made on a selective basis and are, therefore, to be kept confidential.

(e)    RSUs, Shares and the Participant’s interest in RSUs and Shares, may not be sold, assigned, transferred, pledged or otherwise disposed of or encumbered at any time prior to both (i) the Participant’s becoming vested in Shares and (ii) payment of Shares under this Agreement.

(f)    If the Participant at any time forfeits any or all of the RSUs pursuant to this Agreement, the Participant agrees that all of the Participant’s rights to and interest in such RSUs and in Shares issuable thereunder shall terminate upon forfeiture without payment of consideration.

(g)    The Committee shall determine whether an event has occurred resulting in the forfeiture of the RSUs and any Shares issuable thereunder in accordance with this Agreement and all determinations of the Committee shall be final and conclusive.

(h)    With respect to the right to receive payment of Shares under this Agreement, nothing contained herein shall give the Participant any rights that are greater than those of a general creditor of the Company.

6

(i)    The obligations of the Company under this Agreement are unfunded and unsecured. Each Participant shall have the status of a general creditor of the Company with respect to amounts due, if any, under this Agreement.

(j)    The parties to this Agreement intend that this Agreement meet the requirements of Section 409A of the Code and recognize that it may be necessary to modify this Agreement and/or the Plan to reflect guidance under Section 409A of the Code issued by the Internal Revenue Service. Participant agrees that the Committee shall have sole discretion in determining (i) whether any such modification is desirable or appropriate and (ii) the terms of any such modification.

(k)    The Participant hereby automatically becomes a party to this Agreement whether or not he or she accepts the Award electronically or in writing in accordance with procedures of the Committee, its delegates or agents.

(l)    Nothing in this Agreement or the Plan shall interfere with or limit in any way the right of the Company or an Affiliate to terminate the Participant’s employment or service at any time, nor confer upon the Participant the right to continue in the employ of the Company and/or Affiliate.

(m)    The Participant hereby acknowledges that nothing in this Agreement shall be construed as requiring the Committee to allow a Domestic Relations Order with respect to this Award.

8.    Notices. All notices to the Company required hereunder shall be in writing and delivered by hand or by mail, addressed to The Williams Companies, Inc., One Williams Center, Tulsa, Oklahoma 74172, Attention: Stock Administration Department. Notices shall become effective upon their receipt by the Company if delivered in the foregoing manner. To direct the sale of any Shares issued under this Agreement, contact Fidelity at http://netbenefits.fidelity.comor by telephone at 800-544-9354.

9.    Forfeiture and Clawback. Notwithstanding any other provision of the Plan or this Agreement to the contrary, by accepting the Award represented by this Agreement, the Participant acknowledges that any incentive-based compensation paid to the Participant hereunder may be subject to recovery by the Company under any clawback policy that the Company may adopt from time to time, including without limitation any policy that the Company may be required to adopt under Section 954 of the Dodd-Frank Wall Street Reform and Consumer Protection Act and the rules and regulations of the U.S. Securities and Exchange Commission thereunder or the requirements of any national securities exchange on which the Shares may be listed. The Participant further agrees to promptly return any such incentive-based compensation which the Company determines it is required to recover from you under any such clawback policy.

10.    Tax Consultation. The Participant understands he or she will incur tax consequences as a result of acquisition or disposition of the Shares. The Participant agrees to consult with any tax consultants he or she thinks advisable in connection with the acquisition of the Shares and acknowledges that he or she is not relying, and will not rely, on the Company for any tax advice.

THE WILLIAMS COMPANIES, INC.

By:_________________________

Alan S. Armstrong

President and CEO

Participant: <@Name

SSN: <@SSN @>

7

EX-10.19

Exhibit 10.19

Date=Grant Date

TO:        <@Name@>

FROM:    Alan S. Armstrong

SUBJECT:    2016Restricted Stock Unit Award

You have been selected to receive a restricted stock unit award. This award is subject to the terms and conditions of The Williams Companies, Inc. 2007 Incentive Plan, as amended and restated from time to time, and, the 2016 Restricted Stock Unit Agreement (the “Agreement”).

This award is granted to you in recognition of your role as an employee whose responsibilities and performance are critical to the attainment of long-term goals. This award and similar awards are made on a selective basis and are, therefore, to be kept confidential.

Subject to all of the terms of the Agreement, you will become entitled to payment of this award if you are an active employee of the Company on the third anniversary of the grant date.

If you have any questions about this award, you may contact a dedicated Fidelity Stock Plan Representative at 1-800-544-9354.

1

2016 RESTRICTED STOCK UNIT AGREEMENT

THIS RESTRICTED STOCK UNIT AGREEMENT (this “Agreement”), which contains the terms and conditions for the Restricted Stock Units (“Restricted Stock Units” or “RSUs”) referred to in the 2016 Restricted Stock Unit Award Letter delivered in hard copy or electronically to Participant (“2016 Award Letter”), is by and between THE WILLIAMS COMPANIES, INC., a Delaware corporation (the “Company”) and the individual identified on the last page hereof (the “Participant”).

1.    Grant of RSUs. Subject to the terms and conditions of The Williams Companies, Inc. 2007 Incentive Plan, as amended and restated from time to time (the “Plan”), this Agreement and the 2016Award Letter, the Company hereby grants an award (the “Award”) to the Participant of <@Num+C @> RSUs effective <@GrDt+C@> (the “Effective Date”). The Award gives the Participant the opportunity to earn the right to receive the number ofshares of the Common Stock of the Company equal to the number of RSUs shown in the prior sentence, subject to adjustment under the terms of this Agreement. These shares are referred to in this Agreement as the “Shares.” Until the Participant both becomes vested in the Shares under the terms of Paragraph 4 and is paid such Shares under the terms of Paragraph 5, the Participant shall have no rights as a stockholder of the Company with respect to the Shares; provided, however, that the Participant shall have the right to earn Dividend Equivalents with respect to the RSUs awarded under this Agreement in accordance with Subparagraph 4(i) below.

2.    Incorporation of Plan and Acceptance of Documents. The Plan is hereby incorporated herein by reference, and all capitalized terms used herein which are not defined in this Agreement shall have the respective meanings set forth in the Plan. The Participant acknowledges that he or she has received a copy of, or has online access to, the Plan and hereby automatically accepts the RSUs subject to all the terms and provisions of the Plan and this Agreement. The Participant hereby further agrees that he or she has received a copy of, or has online access to, the Plan prospectus, as updated from time to time, and hereby acknowledges his or her automatic acceptance and receipt of such prospectus electronically.

3.    Committee Decisions and Interpretations. The Participant hereby agrees to accept as binding, conclusive and final all actions, decisions and/or interpretations of the Committee, its delegates, or agents, upon any questions or other matters arising under the Plan or this Agreement.

4.    Vesting; Legally Binding Rights.

(a)    Notwithstanding any other provision of this Agreement, (i) a Participant shall not be entitled to any payment of Shares under this Agreement unless and until such Participant obtains a legally binding right to such Shares and satisfies applicable vesting conditions for such payment and (ii) a Participant shall not be entitled to payment of any Dividend Equivalents unless and until such Participant obtains a legally binding right to, and satisfies applicable vesting conditions for payment of, the underlying Shares on which such Dividend Equivalents are payable.

(b)    Except as otherwise provided in Subparagraphs 4(c) – 4(h) below, the Participant shall vest in all Shares on the third anniversary of the Effective Date (the “Maturity Date”), but only if the Participant remains an active employee of the Company or any of its Affiliates through the Maturity Date.

(c)    If a Participant dies prior to the Maturity Date while an active employee of the Company or any of its Affiliates, the Participant shall vest in all Shares at the time of such death.

(d)    If a Participant becomes Disabled (as defined below) prior to the Maturity Date while an active employee of the Company or any of its Affiliates, the Participant shall vest in all Shares at the time the Participant becomes Disabled. For purposes of this Subparagraph 4(d), the Participant shall be considered Disabled if he or she (A) is unable to engage in any substantial gainful activity by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than twelve (12) months, or (B) is, by reason of any medically

2

determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than twelve (12) months, receiving income replacement benefits for a period of not less than three (3) months under an accident and health plan covering employees of the Participant’s employer. Notwithstanding the forgoing, all determinations of whether a Participant is Disabled shall be made in accordance with Section 409A of the Internal Revenue Code of 1986, as amended (the “Code”) and the guidance thereunder.

(e)    If the Participant qualifies for Retirement (as defined in (i) below) with the Company or any of its Affiliates prior to the Maturity Date due to such Retirement, at the time of such Participant’s ceasing being an active employee, the Participant shall vest in a pro rata number of the Shares as determined in accordance with this Subparagraph 4(e). The pro rata number referred to above shall be determined by multiplying the number of Shares subject to the Award by a fraction, the numerator of which is the number of full and partial months in the period that begins the month following the month that contains the Effective Date and ends on (and includes) the date of the Participant’s ceasing being an active employee of the Company and its Affiliates, and the denominator of which is the total number of full and partial months in the period that begins the month following the month that contains the Effective Date and ends on (and includes) the Maturity Date.

(i) For purposes of this Subparagraph 4(e), a Participant “qualifies for Retirement” only if such Participant experiences a Separation from Service (as defined in (ii) below) after attaining age fifty-five (55) and completing at least three (3) years of service with the Company or any of its Affiliates.

(ii) As used in this Agreement, “Separation from Service” means a Participant’s termination or deemed termination from employment with the Company and its Affiliates. For purposes of determining whether a Separation from Service has occurred, the employment relationship is treated as continuing intact while the Participant is on military leave, sick leave or other bona fide leave of absence if the period of such leave does not exceed six (6) months, or if longer, so long as the Participant retains a right to reemployment with his or her employer under an applicable statute or by contract. For this purpose, a leave of absence constitutes a bona fide leave of absence only if there is a reasonable expectation that the Participant will return to perform services for his or her employer. If the period of leave exceeds six (6) months and the Participant does not retain a right to reemployment under an applicable statute or by contract, the employment relationship will be deemed to terminate on the first date immediately following such six (6) month period. Notwithstanding the foregoing, if a leave of absence is due to any medically determinable physical or mental impairment that can be expected to result in death or can be expected to last for a continuous period of not less than six (6) months, and such impairment causes the Participant to be unable to perform the duties of the Participant’s position of employment or any substantially similar position of employment, a twenty-nine (29) month period of absence shall be substituted for such six (6) month period. For purposes of this Agreement, a Separation from Service occurs at the date as of which the facts and circumstances indicate either that, after such date: (A) the Participant and the Company reasonably anticipate the Participant will perform no further services for the Company and its Affiliates (whether as an employee or an independent contractor) or (B) that the level of bona fide services the Participant will perform for the Company and its Affiliates (whether as an employee or independent contractor) will permanently decrease to no more than twenty (20%) of the average level of bona fide services performed over the immediately preceding thirty-six (36) month period or, if the Participant has been providing services to the Company and its Affiliates for less than thirty-six (36) months, the full period over which the Participant has rendered services, whether as an employee or independent contractor. The determination of whether a Separation from Service has occurred shall be governed by the provisions of Treasury Regulation § 1.409A-1, as amended, taking into account the objective facts and circumstances with respect to the level of bona fide services performed by the Participant after a certain date.

(iii)    As used in this Agreement, “Affiliate” means all persons with whom the Company would be considered a single employer under Section 414(b) of the Code, and all persons with whom such person would be considered a single employer under Section 414(c) of the Code.

3

(f)    If the Participant experiences a Separation from Service prior to the Maturity Date within two years following a Change in Control, either voluntarily for Good Reason or involuntarily (other than due to Cause), the Participant shall vest in all of the Shares upon such Separation from Service.

(g)    If the Participant experiences an involuntary Separation from Service prior to the Maturity Date and the Participant either receives benefits under a severance pay plan or program maintained by the Company or receives benefits under a separation agreement with the Company, the Participant shall vest in all Shares upon such Separation from Service.

(h)    If the Participant experiences an involuntary Separation from Service prior to the Maturity Date due to a sale of a business or the outsourcing of any portion of a business, the Participant shall vest in all Shares upon such Separation from Service, but only if the Company or any of its Affiliates failed to make an offer of comparable employment, as defined by a severance pay plan or program maintained by the Company, to the Participant. For purposes of this Subparagraph 4(h), a Termination of Affiliation shall constitute an involuntary Separation from Service.

(i)If the Participant becomes entitled to payment of any Shares under this Agreement, the Participant shall also be entitled to receipt of Dividend Equivalents with respect to such Shares in an amount equal to the amount of dividends, if any, that would have been payable on such Shares if such Shares had been issued and outstanding from the date of this Agreement through the payment date of the Shares. Dividend Equivalents shall remain assets of the Company until paid hereunder and may, in the discretion of the Committee be paid in either cash or Shares. If Dividend Equivalents are paid in Shares, the number of Shares so payable will equal the total amount of Dividend Equivalents payable, if any, divided by the Fair Market Value of a Share on the payment date. No fractional Shares shall be issued.

5.    Payment of Shares and Dividend Equivalents.

(a)    The payment date for all Shares in which a Participant becomes vested pursuant to Subparagraph 4(b) above, and Dividend Equivalents in which the Participant becomes vested pursuant to Subparagraph 4(i), shall be the Maturity Date.

(b)     The payment date for all Shares in which a Participant becomes vested pursuant to Subparagraphs 4(c) and 4(d) above, and Dividend Equivalents in which the Participant becomes vested pursuant to Subparagraph 4(i), shall be no more than thirty (30) days after the date the Participant dies or becomes Disabled, as applicable. If such 30-day period spans two calendar years, then payment will be made in the later calendar year.

(c)    The payment date for all Shares in which the Participant becomes vested pursuant to Subparagraphs 4(e), 4(f) and 4(h) above, and Dividend Equivalents in which the Participant becomes vested pursuant to Subparagraph 4(i), shall be no more than thirty (30) days following such Participant’s Separation from Service, unless otherwise provided in Subparagraph 5(f) below. If such 30-day period spans two calendar years, then payment will be made in the later calendar year.

(d)    The payment date for all Shares in which the Participant becomes vested pursuant to Subparagraph 4(g) above, and Dividend Equivalents in which the Participant becomes vested pursuant to Subparagraph 4(i), shall be no more than sixty (60) days following such Participant’s Separation from Service, unless otherwise provided in Subparagraph 5(f) below. If such 60-day period spans two calendar years, then payment will be made in the later calendar year.

(e)    Upon conversion of RSUs into Shares under this Agreement, such RSUs shall be cancelled. Shares that become payable under this Agreement and will be paid by the Company by the delivery to the Participant, or the Participant’s beneficiary or legal representative, of one or more certificates (or other indicia of ownership) representing shares of Williams Common Stock equal in number to the number of Shares otherwise payable under this Agreement less the number of Shares having a Fair Market Value, as of the date the withholding tax obligation arises, equal to the minimum statutory withholding requirements. Notwithstanding the

4

foregoing, to the extent permitted by Section 409A of the Code and the guidance issued by the Internal Revenue Service thereunder, if federal employment taxes become due upon the Participant’s becoming entitled to payment of Shares, the number of Shares necessary to cover minimum statutory withholding requirements may, in the discretion of the Company, be used to satisfy such requirements upon such entitlement.

(f)    If the Participant was a “key employee” within the meaning of Section 409A(a)(B)(i) of the Code immediately prior to his or her Separation from Service, and such Participant vested in such Shares under Subparagraphs 4(e), (4)(f), 4(g) or 4(h) above, payment shall not be made sooner than six (6) months following the date such Participant experienced a Separation from Service. “Key employee” means an employee designated on an annual basis by the Company as of December 31 (the “Key Employee Designation Date”) as an employee meeting the requirements of Section 416(i) of Code utilizing the definition of compensation under Treasury Regulation § 1.415(c)-2(d)(2). A Participant designated as a “key employee” shall be a “key employee” for the entire twelve (12) month period beginning on April 1 following the Key Employee Designation Date.

6.    Other Provisions.

(a)    The Participant understands and agrees that payments under this Agreement shall not be used for, or in the determination of, any other payment or benefit under any continuing agreement, plan, policy, practice or arrangement providing for the making of any payment or the provision of any benefits to or for the Participant or the Participant’s beneficiaries or representatives, including, without limitation, any employment agreement, any change of control severance protection plan or any employee benefit plan as defined in Section 3(3) of ERISA, including, but not limited to qualified and non-qualified retirement plans.

(b)    The Participant agrees and understands that, subject to the limit expressed in clause (iii) of the following sentence, upon payment of Shares and Dividend Equivalents under this Agreement, stock certificates (or other indicia of ownership) issued may be held as collateral for monies he/she owes to Company or any of its Affiliates, including but not limited to personal loan(s), Company credit card debt, relocation repayment obligations or benefits from any plan that provides for pre-paid educational assistance. In addition, the Company may accelerate the time or schedule of a payment of vested Shares and Dividend Equivalents, and/or deduct from any payment of Shares and Dividend Equivalents to the Participant under this Agreement, or to his or her beneficiaries in the case of the Participant’s death, that number of Shares and Dividend Equivalents having a Fair Market Value at the date of such deduction to the amount of such debt as satisfaction of any such debt, provided that (i) such debt is incurred in the ordinary course of the employment relationship between the Company or any of its Affiliates and the Participant, (ii) the aggregate amount of any such debt-related collateral held or deduction made in any taxable year of the Company with respect to the Participant does not exceed $5,000, and (iii) the deduction of Shares and Dividend Equivalents is made at the same time and in the same amount as the debt otherwise would have been due and collected from the Participant.

(c)    Except as provided in Subparagraphs 4(c) through 4(h) above, in the event that the Participant experiences a Separation from Service prior to the Participant’s becoming vested in the Shares under this Agreement, RSUs subject to this Agreement and any right to Shares and Dividend Equivalents issuable hereunder shall be forfeited.

(d)    The Participant acknowledges that this Award and similar awards are made on a selective basis and are, therefore, to be kept confidential.

(e)    RSUs, Shares and Dividend Equivalents and the Participant’s interest in RSUs and Shares and Dividend Equivalents may not be sold, assigned, transferred, pledged or otherwise disposed of or encumbered at any time prior to both (i) the Participant’s becoming vested in such Shares and (ii) payment of such Shares and Dividend Equivalents under this Agreement.

(f)    If the Participant at any time forfeits any or all of the RSUs pursuant to this Agreement, the Participant agrees that all of the Participant’s rights to and interest in such RSUs and in Shares and Dividend Equivalents payable thereon, if any, issuable hereunder shall terminate upon forfeiture without payment of consideration.

5

(g)    The Committee shall determine whether an event has occurred resulting in the forfeiture of the Shares and Dividend Equivalents payable thereon in accordance with this Agreement, and all determinations of the Committee shall be final and conclusive.

(h)    With respect to the right to receive payment of the Shares and Dividend Equivalents under this Agreement, nothing contained herein shall give the Participant any rights that are greater than those of a general creditor of the Company.

(i)    The obligations of the Company under this Agreement are unfunded and unsecured. Each Participant shall have the status of a general creditor of the Company with respect to amounts due, if any, under this Agreement.

(j)    The parties to this Agreement intend that this Agreement meet the applicable requirements of Section 409A of the Code and recognize that it may be necessary to modify this Agreement and/or the Plan to reflect guidance under Section 409A of the Code issued by the Internal Revenue Service. Participant agrees that the Committee shall have sole discretion in determining (i) whether any such modification is desirable or appropriate and (ii) the terms of any such modification.

(k)    The Participant hereby automatically becomes a party to this Agreement whether or not he or she accepts the Award electronically or in writing in accordance with procedures of the Committee, its delegates or agents.

(l)    Nothing in this Agreement or the Plan shall interfere with or limit in any way the right of the Company or an Affiliate to terminate the Participant’s employment or service at any time, nor confer upon the Participant the right to continue in the employ of the Company and/or Affiliate.

(m)    The Participant hereby acknowledges that nothing in this Agreement shall be construed as requiring the Committee to allow a Domestic Relations Order with respect to this Award.

7.    Notices. All notices to the Company required hereunder shall be in writing and delivered by hand or by mail, addressed to The Williams Companies, Inc., One Williams Center, Tulsa, Oklahoma 74172, Attention: Stock Administration Department. Notices shall become effective upon their receipt by the Company if delivered in the foregoing manner. To direct the sale of any Shares issued under this Agreement, contact Fidelity at http://netbenefits.fidelity.comor by telephone at 800-544-9354.

8.    Tax Consultation. You understand you will incur tax consequences as a result of acquisition or disposition of the Shares and Dividend Equivalents. You agree to consult with any tax consultants you think advisable in connection with the acquisition of the Shares and Dividend Equivalents and acknowledge that you are not relying, and will not rely, on the Company for any tax advice.

THE WILLIAMS COMPANIES, INC.

By:_________________________

Alan S. Armstrong

President and CEO

Participant: <@Name

SSN: <@SSN @>

6

EX-10.20

Exhibit 10.20

Date=Grant Date

TO:        <@Name@>

FROM:    Alan S. Armstrong

SUBJECT:    2016 Restricted Stock Unit Award

You have been selected to receive a restricted stock unit award. This award is subject to the terms and conditions of The Williams Companies, Inc. 2007 Incentive Plan, as amended and restated from time to time, and, the 2016 Restricted Stock Unit Agreement (the “Agreement”).

This award is granted to you in recognition of your role as an employee whose responsibilities and performance are critical to the attainment of long-term goals. This award and similar awards are made on a selective basis and are, therefore, to be kept confidential.

Subject to all of the terms of the Agreement, you will become entitled to payment of this award if you are an active employee of the Company on February 22, 2019.

If you have any questions about this award, you may contact a dedicated Fidelity Stock Plan Representative at 1-800-544-9354.

1

2016 RESTRICTED STOCK UNIT AGREEMENT

THIS RESTRICTED STOCK UNIT AGREEMENT (this “Agreement”), which contains the terms and conditions for the Restricted Stock Units (“Restricted Stock Units” or “RSUs”) referred to in the 2016 Restricted Stock Unit Award Letter delivered in hard copy or electronically to Participant (“2016 Award Letter”), is by and between THE WILLIAMS COMPANIES, INC., a Delaware corporation (the “Company”) and the individual identified on the last page hereof (the “Participant”).

1.    Grant of RSUs. Subject to the terms and conditions of The Williams Companies, Inc. 2007 Incentive Plan, as amended and restated from time to time (the “Plan”), this Agreement and the 2016Award Letter, the Company hereby grants an award (the “Award”) to the Participant of <@Num+C @> RSUs effective <@GrDt+C@> (the “Effective Date”). The Award gives the Participant the opportunity to earn the right to receive the number ofshares of the Common Stock of the Company equal to the number of RSUs shown in the prior sentence, subject to adjustment under the terms of this Agreement. These shares are referred to in this Agreement as the “Shares.” Until the Participant both becomes vested in the Shares under the terms of Paragraph 4 and is paid such Shares under the terms of Paragraph 5, the Participant shall have no rights as a stockholder of the Company with respect to the Shares; provided, however, that the Participant shall have the right to earn Dividend Equivalents with respect to the RSUs awarded under this Agreement in accordance with Subparagraph 4(i) below.

2.    Incorporation of Plan and Acceptance of Documents. The Plan is hereby incorporated herein by reference, and all capitalized terms used herein which are not defined in this Agreement shall have the respective meanings set forth in the Plan. The Participant acknowledges that he or she has received a copy of, or has online access to, the Plan and hereby automatically accepts the RSUs subject to all the terms and provisions of the Plan and this Agreement. The Participant hereby further agrees that he or she has received a copy of, or has online access to, the Plan prospectus, as updated from time to time, and hereby acknowledges his or her automatic acceptance and receipt of such prospectus electronically.

3.    Committee Decisions and Interpretations. The Participant hereby agrees to accept as binding, conclusive and final all actions, decisions and/or interpretations of the Committee, its delegates, or agents, upon any questions or other matters arising under the Plan or this Agreement.

4.    Vesting; Legally Binding Rights.

(a)    Notwithstanding any other provision of this Agreement, (i) a Participant shall not be entitled to any payment of Shares under this Agreement unless and until such Participant obtains a legally binding right to such Shares and satisfies applicable vesting conditions for such payment and (ii) a Participant shall not be entitled to payment of any Dividend Equivalents unless and until such Participant obtains a legally binding right to, and satisfies applicable vesting conditions for payment of, the underlying Shares on which such Dividend Equivalents are payable.

(b)    Except as otherwise provided in Subparagraphs 4(c) – 4(h) below, the Participant shall vest in all Shares on February 22, 2019 (the “Maturity Date”), but only if the Participant remains an active employee of the Company or any of its Affiliates through the Maturity Date.

(c)    If a Participant dies prior to the Maturity Date while an active employee of the Company or any of its Affiliates, the Participant shall vest in all Shares at the time of such death.

(d)    If a Participant becomes Disabled (as defined below) prior to the Maturity Date while an active employee of the Company or any of its Affiliates, the Participant shall vest in all Shares at the time the Participant becomes Disabled. For purposes of this Subparagraph 4(d), the Participant shall be considered Disabled if he or she (A) is unable to engage in any substantial gainful activity by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than twelve (12) months, or (B) is, by reason of any medically

2

determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than twelve (12) months, receiving income replacement benefits for a period of not less than three (3) months under an accident and health plan covering employees of the Participant’s employer. Notwithstanding the forgoing, all determinations of whether a Participant is Disabled shall be made in accordance with Section 409A of the Internal Revenue Code of 1986, as amended (the “Code”) and the guidance thereunder.

(e)    If the Participant qualifies for Retirement (as defined in (i) below) with the Company or any of its Affiliates prior to the Maturity Date due to such Retirement, at the time of such Participant’s ceasing being an active employee, the Participant shall vest in a pro rata number of the Shares as determined in accordance with this Subparagraph 4(e). The pro rata number referred to above shall be determined by multiplying the number of Shares subject to the Award by a fraction, the numerator of which is the number of full and partial months in the period that begins the month following the month that contains the Effective Date and ends on (and includes) the date of the Participant’s ceasing being an active employee of the Company and its Affiliates, and the denominator of which is the total number of full and partial months in the period that begins the month following the month that contains the Effective Date and ends on (and includes) the Maturity Date.

(i) For purposes of this Subparagraph 4(e), a Participant “qualifies for Retirement” only if such Participant experiences a Separation from Service (as defined in (ii) below) after attaining age fifty-five (55) and completing at least three (3) years of service with the Company or any of its Affiliates.

(ii) As used in this Agreement, “Separation from Service” means a Participant’s termination or deemed termination from employment with the Company and its Affiliates. For purposes of determining whether a Separation from Service has occurred, the employment relationship is treated as continuing intact while the Participant is on military leave, sick leave or other bona fide leave of absence if the period of such leave does not exceed six (6) months, or if longer, so long as the Participant retains a right to reemployment with his or her employer under an applicable statute or by contract. For this purpose, a leave of absence constitutes a bona fide leave of absence only if there is a reasonable expectation that the Participant will return to perform services for his or her employer. If the period of leave exceeds six (6) months and the Participant does not retain a right to reemployment under an applicable statute or by contract, the employment relationship will be deemed to terminate on the first date immediately following such six (6) month period. Notwithstanding the foregoing, if a leave of absence is due to any medically determinable physical or mental impairment that can be expected to result in death or can be expected to last for a continuous period of not less than six (6) months, and such impairment causes the Participant to be unable to perform the duties of the Participant’s position of employment or any substantially similar position of employment, a twenty-nine (29) month period of absence shall be substituted for such six (6) month period. For purposes of this Agreement, a Separation from Service occurs at the date as of which the facts and circumstances indicate either that, after such date: (A) the Participant and the Company reasonably anticipate the Participant will perform no further services for the Company and its Affiliates (whether as an employee or an independent contractor) or (B) that the level of bona fide services the Participant will perform for the Company and its Affiliates (whether as an employee or independent contractor) will permanently decrease to no more than twenty (20%) of the average level of bona fide services performed over the immediately preceding thirty-six (36) month period or, if the Participant has been providing services to the Company and its Affiliates for less than thirty-six (36) months, the full period over which the Participant has rendered services, whether as an employee or independent contractor. The determination of whether a Separation from Service has occurred shall be governed by the provisions of Treasury Regulation § 1.409A-1, as amended, taking into account the objective facts and circumstances with respect to the level of bona fide services performed by the Participant after a certain date.

(iii)    As used in this Agreement, “Affiliate” means all persons with whom the Company would be considered a single employer under Section 414(b) of the Code, and all persons with whom such person would be considered a single employer under Section 414(c) of the Code.

3

(f)    If the Participant experiences a Separation from Service prior to the Maturity Date within two years following a Change in Control, either voluntarily for Good Reason or involuntarily (other than due to Cause), the Participant shall vest in all of the Shares upon such Separation from Service.

(g)    If the Participant experiences an involuntary Separation from Service prior to the Maturity Date and the Participant either receives benefits under a severance pay plan or program maintained by the Company or receives benefits under a separation agreement with the Company, the Participant shall vest in all Shares upon such Separation from Service.

(h)    If the Participant experiences an involuntary Separation from Service prior to the Maturity Date due to a sale of a business or the outsourcing of any portion of a business, the Participant shall vest in all Shares upon such Separation from Service, but only if the Company or any of its Affiliates failed to make an offer of comparable employment, as defined by a severance pay plan or program maintained by the Company, to the Participant. For purposes of this Subparagraph 4(h), a Termination of Affiliation shall constitute an involuntary Separation from Service.

(i)If the Participant becomes entitled to payment of any Shares under this Agreement, the Participant shall also be entitled to receipt of Dividend Equivalents with respect to such Shares in an amount equal to the amount of dividends, if any, that would have been payable on such Shares if such Shares had been issued and outstanding from the date of this Agreement through the payment date of the Shares. Dividend Equivalents shall remain assets of the Company until paid hereunder and may, in the discretion of the Committee be paid in either cash or Shares. If Dividend Equivalents are paid in Shares, the number of Shares so payable will equal the total amount of Dividend Equivalents payable, if any, divided by the Fair Market Value of a Share on the payment date. No fractional Shares shall be issued.

5.    Payment of Shares and Dividend Equivalents.

(a)    The payment date for all Shares in which a Participant becomes vested pursuant to Subparagraph 4(b) above, and Dividend Equivalents in which the Participant becomes vested pursuant to Subparagraph 4(i), shall be the Maturity Date.

(b)     The payment date for all Shares in which a Participant becomes vested pursuant to Subparagraphs 4(c) and 4(d) above, and Dividend Equivalents in which the Participant becomes vested pursuant to Subparagraph 4(i), shall be no more than thirty (30) days after the date the Participant dies or becomes Disabled, as applicable. If such 30-day period spans two calendar years, then payment will be made in the later calendar year.

(c)    The payment date for all Shares in which the Participant becomes vested pursuant to Subparagraphs 4(e), 4(f) and 4(h) above, and Dividend Equivalents in which the Participant becomes vested pursuant to Subparagraph 4(i), shall be no more than thirty (30) days following such Participant’s Separation from Service, unless otherwise provided in Subparagraph 5(f) below. If such 30-day period spans two calendar years, then payment will be made in the later calendar year.

(d)    The payment date for all Shares in which the Participant becomes vested pursuant to Subparagraph 4(g) above, and Dividend Equivalents in which the Participant becomes vested pursuant to Subparagraph 4(i), shall be no more than sixty (60) days following such Participant’s Separation from Service. If such 60-day period spans two calendar years, then payment will be made in the later calendar year, unless otherwise provided in Subparagraph 5(f) below.

(e)    Upon conversion of RSUs into Shares under this Agreement, such RSUs shall be cancelled. Shares that become payable under this Agreement and will be paid by the Company by the delivery to the Participant, or the Participant’s beneficiary or legal representative, of one or more certificates (or other indicia of ownership) representing shares of Williams Common Stock equal in number to the number of Shares otherwise payable under this Agreement less the number of Shares having a Fair Market Value, as of the date the withholding tax obligation arises, equal to the minimum statutory withholding requirements. Notwithstanding the

4

foregoing, to the extent permitted by Section 409A of the Code and the guidance issued by the Internal Revenue Service thereunder, if federal employment taxes become due upon the Participant’s becoming entitled to payment of Shares, the number of Shares necessary to cover minimum statutory withholding requirements may, in the discretion of the Company, be used to satisfy such requirements upon such entitlement.

(f)     If the Participant was a “key employee” within the meaning of Section 409A(a)(B)(i) of the Code immediately prior to his or her Separation from Service, and such Participant vested in such Shares under Subparagraphs 4(e), 4(f), 4(g) or 4(h) above, payment shall not be made sooner than six (6) months following the date such Participant experienced a Separation from Service. “Key employee” means an employee designated on an annual basis by the Company as of December 31 (the “Key Employee Designation Date”) as an employee meeting the requirements of Section 416(i) of Code utilizing the definition of compensation under Treasury Regulation § 1.415(c)-2(d)(2). A Participant designated as a “key employee” shall be a “key employee” for the entire twelve (12) month period beginning on April 1 following the Key Employee Designation Date.

6.    Other Provisions.

(a)    The Participant understands and agrees that payments under this Agreement shall not be used for, or in the determination of, any other payment or benefit under any continuing agreement, plan, policy, practice or arrangement providing for the making of any payment or the provision of any benefits to or for the Participant or the Participant’s beneficiaries or representatives, including, without limitation, any employment agreement, any change of control severance protection plan or any employee benefit plan as defined in Section 3(3) of ERISA, including, but not limited to qualified and non-qualified retirement plans.

(b)    The Participant agrees and understands that, subject to the limit expressed in clause (iii) of the following sentence, upon payment of Shares and Dividend Equivalents under this Agreement, stock certificates (or other indicia of ownership) issued may be held as collateral for monies he/she owes to Company or any of its Affiliates, including but not limited to personal loan(s), Company credit card debt, relocation repayment obligations or benefits from any plan that provides for pre-paid educational assistance. In addition, the Company may accelerate the time or schedule of a payment of vested Shares and Dividend Equivalents, and/or deduct from any payment of Shares and Dividend Equivalents to the Participant under this Agreement, or to his or her beneficiaries in the case of the Participant’s death, that number of Shares and Dividend Equivalents having a Fair Market Value at the date of such deduction to the amount of such debt as satisfaction of any such debt, provided that (i) such debt is incurred in the ordinary course of the employment relationship between the Company or any of its Affiliates and the Participant, (ii) the aggregate amount of any such debt-related collateral held or deduction made in any taxable year of the Company with respect to the Participant does not exceed $5,000, and (iii) the deduction of Shares and Dividend Equivalents is made at the same time and in the same amount as the debt otherwise would have been due and collected from the Participant.

(c)    Except as provided in Subparagraphs 4(c) through 4(h) above, in the event that the Participant experiences a Separation from Service prior to the Participant’s becoming vested in the Shares under this Agreement, RSUs subject to this Agreement and any right to Shares and Dividend Equivalents issuable hereunder shall be forfeited.

(d)    The Participant acknowledges that this Award and similar awards are made on a selective basis and are, therefore, to be kept confidential.

(e)    RSUs, Shares and Dividend Equivalents and the Participant’s interest in RSUs and Shares and Dividend Equivalents may not be sold, assigned, transferred, pledged or otherwise disposed of or encumbered at any time prior to both (i) the Participant’s becoming vested in such Shares and (ii) payment of such Shares and Dividend Equivalents under this Agreement.

(f)    If the Participant at any time forfeits any or all of the RSUs pursuant to this Agreement, the Participant agrees that all of the Participant’s rights to and interest in such RSUs and in Shares and Dividend Equivalents payable thereon, if any, issuable hereunder shall terminate upon forfeiture without payment of consideration.

5

(g)    The Committee shall determine whether an event has occurred resulting in the forfeiture of the Shares and Dividend Equivalents payable thereon in accordance with this Agreement, and all determinations of the Committee shall be final and conclusive.

(h)    With respect to the right to receive payment of the Shares and Dividend Equivalents under this Agreement, nothing contained herein shall give the Participant any rights that are greater than those of a general creditor of the Company.

(i)    The obligations of the Company under this Agreement are unfunded and unsecured. Each Participant shall have the status of a general creditor of the Company with respect to amounts due, if any, under this Agreement.

(j)    The parties to this Agreement intend that this Agreement meet the applicable requirements of Section 409A of the Code and recognize that it may be necessary to modify this Agreement and/or the Plan to reflect guidance under Section 409A of the Code issued by the Internal Revenue Service. Participant agrees that the Committee shall have sole discretion in determining (i) whether any such modification is desirable or appropriate and (ii) the terms of any such modification.

(k)    The Participant hereby automatically becomes a party to this Agreement whether or not he or she accepts the Award electronically or in writing in accordance with procedures of the Committee, its delegates or agents.

(l)    Nothing in this Agreement or the Plan shall interfere with or limit in any way the right of the Company or an Affiliate to terminate the Participant’s employment or service at any time, nor confer upon the Participant the right to continue in the employ of the Company and/or Affiliate.

(m)    The Participant hereby acknowledges that nothing in this Agreement shall be construed as requiring the Committee to allow a Domestic Relations Order with respect to this Award.

7.    Notices. All notices to the Company required hereunder shall be in writing and delivered by hand or by mail, addressed to The Williams Companies, Inc., One Williams Center, Tulsa, Oklahoma 74172, Attention: Stock Administration Department. Notices shall become effective upon their receipt by the Company if delivered in the foregoing manner. To direct the sale of any Shares issued under this Agreement, contact Fidelity at http://netbenefits.fidelity.comor by telephone at 800-544-9354.

8.    Tax Consultation. You understand you will incur tax consequences as a result of acquisition or disposition of the Shares and Dividend Equivalents. You agree to consult with any tax consultants you think advisable in connection with the acquisition of the Shares and Dividend Equivalents and acknowledge that you are not relying, and will not rely, on the Company for any tax advice.

THE WILLIAMS COMPANIES, INC.

By:_________________________

Alan S. Armstrong

President and CEO

Participant: <@Name

SSN: <@SSN @>

6

EX-10.21

Exhibit 10.21

Date=Grant Date

TO:        <@Name@>

FROM:    Alan S. Armstrong

SUBJECT:    2016Restricted Stock Unit Award

You have been granted a restricted stock unit award. This award, which is subject to adjustment under the 2016 Restricted Stock Unit Agreement (the “Agreement”), is granted to you in recognition of your role as a non-management director for The Williams Companies, Inc. It is granted and subject to the terms and conditions of The Williams Companies, Inc. 2007 Incentive Plan, as amended and restated from time to time, and the Agreement.

Subject to all of the terms of the Agreement, you will become entitled to payment of this award one year after the date on which this award is made.

If you have any questions about this award, you may contact a dedicated Fidelity Stock Plan Representative at 1-800-823-0217.

1

2016 RESTRICTED STOCK UNIT AGREEMENT

THIS RESTRICTED STOCK UNIT AGREEMENT (this “Agreement”), which contains the terms and conditions for the Restricted Stock Units (“Restricted Stock Units” or “RSUs”) referred to in the 2016 Restricted Stock Unit Award Letter delivered in hard copy or electronically to Participant (“2016 Award Letter”), is by and between THE WILLIAMS COMPANIES, INC., a Delaware corporation (the “Company”) and the individual identified on the last page hereof (the “Participant”).

1.    Grant of RSUs. Subject to the terms and conditions of The Williams Companies, Inc. 2007 Incentive Plan, as amended and restated from time to time (the “Plan”), this Agreement and the 2016 Award Letter, the Company hereby grants an award (the “Award”) to the Participant of <@Num+C @> RSUs effective <@GrDt+C@> (the “Effective Date”). The Award gives the Participant the right to receive the number ofshares of the Common Stock of the Company equal to the number of RSUs shown in the prior sentence, subject to adjustment under the terms of this Agreement. These shares are referred to in this Agreement as the “Shares.” Until the Participant receives payment of the Shares under the terms of Paragraph 4, the Participant shall have no rights as a stockholder of the Company with respect to the Shares, except for the right to earn Dividend Equivalents as set forth herein.

2.    Incorporation of Plan and Acceptance of Documents. The Plan is hereby incorporated herein by reference, and all capitalized terms used herein which are not defined in this Agreement shall have the respective meanings set forth in the Plan. The Participant acknowledges that he or she has received a copy of, or has online access to, the Plan and hereby automatically accepts the RSUs subject to all the terms and provisions of the Plan and this Agreement. The Participant hereby further agrees that he or she has received a copy of, or has online access to, the prospectus and hereby acknowledges his or her automatic acceptance and receipt of such prospectus electronically.

3.    Board Decisions and Interpretations. The Participant hereby agrees to accept as binding, conclusive and final all actions, decisions and/or interpretations of the Board, its delegates, or agents, upon any questions or other matters arising under the Plan or this Agreement.

4.    Payment of Shares; Dividend Equivalents.

(a)    Except as otherwise provided in Subparagraph 4(b) or 4(d) below, the Participant shall receive payment of all Shares on the date that is one year after the Effective Date (not including the Effective Date) (the “Maturity Date”). For example, if the Effective Date of the Participant’s award under this Agreement is August 4, 2016, the Maturity Date will be August 4, 2017.

(b)    If the Participant dies prior to the Maturity Date while serving as a Non-Management Director of the Company or his or her service as a Non-Management Director of the Company terminates for any other reason prior to the Maturity Date and such termination constitutes a “separation from service” as defined under Treasury Regulation § 1.409A-1, as amended, the Participant shall receive payment of all Shares at the time of such death or separation from service. In this regard, if at the time a Non-Management Director’s service as a Non-Management Director terminates, such Non-Management Director is also providing services to the Company or an Affiliate (as defined below) as an independent contractor, no separation from service by such Non-Management Director shall occur, and no Shares shall be payable to such Non-Management Director until the date on which such Non-Management Director has a Separation from Service as an Independent Contractor (as defined below) from the Company and its Affiliates.

(c)     All Shares that are paid pursuant to the Participant’s death or separation from service as provided in Subparagraph 4(b) above shall be paid to the Participant upon occurrence of the event giving rise to the right to payment or, in the case of Participant’s death, to the beneficiary of the Participant under the Plan or, if no beneficiary has been designated, to the Participant’s estate, providedthat, except as otherwise required under Federal securities laws or other applicable law, all Shares that are paid pursuant to Subparagraph 4(b) above shall be paid not more than 90 days following the occurrence of the event giving rise to the right to payment.

2

(d)    If the Participant has elected, pursuant to a timely Deferral Election, to defer receipt of the Shares until a separation from service as described in Subparagraph 4(b) above that occurs after the Maturity Date, all Shares shall be paid to the Participant in a lump sum within 30 days following such Participant’s separation from service.

(e)    Shares that become payable under this Agreement will be paid by the Company by the delivery to the Participant, or, in the case of the Participant’s death, to the Participant’s beneficiary or legal representative, of one or more certificates (or other indicia of ownership) representing shares of Williams Common Stock equal in number to the number of Shares otherwise payable under this Agreement. Notwithstanding the foregoing, to the extent permitted by Section 409A of the Code and the guidance issued by the Internal Revenue Service thereunder, if employment taxes become due or other withholding obligations arise upon the Participant’s becoming entitled to payment of Shares, the number of Shares necessary to cover minimum statutory withholding requirements may be used to satisfy such requirements upon such entitlement.

(f)    Upon conversion of RSUs into Shares under this Agreement, such RSUs shall be cancelled.

(g)    From and after the Effective Date, the Participant shall be entitled to accrue Dividend Equivalents with respect to each Share subject to the Award. Such Dividend Equivalents shall accrue in cash as and when dividends are paid to stockholders generally. Prior to payment, the Dividend Equivalents shall be subject to the same restrictions and limitations set forth herein with respect to the RSUs to which the Dividend Equivalents relate. The Dividend Equivalents accrued hereunder shall be paid in cash in lump sum (without interest) to the Participant (or beneficiary or estate, as applicable) as and when the Shares to which such Dividend Equivalents relate are paid pursuant to this Section 4.

5.    Definitions. As used in this Agreement, the following terms shall have the definitions set forth below.

(a)    “Affiliate” means all persons with whom the Company would be considered a single employer under Section 414(b) of the Code, and all persons with whom such person would be considered a single employer under Section 414(c) of the Code.    

(b)    “Separation from Service as an Independent Contractor” will occur upon the expiration of the contract (or in the case of more than one contract, all contracts) under which services are performed by a Non-Management Director for the Company or an Affiliate, but only if the expiration constitutes a good-faith and complete termination of the contractual relationship. An expiration of a contract shall not constitute a good faith and complete termination of the contractual relationship if the Company or an Affiliate anticipates either a renewal of a contractual relationship or the Non-Management Director’s becoming an employee. The determination of whether a Separation from Service as an Independent Contractor has occurred shall be governed by the provisions of Treasury Regulation § 1.409A-1, as amended.

6.    Other Provisions.

(a)    The Participant understands and agrees that payments under this Agreement shall not be used for, or in the determination of, any other payment or benefit under any continuing agreement, plan, policy, practice or arrangement providing for the making of any payment or the provision of any benefits to or for the Participant or the Participant’s beneficiaries or representatives, including, without limitation, any employment agreement, any change of control severance protection plan or any employee benefit plan as defined in Section 3(3) of ERISA, including, but not limited to qualified and non-qualified retirement plans.

(b)    The Participant agrees and understands that, upon payment of Shares under this Agreement, stock certificates (or other indicia of ownership) issued may be held as collateral for monies he/she owes to the Company or any of its Affiliates, including but not limited to personal loan(s) or the Company credit card debt.

3

(c)    RSUs, Shares and the Participant’s interest in RSUs and Shares may not be sold, assigned, transferred, pledged or otherwise disposed of or encumbered at any time prior to the Participant’s becoming entitled to payment of Shares under this Agreement.

(d)    With respect to the right to receive payment of the Shares under this Agreement, nothing contained herein shall give the Participant any rights that are greater than those of a general creditor of the Company.

(e)    The obligations of the Company under this Agreement are unfunded and unsecured. Each Participant shall have the status of a general creditor of the Company with respect to amounts due, if any, under this Agreement.

(f)    The parties to this Agreement intend that this Agreement meet the applicable requirements of Section 409A of the Code and recognize that it may be necessary to modify this Agreement and/or the Plan to reflect guidance under Section 409A of the Code issued by the Internal Revenue Service. Participant agrees that the Board shall have sole discretion in determining (i) whether any such modification is desirable or appropriate and (ii) the terms of any such modification.

(g)    The Participant hereby automatically becomes a party to this Agreement whether or not he or she accepts the Award electronically or in writing in accordance with procedures of the Board, its delegates or agents.

(h)    Nothing in this Agreement or the Plan shall confer upon the Participant the right to continue to serve as a director of the Company.

(i)    The Participant hereby acknowledges that nothing in this Agreement shall be construed as requiring the Board or Committee to allow a Domestic Relations Order with respect to this Award.

7.    Notices. All notices to the Company required hereunder shall be in writing and delivered by hand or by mail, addressed to The Williams Companies, Inc., One Williams Center, Tulsa, Oklahoma 74172, Attention: Stock Administration Department. Notices shall become effective upon their receipt by the Company if delivered in the foregoing manner. To direct the sale of any Shares issued under this Agreement, the Participant must contact Fidelity at http://netbenefits.fidelity.comor by telephone at 800-823-0217.

8.    Tax Consultation. You understand you will incur tax consequences as a result of acquisition or disposition of the Shares. You agree to consult with any tax consultants you think advisable in connection with the acquisition of the Shares and acknowledge that you are not relying, and will not rely, on the Company for any tax advice.

THE WILLIAMS COMPANIES, INC.

By:_________________________

Alan S. Armstrong

President and CEO

Participant: <@Name@>

SSN: <@SSN@>

4

EX-10.22

Exhibit 10.22

Date=Grant Date

TO:        <@Name@>

FROM:     Alan S. Armstrong

SUBJECT:    Stock Option Award

You have been selected to receive a stock option award. This award is subject to the terms and conditions of The Williams Companies, Inc. 2007 Incentive Plan, as amended and restated from time to time, and the Nonqualified Stock Option Agreement. Your stock option award is subject to graded vesting. You may view the vesting schedule for this award online.

This stock option award is granted to you in recognition of your role as an employee whose responsibilities and performance are critical to the attainment of long-term goals. This award and similar awards are made on a selective basis and are, therefore, to be kept confidential.

If you have any questions about this award, you may contact a dedicated Fidelity Stock Plan Representative at 1-800-823-0217.

1

Name: <@Name@>

SSN: <@SSN@>

THE WILLIAMS COMPANIES, INC.

2007 INCENTIVE PLAN

NONQUALIFIED STOCK OPTION AGREEMENT

This Nonqualified Stock Option Agreement (“Option Agreement”) contains the terms of the Option (as defined below) granted to you in this Option Agreement. Certain other terms of the Option are defined in the Plan (as defined below).

1.    Stock Options. Subject to the terms of The Williams Companies, Inc. 2007 Incentive Plan or any successor plan, including any supplements or amendments and restatements to it (the "Plan"), you have been granted the right (“Option”) to purchase from the Company <@Num+C @> shares of the Company's Common Stock, par value $1 per share (the "Shares") effective <@GrDt+C@>. (the “Effective Date”). Your Option is exercisable in whole or in part at the exercise price of <@P+C @> (the“Option Price”), the closing stock price on <@GrDt+C@>, and has an expiration date of <@ExDt @>. The Option will vest in one-third increments on February 22, 2017, February 22, 2018 and February 22, 2019 and is exercisable at such times and during such periods as are set forth in this Option Agreement and the Plan.

2.    Incorporation of Plan and Acceptance of Documents. The Plan applies as though it were included in this Option Agreement. Any capitalized word has a special meaning, which can be found either in the Plan or in this Option Agreement. You agree to accept as binding, conclusive and final all decisions and interpretations of the Committee upon any questions arising under the Plan or this Option Agreement. You acknowledge that you have received a copy of, or have online access to, the Plan and hereby automatically accept the Option subject to all the terms and provisions of the Plan and this Option Agreement. You further acknowledge and agree that you have received a copy of, or that you have online access to, the Plan prospectus, as updated from time to time, and you hereby acknowledge your automatic acceptance and receipt of such prospectus electronically.

3.    Exercise. Except as otherwise provided in this Option Agreement, you may exercise vested Options, in whole or in part, by delivering a notice of exercise to the Plan’s designated broker, showing the number of Shares for which the Option is being exercised, and providing payment in full for the Option Price. To give notice of exercise of an Option and receive instructions on payment of the Option Price, contact Fidelity at http://netbenefits.fidelity.comor by telephone at 800-823-0217. If you have not signed and delivered this Option Agreement prior to submitting a notification of such election, submission of your notification of election shall constitute your agreement with the terms and conditions of this Option Agreement. Notwithstanding the preceding sentence, the Company reserves the right to require your signature to this Option Agreement prior to accepting a notification of election to exercise this Option in whole or in part.

4.    Payment. You must pay the Option Price in full by any one or more of the following methods, subject to approval of the Committee in its sole discretion, (i) subject to applicable law, in cash through the sale of the Shares acquired on exercise of the Option through a broker-dealer to whom you have submitted an irrevocable notice of exercise and irrevocable instructions to deliver promptly to the Company the amount of sale or loan proceeds sufficient to pay the Option Price; (ii) in cash, by personal check or wire transfer; (iii) in Shares valued at their Fair Market Value on the date of exercise; (iv) withholding of Shares otherwise deliverable upon exercise valued at their Fair Market Value on the date of exercise; or (v) in any combination of the above methods. Certificates for any Shares used to pay the Option Price must be attested to in writing to the Company or delivered to the Company in negotiable form, duly endorsed in blank or with separate stock powers attached, and must be free and clear of all liens, encumbrances, claims and any other charges thereon of any kind.

5.    Tax Withholding. Whenever any Options are exercised under the terms of this Option Agreement, the Company will not deliver your Shares unless you remit or, in appropriate cases, agree to remit when due the minimum amount necessary to satisfy all of the Company’s federal, state and local withholding tax requirements relating to your Option or the Shares. The Committee may require you to satisfy these minimum withholding tax obligations by any (or a combination) of the following means as determined by the Committee in its sole discretion: (i) a cash payment; (ii) withholding from compensation otherwise payable to you; (iii) authorizing the Company to withhold from the Shares otherwise deliverable to you as a result of the exercise of an Option, a number of Shares having a Fair Market Value, as of the date the withholding tax obligation arises, less than or equal to the amount of the withholding obligation; or

1

(iv) delivering to the Company unencumbered Mature Shares having a Fair Market Value, as of the date the withholding tax obligation arises, less than or equal to the amount of the withholding obligation.

6.    Automatic Exercise. Unexercised, vested Options may be automatically exercised immediately prior to the expiration of such Options provided that the Fair Market Value of a Share on the date of automatic exercise exceeds the Option Price by at least $1.00 per Share. The Option Price and any applicable federal, state and local withholding tax requirements in connection with an automatic exercise will be satisfied by withholding from Shares otherwise deliverable upon exercise, a number of Shares having a Fair Market Value as of the date of exercise equal to the Option Price and applicable withholding obligations.

7.    Rights in the Event of Termination of Service.

(a) Rights in the Event of Termination of Service. If your service with the Company and its Affiliates is terminated for any reason other than death, retirement, Disability or for Cause as defined below, the Option, to the extent vested on the date of your termination, will remain exercisable for six months from the date of such termination (but may not be exercised later than the last day of the original Option Term).

(b) Rights in the Event of Death. If you die while in the service of the Company and its Affiliates, your Option will immediately vest, and the Option shall remain exercisable for a period of five years from the date of your death (but may not be exercised later than the last day of the original Option Term) by the person who becomes entitled to exercise your Option after your death (whether by will or by the laws of descent and distribution, or by means of a written beneficiary designation you filed with the Stock Administration Department before your death).

(c) Rights in the Event of Retirement or Disability. If your service with the Company and its Affiliates is terminated for retirement (as defined below) or Disability (as defined below), your Option will immediately vest, and the Option shall remain exercisable for five years from the date of your termination (but may not be exercised later than the last day of the original Option Term). The term “Disability” is defined in the Company’s long-term disability plan in which you participate or are eligible to participate, as determined by the Committee. Your service will “terminate for retirement” if your employment for the Company and its Affiliates is terminated after you have attained age fifty-five (55) and completed at least three (3) years of service with the Company or any of its Affiliates.

(d) Rights in the Event of Termination for Cause. If your service for the Company or an Affiliate terminates for Cause (as defined under the Plan and set forth below), any Option exercisable on or before such termination shall remain exercisable for a period of 30 days from the date of such termination (but may not be exercised later than the last day of the original Option Term). As of the date of this Agreement, the Plan defines “Cause” as (i) your willful failure to substantially perform your duties, other than any such failure resulting from a Disability; or (ii) your gross negligence or willful misconduct which results in a significantly adverse effect upon the Company or an Affiliate; or (iii) your willful violation or disregard of the Company's or an Affiliate’s code of business conduct or other published policy of the Company or an Affiliate; or (iv) your conviction of a crime involving an act of fraud, embezzlement, theft, or any other act constituting a felony involving moral turpitude or causing material harm, financial or otherwise, to the Company or an Affiliate. The Company may change the definition of Cause under the Plan at any time.

8.    Notices. All notices to the Company or to the Committee must be in writing and delivered by hand or by mail, addressed to The Williams Companies, Inc., One Williams Center, Tulsa, Oklahoma 74172, Attention: Stock Administration Department. Notices become effective upon their receipt by the Company if delivered as described in this section. To give notice of exercise of an Option and receive instructions on payment of the Option Price, contact Fidelity at http://netbenefits.fidelity.comor by telephone at 800-544-9354.

9.     Securities Law Compliance. The Company may, without liability for its good faith actions, place legend restrictions upon Shares obtained by exercising this Option and issue “stop transfer” instructions requiring compliance with applicable securities laws and the terms of this Option.

10.     No Right to Employment or Service. Nothing in the Option Agreement or the Plan shall interfere with or limit in any way the right of the Company or an Affiliate to terminate your employment or service at any time, nor confer upon you the right to continue in the employ of the Company and/or Affiliate.

1

11.    Domestic Relations Orders.    You hereby acknowledge that nothing in this Agreement shall be construed as requiring the Committee to allow a Domestic Relations Order with respect to this Option grant.

12.    Forfeiture and Clawback. Notwithstanding any other provision of the Plan or this Option Agreement to the contrary, by signing this Agreement, you acknowledge that any incentive-based compensation paid to you hereunder may be subject to recovery by the Company under any clawback policy that the Company may adopt from time to time, including without limitation any policy that the Company may be required to adopt under Section 954 of the Dodd-Frank Wall Street Reform and Consumer Protection Act and the rules and regulations of the U.S. Securities and Exchange Commission thereunder or the requirements of any national securities exchange on which the Shares may be listed. You further agree to promptly return any such incentive-based compensation which the Company determines it is required to recover from you under any such clawback policy.

13.    Tax Consultation. You understand you will incur tax consequences as a result of purchase or disposition of the Shares. You agree to consult with any tax consultants you think advisable in connection with the purchase of the Shares and acknowledge that you are not relying, and will not rely, on the Company for any tax advice.

14.    Confidentiality. The Participant acknowledges that this Award and similar awards are made on a selective basis and are, therefore, to be kept confidential.

THE WILLIAMS COMPANIES, INC.

By____________________________

Alan S. Armstrong            

President and CEO    

1

EX-10.23

Exhibit 10.23

Date=Grant Date

TO:        <@Name@>

FROM:    Alan S. Armstrong

SUBJECT:    2017Restricted Stock Unit Award

You have been selected to receive a restricted stock unit award. This award is subject to the terms and conditions of The Williams Companies, Inc. 2007 Incentive Plan, as amended and restated from time to time, and, the 2017 Restricted Stock Unit Agreement (the “Agreement”).

This award is granted to you in recognition of your role as an employee whose responsibilities and performance are critical to the attainment of long-term goals. This award and similar awards are made on a selective basis and are, therefore, to be kept confidential.

Subject to all of the terms of the Agreement, you will become entitled to payment of this award if you are an active employee of the Company on the third anniversary of the grant date.

If you have any questions about this award, you may contact a dedicated Fidelity Stock Plan Representative at 1-800-544-9354.

2017 RESTRICTED STOCK UNIT AGREEMENT

THIS RESTRICTED STOCK UNIT AGREEMENT (this “Agreement”), which contains the terms and conditions for the Restricted Stock Units (“Restricted Stock Units” or “RSUs”) referred to in the 2017 Restricted Stock Unit Award Letter delivered in hard copy or electronically to Participant (“2017 Award Letter”), is by and between THE WILLIAMS COMPANIES, INC., a Delaware corporation (the “Company”) and the individual identified on the last page hereof (the “Participant”).

1.    Grant of RSUs. Subject to the terms and conditions of The Williams Companies, Inc. 2007 Incentive Plan, as amended and restated from time to time (the “Plan”), this Agreement and the 2017 Award Letter, the Company hereby grants an award (the “Award”) to the Participant of <@Num+C @> RSUs effective <@GrDt+C@> (the “Effective Date”). The Award gives the Participant the opportunity to earn the right to receive the number ofshares of the Common Stock of the Company equal to the number of RSUs shown in the prior sentence, subject to adjustment under the terms of this Agreement. These shares are referred to in this Agreement as the “Shares.” Until the Participant both becomes vested in the Shares under the terms of Paragraph 4 and is paid such Shares under the terms of Paragraph 5, the Participant shall have no rights as a stockholder of the Company with respect to the Shares; provided, however, that the Participant shall have the right to earn Dividend Equivalents with respect to the RSUs awarded under this Agreement in accordance with Subparagraph 4(i) below.

2.    Incorporation of Plan and Acceptance of Documents. The Plan is hereby incorporated herein by reference, and all capitalized terms used herein which are not defined in this Agreement shall have the respective meanings set forth in the Plan. The Participant acknowledges that he or she has received a copy of, or has online access to, the Plan and hereby automatically accepts the RSUs subject to all the terms and provisions of the Plan and this Agreement. The Participant hereby further agrees that he or she has received a copy of, or has online access to, the Plan prospectus, as updated from time to time, and hereby acknowledges his or her automatic acceptance and receipt of such prospectus electronically.

3.    Committee Decisions and Interpretations. The Participant hereby agrees to accept as binding, conclusive and final all actions, decisions and/or interpretations of the Committee, its delegates, or agents, upon any questions or other matters arising under the Plan or this Agreement.

4.    Vesting; Legally Binding Rights.

(a)    Notwithstanding any other provision of this Agreement, (i) a Participant shall not be entitled to any payment of Shares under this Agreement unless and until such Participant obtains a legally binding right to such Shares and satisfies applicable vesting conditions for such payment and (ii) a Participant shall not be entitled to payment of any Dividend Equivalents unless and until such Participant obtains a legally binding right to, and satisfies applicable vesting conditions for payment of, the underlying Shares on which such Dividend Equivalents are payable.

(b)    Except as otherwise provided in Subparagraphs 4(c) – 4(h) below, the Participant shall vest in all Shares on the third anniversary of the Effective Date (the “Maturity Date”), but only if the Participant remains an active employee of the Company or any of its Affiliates through the Maturity Date.

(c)    If a Participant dies prior to the Maturity Date while an active employee of the Company or any of its Affiliates, the Participant shall vest in all Shares at the time of such death.

(d)    If a Participant becomes Disabled (as defined below) prior to the Maturity Date while an active employee of the Company or any of its Affiliates, the Participant shall vest in all Shares at the time the Participant becomes Disabled. For purposes of this Subparagraph 4(d), the Participant shall be considered Disabled if he or she (A) is unable to engage in any substantial gainful activity by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than twelve (12) months, or (B) is, by reason of any medically

2

determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than twelve (12) months, receiving income replacement benefits for a period of not less than three (3) months under an accident and health plan covering employees of the Participant’s employer. Notwithstanding the forgoing, all determinations of whether a Participant is Disabled shall be made in accordance with Section 409A of the Internal Revenue Code of 1986, as amended (the “Code”) and the guidance thereunder.

(e)    If the Participant qualifies for Retirement (as defined in (i) below) with the Company or any of its Affiliates prior to the Maturity Date due to such Retirement, at the time of such Participant’s ceasing being an active employee, the Participant shall vest in a pro rata number of the Shares as determined in accordance with this Subparagraph 4(e). The pro rata number referred to above shall be determined by multiplying the number of Shares subject to the Award by a fraction, the numerator of which is the number of full and partial months in the period that begins the month following the month that contains the Effective Date and ends on (and includes) the date of the Participant’s ceasing being an active employee of the Company and its Affiliates, and the denominator of which is the total number of full and partial months in the period that begins the month following the month that contains the Effective Date and ends on (and includes) the Maturity Date.

(i) For purposes of this Subparagraph 4(e), a Participant “qualifies for Retirement” only if such Participant experiences a Separation from Service (as defined in (ii) below) after attaining age fifty-five (55) and completing at least three (3) years of service with the Company or any of its Affiliates.

(ii) As used in this Agreement, “Separation from Service” means a Participant’s termination or deemed termination from employment with the Company and its Affiliates. For purposes of determining whether a Separation from Service has occurred, the employment relationship is treated as continuing intact while the Participant is on military leave, sick leave or other bona fide leave of absence if the period of such leave does not exceed six (6) months, or if longer, so long as the Participant retains a right to reemployment with his or her employer under an applicable statute or by contract. For this purpose, a leave of absence constitutes a bona fide leave of absence only if there is a reasonable expectation that the Participant will return to perform services for his or her employer. If the period of leave exceeds six (6) months and the Participant does not retain a right to reemployment under an applicable statute or by contract, the employment relationship will be deemed to terminate on the first date immediately following such six (6) month period. Notwithstanding the foregoing, if a leave of absence is due to any medically determinable physical or mental impairment that can be expected to result in death or can be expected to last for a continuous period of not less than six (6) months, and such impairment causes the Participant to be unable to perform the duties of the Participant’s position of employment or any substantially similar position of employment, a twenty-nine (29) month period of absence shall be substituted for such six (6) month period. For purposes of this Agreement, a Separation from Service occurs at the date as of which the facts and circumstances indicate either that, after such date: (A) the Participant and the Company reasonably anticipate the Participant will perform no further services for the Company and its Affiliates (whether as an employee or an independent contractor) or (B) that the level of bona fide services the Participant will perform for the Company and its Affiliates (whether as an employee or independent contractor) will permanently decrease to no more than twenty (20%) of the average level of bona fide services performed over the immediately preceding thirty-six (36) month period or, if the Participant has been providing services to the Company and its Affiliates for less than thirty-six (36) months, the full period over which the Participant has rendered services, whether as an employee or independent contractor. The determination of whether a Separation from Service has occurred shall be governed by the provisions of Treasury Regulation § 1.409A-1, as amended, taking into account the objective facts and circumstances with respect to the level of bona fide services performed by the Participant after a certain date.

(iii)    As used in this Agreement, “Affiliate” means all persons with whom the Company would be considered a single employer under Section 414(b) of the Code, and all persons with whom such person would be considered a single employer under Section 414(c) of the Code.

3

(f)    If the Participant experiences a Separation from Service prior to the Maturity Date within two years following a Change in Control, either voluntarily for Good Reason or involuntarily (other than due to Cause), the Participant shall vest in all of the Shares upon such Separation from Service.

(g)    If the Participant experiences an involuntary Separation from Service prior to the Maturity Date and the Participant either receives benefits under a severance pay plan or program maintained by the Company or receives benefits under a separation agreement with the Company, the Participant shall vest in all Shares upon such Separation from Service.

(h)    If the Participant experiences an involuntary Separation from Service prior to the Maturity Date due to a sale of a business or the outsourcing of any portion of a business, the Participant shall vest in all Shares upon such Separation from Service, but only if the Company or any of its Affiliates failed to make an offer of comparable employment, as defined by a severance pay plan or program maintained by the Company, to the Participant. For purposes of this Subparagraph 4(h), a Termination of Affiliation shall constitute an involuntary Separation from Service.

(i)If the Participant becomes entitled to payment of any Shares under this Agreement, the Participant shall also be entitled to receipt of Dividend Equivalents with respect to such Shares in an amount equal to the amount of dividends, if any, that would have been payable on such Shares if such Shares had been issued and outstanding from the date of this Agreement through the payment date of the Shares. Dividend Equivalents shall remain assets of the Company until paid hereunder and may, in the discretion of the Committee be paid in either cash or Shares. If Dividend Equivalents are paid in Shares, the number of Shares so payable will equal the total amount of Dividend Equivalents payable, if any, divided by the Fair Market Value of a Share on the payment date. No fractional Shares shall be issued.

5.    Payment of Shares and Dividend Equivalents.

(a)    The payment date for all Shares in which a Participant becomes vested pursuant to Subparagraph 4(b) above, and Dividend Equivalents in which the Participant becomes vested pursuant to Subparagraph 4(i), shall be the Maturity Date.

(b)     The payment date for all Shares in which a Participant becomes vested pursuant to Subparagraphs 4(c) and 4(d) above, and Dividend Equivalents in which the Participant becomes vested pursuant to Subparagraph 4(i), shall be no more than thirty (30) days after the date the Participant dies or becomes Disabled, as applicable. If such 30-day period spans two calendar years, then payment will be made in the later calendar year.

(c)    The payment date for all Shares in which the Participant becomes vested pursuant to Subparagraphs 4(e), 4(f), 4(g) and 4(h) above, and Dividend Equivalents in which the Participant becomes vested pursuant to Subparagraph 4(i), shall be no more than sixty (60) days following such Participant’s Separation from Service, unless otherwise provided in Subparagraph 5(e) below. If such 60-day period spans two calendar years, then payment will be made in the later calendar year.

(d)    Upon conversion of RSUs into Shares under this Agreement, such RSUs shall be cancelled. Shares that become payable under this Agreement and will be paid by the Company by the delivery to the Participant, or the Participant’s beneficiary or legal representative, of one or more certificates (or other indicia of ownership) representing shares of Williams Common Stock equal in number to the number of Shares otherwise payable under this Agreement less the number of Shares having a Fair Market Value, as of the date the withholding tax obligation arises, equal to the minimum statutory withholding requirements. Notwithstanding the foregoing, to the extent permitted by Section 409A of the Code and the guidance issued by the Internal Revenue Service thereunder, if federal employment taxes become due upon the Participant’s becoming entitled to payment of Shares, the number of Shares necessary to cover minimum statutory withholding requirements may, in the discretion of the Company, be used to satisfy such requirements upon such entitlement.

4

(e)    If the Participant was a “key employee” within the meaning of Section 409A(a)(B)(i) of the Code immediately prior to his or her Separation from Service, and such Participant vested in such Shares under Subparagraphs 4(e), (4)(f), 4(g) or 4(h) above, payment shall not be made sooner than six (6) months following the date such Participant experienced a Separation from Service. “Key employee” means an employee designated on an annual basis by the Company as of December 31 (the “Key Employee Designation Date”) as an employee meeting the requirements of Section 416(i) of Code utilizing the definition of compensation under Treasury Regulation § 1.415(c)-2(d)(2). A Participant designated as a “key employee” shall be a “key employee” for the entire twelve (12) month period beginning on April 1 following the Key Employee Designation Date.

6.    Other Provisions.

(a)    The Participant understands and agrees that payments under this Agreement shall not be used for, or in the determination of, any other payment or benefit under any continuing agreement, plan, policy, practice or arrangement providing for the making of any payment or the provision of any benefits to or for the Participant or the Participant’s beneficiaries or representatives, including, without limitation, any employment agreement, any change of control severance protection plan or any employee benefit plan as defined in Section 3(3) of ERISA, including, but not limited to qualified and non-qualified retirement plans.

(b)    The Participant agrees and understands that, subject to the limit expressed in clause (iii) of the following sentence, upon payment of Shares and Dividend Equivalents under this Agreement, stock certificates (or other indicia of ownership) issued may be held as collateral for monies he/she owes to Company or any of its Affiliates, including but not limited to personal loan(s), Company credit card debt, relocation repayment obligations or benefits from any plan that provides for pre-paid educational assistance. In addition, the Company may accelerate the time or schedule of a payment of vested Shares and Dividend Equivalents, and/or deduct from any payment of Shares and Dividend Equivalents to the Participant under this Agreement, or to his or her beneficiaries in the case of the Participant’s death, that number of Shares and Dividend Equivalents having a Fair Market Value at the date of such deduction to the amount of such debt as satisfaction of any such debt, provided that (i) such debt is incurred in the ordinary course of the employment relationship between the Company or any of its Affiliates and the Participant, (ii) the aggregate amount of any such debt-related collateral held or deduction made in any taxable year of the Company with respect to the Participant does not exceed $5,000, and (iii) the deduction of Shares and Dividend Equivalents is made at the same time and in the same amount as the debt otherwise would have been due and collected from the Participant.

(c)    Except as provided in Subparagraphs 4(c) through 4(h) above, in the event that the Participant experiences a Separation from Service prior to the Participant’s becoming vested in the Shares under this Agreement, RSUs subject to this Agreement and any right to Shares and Dividend Equivalents issuable hereunder shall be forfeited.

(d)    The Participant acknowledges that this Award and similar awards are made on a selective basis and are, therefore, to be kept confidential.

(e)    RSUs, Shares and Dividend Equivalents and the Participant’s interest in RSUs and Shares and Dividend Equivalents may not be sold, assigned, transferred, pledged or otherwise disposed of or encumbered at any time prior to both (i) the Participant’s becoming vested in such Shares and (ii) payment of such Shares and Dividend Equivalents under this Agreement.

(f)    If the Participant at any time forfeits any or all of the RSUs pursuant to this Agreement, the Participant agrees that all of the Participant’s rights to and interest in such RSUs and in Shares and Dividend Equivalents payable thereon, if any, issuable hereunder shall terminate upon forfeiture without payment of consideration.

(g)    The Committee shall determine whether an event has occurred resulting in the forfeiture of the Shares and Dividend Equivalents payable thereon in accordance with this Agreement, and all determinations of the Committee shall be final and conclusive.

5

(h)    With respect to the right to receive payment of the Shares and Dividend Equivalents under this Agreement, nothing contained herein shall give the Participant any rights that are greater than those of a general creditor of the Company.

(i)    The obligations of the Company under this Agreement are unfunded and unsecured. Each Participant shall have the status of a general creditor of the Company with respect to amounts due, if any, under this Agreement.

(j)    The parties to this Agreement intend that this Agreement meet the applicable requirements of Section 409A of the Code and recognize that it may be necessary to modify this Agreement and/or the Plan to reflect guidance under Section 409A of the Code issued by the Internal Revenue Service. Participant agrees that the Committee shall have sole discretion in determining (i) whether any such modification is desirable or appropriate and (ii) the terms of any such modification.

(k)    The Participant hereby automatically becomes a party to this Agreement whether or not he or she accepts the Award electronically or in writing in accordance with procedures of the Committee, its delegates or agents.

(l)    Nothing in this Agreement or the Plan shall interfere with or limit in any way the right of the Company or an Affiliate to terminate the Participant’s employment or service at any time, nor confer upon the Participant the right to continue in the employ of the Company and/or Affiliate.

(m)    The Participant hereby acknowledges that nothing in this Agreement shall be construed as requiring the Committee to allow a Domestic Relations Order with respect to this Award.

7.    Notices. All notices to the Company required hereunder shall be in writing and delivered by hand or by mail, addressed to The Williams Companies, Inc., One Williams Center, Tulsa, Oklahoma 74172, Attention: Stock Administration Department. Notices shall become effective upon their receipt by the Company if delivered in the foregoing manner. To direct the sale of any Shares issued under this Agreement, contact Fidelity at http://netbenefits.fidelity.comor by telephone at 800-544-9354.

8.    Tax Consultation. You understand you will incur tax consequences as a result of acquisition or disposition of the Shares and Dividend Equivalents. You agree to consult with any tax consultants you think advisable in connection with the acquisition of the Shares and Dividend Equivalents and acknowledge that you are not relying, and will not rely, on the Company for any tax advice.

THE WILLIAMS COMPANIES, INC.

By:_________________________

Alan S. Armstrong

President and CEO

Participant: <@Name

SSN: <@SSN @>

6

EX-10.24

Exhibit 10.24

Date=Grant Date

TO:        <@Name@>

FROM:    Alan S. Armstrong

SUBJECT:    2017Restricted Stock Unit Award

You have been granted a restricted stock unit award. This award, which is subject to adjustment under the 2017 Restricted Stock Unit Agreement (the “Agreement”), is granted to you in recognition of your role as a non-management director for The Williams Companies, Inc. It is granted and subject to the terms and conditions of The Williams Companies, Inc. 2007 Incentive Plan, as amended and restated from time to time, and the Agreement.

Subject to all of the terms of the Agreement, you will become entitled to payment of this award one year after the date on which this award is made.

If you have any questions about this award, you may contact a dedicated Fidelity Stock Plan Representative at 1-800-823-0217.

2017 RESTRICTED STOCK UNIT AGREEMENT

THIS RESTRICTED STOCK UNIT AGREEMENT (this “Agreement”), which contains the terms and conditions for the Restricted Stock Units (“Restricted Stock Units” or “RSUs”) referred to in the 2017 Restricted Stock Unit Award Letter delivered in hard copy or electronically to Participant (“2017 Award Letter”), is by and between THE WILLIAMS COMPANIES, INC., a Delaware corporation (the “Company”) and the individual identified on the last page hereof (the “Participant”).

1.    Grant of RSUs. Subject to the terms and conditions of The Williams Companies, Inc. 2007 Incentive Plan, as amended and restated from time to time (the “Plan”), this Agreement and the 2017 Award Letter, the Company hereby grants an award (the “Award”) to the Participant of <@Num+C @> RSUs effective <@GrDt+C@> (the “Effective Date”). The Award gives the Participant the right to receive the number ofshares of the Common Stock of the Company equal to the number of RSUs shown in the prior sentence, subject to adjustment under the terms of this Agreement. These shares are referred to in this Agreement as the “Shares.” Until the Participant receives payment of the Shares under the terms of Paragraph 4, the Participant shall have no rights as a stockholder of the Company with respect to the Shares, except for the right to earn Dividend Equivalents as set forth herein.

2.    Incorporation of Plan and Acceptance of Documents. The Plan is hereby incorporated herein by reference, and all capitalized terms used herein which are not defined in this Agreement shall have the respective meanings set forth in the Plan. The Participant acknowledges that he or she has received a copy of, or has online access to, the Plan and hereby automatically accepts the RSUs subject to all the terms and provisions of the Plan and this Agreement. The Participant hereby further agrees that he or she has received a copy of, or has online access to, the prospectus and hereby acknowledges his or her automatic acceptance and receipt of such prospectus electronically.

3.    Board Decisions and Interpretations. The Participant hereby agrees to accept as binding, conclusive and final all actions, decisions and/or interpretations of the Board, its delegates, or agents, upon any questions or other matters arising under the Plan or this Agreement.

4.    Payment of Shares; Dividend Equivalents.

(a)    Except as otherwise provided in Subparagraph 4(b) or 4(d) below, the Participant shall receive payment of all Shares on the date that is one year after the Effective Date (not including the Effective Date) (the “Maturity Date”). For example, if the Effective Date of the Participant’s award under this Agreement is August 4, 2017, the Maturity Date will be August 4, 2018.

(b)    If the Participant dies prior to the Maturity Date while serving as a Non-Management Director of the Company or his or her service as a Non-Management Director of the Company terminates for any other reason prior to the Maturity Date and such termination constitutes a “separation from service” as defined under Treasury Regulation § 1.409A-1, as amended, the Participant shall receive payment of all Shares at the time of such death or separation from service. In this regard, if at the time a Non-Management Director’s service as a Non-Management Director terminates, such Non-Management Director is also providing services to the Company or an Affiliate (as defined below) as an independent contractor, no separation from service by such Non-Management Director shall occur, and no Shares shall be payable to such Non-Management Director until the date on which such Non-Management Director has a Separation from Service as an Independent Contractor (as defined below) from the Company and its Affiliates.

(c)     All Shares that are paid pursuant to the Participant’s death or separation from service as provided in Subparagraph 4(b) above shall be paid to the Participant upon occurrence of the event giving rise to the right to payment or, in the case of Participant’s death, to the beneficiary of the Participant under the Plan or, if no beneficiary has been designated, to the Participant’s estate, providedthat, except as otherwise required under Federal securities laws or other applicable law, all Shares that are paid pursuant to Subparagraph 4(b) above in the event of death shall be paid not more than 90 days following such death, and all Shares that are paid pursuant to Subparagraph 4(b) above in the event of a separation from service shall be paid not more than 30

2

days following such separation from service. If such 90-day or 30-day period as applicable spans two calendar years, then payment will be made in the later calendar year.

(d)    If the Participant has elected, pursuant to a timely Deferral Election, to defer receipt of the Shares until a separation from service as described in Subparagraph 4(b) above that occurs after the Maturity Date, all Shares shall be paid to the Participant in a lump sum within 30 days following such Participant’s separation from service.

(e)    Shares that become payable under this Agreement will be paid by the Company by the delivery to the Participant, or, in the case of the Participant’s death, to the Participant’s beneficiary or legal representative, of one or more certificates (or other indicia of ownership) representing shares of Williams Common Stock equal in number to the number of Shares otherwise payable under this Agreement. Notwithstanding the foregoing, to the extent permitted by Section 409A of the Code and the guidance issued by the Internal Revenue Service thereunder, if employment taxes become due or other withholding obligations arise upon the Participant’s becoming entitled to payment of Shares, the number of Shares necessary to cover minimum statutory withholding requirements may be used to satisfy such requirements upon such entitlement.

(f)    Upon conversion of RSUs into Shares under this Agreement, such RSUs shall be cancelled.

(g)    From and after the Effective Date, the Participant shall be entitled to accrue Dividend Equivalents with respect to each Share subject to the Award. Such Dividend Equivalents shall accrue in cash as and when dividends are paid to stockholders generally. Prior to payment, the Dividend Equivalents shall be subject to the same restrictions and limitations set forth herein with respect to the RSUs to which the Dividend Equivalents relate. The Dividend Equivalents accrued hereunder shall be paid in cash in lump sum (without interest) to the Participant (or beneficiary or estate, as applicable) as and when the Shares to which such Dividend Equivalents relate are paid pursuant to this Section 4.

5.    Definitions. As used in this Agreement, the following terms shall have the definitions set forth below.

(a)    “Affiliate” means all persons with whom the Company would be considered a single employer under Section 414(b) of the Code, and all persons with whom such person would be considered a single employer under Section 414(c) of the Code.    

(b)    “Separation from Service as an Independent Contractor” will occur upon the expiration of the contract (or in the case of more than one contract, all contracts) under which services are performed by a Non-Management Director for the Company or an Affiliate, but only if the expiration constitutes a good-faith and complete termination of the contractual relationship. An expiration of a contract shall not constitute a good faith and complete termination of the contractual relationship if the Company or an Affiliate anticipates either a renewal of a contractual relationship or the Non-Management Director’s becoming an employee. The determination of whether a Separation from Service as an Independent Contractor has occurred shall be governed by the provisions of Treasury Regulation § 1.409A-1, as amended.

6.    Other Provisions.

(a)    The Participant understands and agrees that payments under this Agreement shall not be used for, or in the determination of, any other payment or benefit under any continuing agreement, plan, policy, practice or arrangement providing for the making of any payment or the provision of any benefits to or for the Participant or the Participant’s beneficiaries or representatives, including, without limitation, any employment agreement, any change of control severance protection plan or any employee benefit plan as defined in Section 3(3) of ERISA, including, but not limited to qualified and non-qualified retirement plans.

(b)    The Participant agrees and understands that, upon payment of Shares under this Agreement, stock certificates (or other indicia of ownership) issued may be held as collateral for monies he/she owes to the Company or any of its Affiliates, including but not limited to personal loan(s) or the Company credit card debt.

3

(c)    RSUs, Shares and the Participant’s interest in RSUs and Shares may not be sold, assigned, transferred, pledged or otherwise disposed of or encumbered at any time prior to the Participant’s becoming entitled to payment of Shares under this Agreement.

(d)    With respect to the right to receive payment of the Shares under this Agreement, nothing contained herein shall give the Participant any rights that are greater than those of a general creditor of the Company.

(e)    The obligations of the Company under this Agreement are unfunded and unsecured. Each Participant shall have the status of a general creditor of the Company with respect to amounts due, if any, under this Agreement.

(f)    The parties to this Agreement intend that this Agreement meet the applicable requirements of Section 409A of the Code and recognize that it may be necessary to modify this Agreement and/or the Plan to reflect guidance under Section 409A of the Code issued by the Internal Revenue Service. Participant agrees that the Board shall have sole discretion in determining (i) whether any such modification is desirable or appropriate and (ii) the terms of any such modification.

(g)    The Participant hereby automatically becomes a party to this Agreement whether or not he or she accepts the Award electronically or in writing in accordance with procedures of the Board, its delegates or agents.

(h)    Nothing in this Agreement or the Plan shall confer upon the Participant the right to continue to serve as a director of the Company.

(i)    The Participant hereby acknowledges that nothing in this Agreement shall be construed as requiring the Board or Committee to allow a Domestic Relations Order with respect to this Award.

7.    Notices. All notices to the Company required hereunder shall be in writing and delivered by hand or by mail, addressed to The Williams Companies, Inc., One Williams Center, Tulsa, Oklahoma 74172, Attention: Stock Administration Department. Notices shall become effective upon their receipt by the Company if delivered in the foregoing manner. To direct the sale of any Shares issued under this Agreement, the Participant must contact Fidelity at http://netbenefits.fidelity.comor by telephone at 800-823-0217.

8.    Tax Consultation. You understand you will incur tax consequences as a result of acquisition or disposition of the Shares. You agree to consult with any tax consultants you think advisable in connection with the acquisition of the Shares and acknowledge that you are not relying, and will not rely, on the Company for any tax advice.

THE WILLIAMS COMPANIES, INC.

By:_________________________

Alan S. Armstrong

President and CEO

Participant: <@Name@>

SSN: <@SSN@>

4

EX-10.25

Exhibit 10.25

Date=Grant Date

TO:        <@Name@>

FROM:     Alan S. Armstrong

SUBJECT:    Stock Option Award

You have been selected to receive a stock option award. This award is subject to the terms and conditions of The Williams Companies, Inc. 2007 Incentive Plan, as amended and restated from time to time, and the Nonqualified Stock Option Agreement. Your stock option award is subject to graded vesting. You may view the vesting schedule for this award online.

This stock option award is granted to you in recognition of your role as an employee whose responsibilities and performance are critical to the attainment of long-term goals. This award and similar awards are made on a selective basis and are, therefore, to be kept confidential.

If you have any questions about this award, you may contact a dedicated Fidelity Stock Plan Representative at 1-800-823-0217.

1

Name: <@Name@>

SSN: <@SSN@>

THE WILLIAMS COMPANIES, INC.

2007 INCENTIVE PLAN

NONQUALIFIED STOCK OPTION AGREEMENT

This Nonqualified Stock Option Agreement (“Option Agreement”) contains the terms of the Option (as defined below) granted to you in this Option Agreement. Certain other terms of the Option are defined in the Plan (as defined below).

1.    Stock Options. Subject to the terms of The Williams Companies, Inc. 2007 Incentive Plan or any successor plan, including any supplements or amendments and restatements to it (the "Plan"), you have been granted the right (“Option”) to purchase from the Company <@Num+C @> shares of the Company's Common Stock, par value $1 per share (the "Shares") effective <@GrDt+C@>. (the “Effective Date”). Your Option is exercisable in whole or in part at the exercise price of <@P+C @> (the“Option Price”), the closing stock price on <@GrDt+C@>, and has an expiration date of <@ExDt @>. The Option will vest in one-third increments each year for three years on the anniversary date of the Effective Date beginning the year following the Effective Date and is exercisable at such times and during such periods as are set forth in this Option Agreement and the Plan.

2.    Incorporation of Plan and Acceptance of Documents. The Plan applies as though it were included in this Option Agreement. Any capitalized word has a special meaning, which can be found either in the Plan or in this Option Agreement. You agree to accept as binding, conclusive and final all decisions and interpretations of the Committee upon any questions arising under the Plan or this Option Agreement. You acknowledge that you have received a copy of, or have online access to, the Plan and hereby automatically accept the Option subject to all the terms and provisions of the Plan and this Option Agreement. You further acknowledge and agree that you have received a copy of, or that you have online access to, the Plan prospectus, as updated from time to time, and you hereby acknowledge your automatic acceptance and receipt of such prospectus electronically.

3.    Exercise. Except as otherwise provided in this Option Agreement, you may exercise vested Options, in whole or in part, by delivering a notice of exercise to the Plan’s designated broker, showing the number of Shares for which the Option is being exercised, and providing payment in full for the Option Price. To give notice of exercise of an Option and receive instructions on payment of the Option Price, contact Fidelity at http://netbenefits.fidelity.comor by telephone at 800-823-0217. If you have not signed and delivered this Option Agreement prior to submitting a notification of such election, submission of your notification of election shall constitute your agreement with the terms and conditions of this Option Agreement. Notwithstanding the preceding sentence, the Company reserves the right to require your signature to this Option Agreement prior to accepting a notification of election to exercise this Option in whole or in part.

4.    Payment. You must pay the Option Price in full by any one or more of the following methods, subject to approval of the Committee in its sole discretion, (i) subject to applicable law, in cash through the sale of the Shares acquired on exercise of the Option through a broker-dealer to whom you have submitted an irrevocable notice of exercise and irrevocable instructions to deliver promptly to the Company the amount of sale or loan proceeds sufficient to pay the Option Price; (ii) in cash, by personal check or wire transfer; (iii) in Shares valued at their Fair Market Value on the date of exercise; (iv) withholding of Shares otherwise deliverable upon exercise valued at their Fair Market Value on the date of exercise; or (v) in any combination of the above methods. Certificates for any Shares used to pay the Option Price must be attested to in writing to the Company or delivered to the Company in negotiable form, duly endorsed in blank or with separate stock powers attached, and must be free and clear of all liens, encumbrances, claims and any other charges thereon of any kind.

5.    Tax Withholding. Whenever any Options are exercised under the terms of this Option Agreement, the Company will not deliver your Shares unless you remit or, in appropriate cases, agree to remit when due the minimum amount necessary to satisfy all of the Company’s federal, state and local withholding tax requirements relating to your Option or the Shares. The Committee may require you to satisfy these minimum withholding tax obligations by any (or a combination) of the following means as determined by the Committee in its sole discretion: (i) a cash payment; (ii) withholding from compensation otherwise payable to you; (iii) authorizing the Company to withhold from the Shares otherwise deliverable to you as a result of the exercise of an Option, a number of Shares having a Fair Market Value, as of the date the withholding tax obligation arises, less than or equal to the amount of the withholding obligation; or (iv) delivering to the Company unencumbered mature Shares having a Fair Market Value, as of the date the withholding tax obligation arises, less than or equal to the amount of the withholding obligation.

2

6.    Automatic Exercise. Unexercised, vested Options may be automatically exercised immediately prior to the expiration of such Options provided that the Fair Market Value of a Share on the date of automatic exercise exceeds the Option Price by at least $1.00 per Share. The Option Price and any applicable federal, state and local withholding tax requirements in connection with an automatic exercise will be satisfied by withholding from Shares otherwise deliverable upon exercise, a number of Shares having a Fair Market Value as of the date of exercise equal to the Option Price and applicable withholding obligations.

7.    Rights in the Event of Termination of Service.

(a) Rights in the Event of Termination of Service. If your service with the Company and its Affiliates is terminated for any reason other than death, retirement, Disability or for Cause as defined below, the Option, to the extent vested on the date of your termination, will remain exercisable for six months from the date of such termination (but may not be exercised later than the last day of the original Option Term).

(b) Rights in the Event of Death. If you die while in the service of the Company and its Affiliates, your Option will immediately vest, and the Option shall remain exercisable for a period of five years from the date of your death (but may not be exercised later than the last day of the original Option Term) by the person who becomes entitled to exercise your Option after your death (whether by will or by the laws of descent and distribution, or by means of a written beneficiary designation you filed with the Stock Administration Department before your death).

(c) Rights in the Event of Retirement or Disability. If your service with the Company and its Affiliates is terminated for retirement (as defined below) or Disability (as defined below), your Option will immediately vest, and the Option shall remain exercisable for five years from the date of your termination (but may not be exercised later than the last day of the original Option Term). The term “Disability” is defined in the Company’s long-term disability plan in which you participate or are eligible to participate, as determined by the Committee. Your service will “terminate for retirement” if your employment for the Company and its Affiliates is terminated after you have attained age fifty-five (55) and completed at least three (3) years of service with the Company or any of its Affiliates.

(d) Rights in the Event of Termination for Cause. If your service for the Company or an Affiliate terminates for Cause (as defined under the Plan and set forth below), any Option exercisable on or before such termination shall remain exercisable for a period of 30 days from the date of such termination (but may not be exercised later than the last day of the original Option Term). As of the date of this Agreement, the Plan defines “Cause” as (i) your willful failure to substantially perform your duties, other than any such failure resulting from a Disability; or (ii) your gross negligence or willful misconduct which results in a significantly adverse effect upon the Company or an Affiliate; or (iii) your willful violation or disregard of the Company's or an Affiliate’s code of business conduct or other published policy of the Company or an Affiliate; or (iv) your conviction of a crime involving an act of fraud, embezzlement, theft, or any other act constituting a felony involving moral turpitude or causing material harm, financial or otherwise, to the Company or an Affiliate. The Company may change the definition of Cause under the Plan at any time.

8.    Notices. All notices to the Company or to the Committee must be in writing and delivered by hand or by mail, addressed to The Williams Companies, Inc., One Williams Center, Tulsa, Oklahoma 74172, Attention: Stock Administration Department. Notices become effective upon their receipt by the Company if delivered as described in this section. To give notice of exercise of an Option and receive instructions on payment of the Option Price, contact Fidelity at http://netbenefits.fidelity.comor by telephone at 800-544-9354.

9.     Securities Law Compliance. The Company may, without liability for its good faith actions, place legend restrictions upon Shares obtained by exercising this Option and issue “stop transfer” instructions requiring compliance with applicable securities laws and the terms of this Option.

10.     No Right to Employment or Service. Nothing in the Option Agreement or the Plan shall interfere with or limit in any way the right of the Company or an Affiliate to terminate your employment or service at any time, nor confer upon you the right to continue in the employ of the Company and/or Affiliate.

11.    Domestic Relations Orders.    You hereby acknowledge that nothing in this Agreement shall be construed as requiring the Committee to allow a Domestic Relations Order with respect to this Option grant.

3

12.    Forfeiture and Clawback. Notwithstanding any other provision of the Plan or this Option Agreement to the contrary, by signing this Agreement, you acknowledge that any incentive-based compensation paid to you hereunder may be subject to recovery by the Company under any clawback policy that the Company may adopt from time to time, including without limitation any policy that the Company may be required to adopt under Section 954 of the Dodd-Frank Wall Street Reform and Consumer Protection Act and the rules and regulations of the U.S. Securities and Exchange Commission thereunder or the requirements of any national securities exchange on which the Shares may be listed. You further agree to promptly return any such incentive-based compensation which the Company determines it is required to recover from you under any such clawback policy.

13.    Tax Consultation. You understand you will incur tax consequences as a result of purchase or disposition of the Shares. You agree to consult with any tax consultants you think advisable in connection with the purchase of the Shares and acknowledge that you are not relying, and will not rely, on the Company for any tax advice.

14.    Confidentiality. The Participant acknowledges that this Award and similar awards are made on a selective basis and are, therefore, to be kept confidential.

THE WILLIAMS COMPANIES, INC.

By____________________________

Alan S. Armstrong            

President and CEO    

4

EX-10.38

EXHIBIT 10.38

The Williams Companies, Inc.

2007 Incentive Plan

Effective as of March 14, 2007, as subsequently amended

Amended and restated effective as of July 14, 2016

1

Table of Contents

Page

Article 1. - Effective Date, History, Objectives, and Duration1

1.1Effective Date    1

1.2Objectives of the Plan    1

1.3Duration of the Plan    1

Article 2. - Definitions1

2.1“Acquired Entity Award”    1

2.2“Affiliate”    1

2.3“Annual Meeting of Company Stockholders”    1

2.4“Award”    1

2.5“Award Agreement”    2

2.6“Base Amount”    2

2.7“Board”    2

2.8“CEO”    2

2.9“Code”    2

2.10“Committee” and “Management Committee”    2

2.11“Common Stock”    2

2.12“Controlled Affiliate”    2

2.13“Covered Employee”    2

2.14“Designated 162(m) Group”    2

2.15“Director Annual Grant”    2

2.16“Director Fees”    2

2.17“Disability”    2

2.18“Dividend Equivalent”    2

2.19“Eligible Person”    2

2.20“Exchange Act”    2

2.21“Equity Election”    2

2.22“Fair Market Value”    3

2.23“Grant Date”    3

2.24“Grantee”    3

2.25“Incentive Stock Option”    3

2.26“including” or “includes”    3

2.27“Non-Equity Incentive Award”    3

2.28“Non-Management Director”    3

2.29“Non-Qualified Stock Option”    3

2.30“Option Price”    3

2.31“Option Term”    3

2.32“Other Stock-Based Award”    3

2.33“Performance-Based Exception”    3

2.34“Performance Measures”    3

2.35“Performance Period”    3

2.36“Performance Share” and “Performance Unit”    3

2.37“Period of Restriction”    3

2.38“Person”    4

2.39“Restricted Stock Unit”    4

2.40“Rule 16b-3”    4

2.41“SEC”    4

2.42“Section 16 Non-Management Director”    4

2.43“Section 16 Person”    4

2.44“Share”    4

2.45“Shares of Restricted Stock” or “Restricted Stock”    4

2.46“Stock Appreciation Right” or “SAR”    4

2.47“Termination of Affiliation”    4

Article 3. - Administration4

i

3.1Committee.    4

3.2Powers of Committee    5

Article 4. - Shares Subject to the Plan, Maximum Awards, and 162(m) Compliance7

4.1Number of Shares Available for Grants    7

4.2Adjustments in Authorized Shares and Awards    7

4.3Compliance with Section 162(m) of the Code; Annual Individual Limitations    8

4.4Performance-Based Exception Under Section 162(m)    8

Article 5. - Eligibility and General Conditions of Awards10

5.1Eligibility    10

5.2Award Agreement    10

5.3General Terms and Termination of Affiliation    10

5.4Nontransferability of Awards    10

5.5Cancellation and Rescission of Awards    11

5.6Stand-Alone, Tandem and Substitute Awards    11

5.7Compliance with Rule 16b-3    11

(a)Reformation to Comply with Exchange Act Rules    11

(b)Rule 16b-3 Administration    12

5.8Deferral of Award Payouts    12

Article 6. - Stock Options12

6.1Grant of Options    12

6.2Award Agreement    12

6.3Option Price; No Repricing    12

6.4Grant of Incentive Stock Options    13

6.5Payment    13

Article 7. - Shares of Restricted Stock14

7.1Grant of Shares of Restricted Stock    14

7.2Award Agreement    14

7.3Consideration for Shares of Restricted Stock    14

7.4Effect of Forfeiture    14

7.5Escrow; Legends    15

7.6Voting Rights; Dividends and Distributions    15

Article 8. - Restricted Stock Units15

8.1Grant of Restricted Stock Units    15

8.2Delivery and Limitations    15

8.3Forfeiture    15

Article 9. - Performance Units and Performance Shares15

9.1Grant of Performance Units and Performance Shares    15

9.2Value/Performance Goals    15

(a)Performance Unit    16

(b)Performance Share    16

9.3Earning of Performance Units and Performance Shares    16

9.4Forfeiture    16

Article 10. - Stock Appreciation Rights16

10.1Grant of SARs    16

10.2Award Agreement    16

10.3Payment of SAR Amount    17

10.4Forfeiture    17

10.5No Repricing    17

Article 11. - Other Stock-Based Awards17

Article 12. - Non-Equity Incentive Awards17

ii

Article 13. - Change in Control17

13.1Acceleration of Exercisability and Lapse of Restrictions    17

13.2Definitions    18

(a)“Cause”    18

(b)“Change Date”    18

(c)“Change in Control”    18

(d)“Good Reason”    19

(e)“Incumbent Directors”    20

(f)“Retirement”    20

(g)“Surviving Corporation”    20

(h)“Voting Securities”    20

Article 14. - Non-Management Director Awards21

14.1Director Annual Grant.    21

(a)Automatic Grant of Director Annual Grant    21

(b)Prorated Director Annual Grant    21

(c)Non-Management Director Status    22

(d)Vesting and Payment    22

14.2Election to Receive Director Fees in Shares or Restricted Stock Units in Lieu of Cash    22

(a)Payment of Director Fees in Shares    22

(b)Payment of Director Fees in Restricted Stock Units    22

14.3Deferral Elections    22

(a)Timing of Deferral Elections    23

(b)Content of Deferral Elections    23

(c)Deferral Account    23

(d)Settlement of Deferral Accounts    23

14.4Insufficient Number of Shares    23

14.5Non-Forfeitability    24

14.6No Duplicate Payments    24

Article 15. - Amendment, Modification, and Termination24

15.1Amendment, Modification, and Termination    24

15.2Awards Previously Granted    24

Article 16. - Withholding24

16.1Mandatory Tax Withholding.    24

16.2Notification under Code Section 83(b)    24

Article 17. - Additional Provisions25

17.1Successors    25

17.2Severability    25

17.3Requirements of Law    25

17.4Securities Law Compliance    25

17.5No Rights as a Stockholder    25

17.6Nature of Payments    25

17.7Non-Exclusivity of Plan    26

17.8Governing Law    26

17.9Share Certificates    26

17.10Unfunded Status of Awards; Creation of Trusts    26

17.11Employment    26

17.12Participation    26

17.13Military Service    26

17.14Construction; Gender and Number    26

17.15Headings    26

17.16Obligations    26

17.17No Right to Continue as Director    27

17.18Code Section 409A Compliance    27

17.19Recoupment Policy    27

iii

THE WILLIAMS COMPANIES, INC.
2007 INCENTIVE PLAN

(Effective as of March 14, 2007, as subsequently amended)
(Amended and restated effective as of July 14, 2016)

(Termination Date: May 22, 2024)

Article 1. - Effective Date, History, Objectives, and Duration

1.1Effective Date. The Williams Companies, Inc., a Delaware corporation (the “Company”), established an incentive compensation plan known as The Williams Companies, Inc. 2007 Incentive Plan (the “Plan”) effective March 14, 2007 (the “Effective Date”); which Plan was subsequently amended from time to time. From and after the Effective Date, no further grants or awards shall be made under The Williams Companies, Inc. 2002 Incentive Plan, as amended from time to time, The Williams Companies, Inc. Stock Plan for Nonofficer Employees, The Williams International Stock Plan, The Williams Companies, Inc. 1996 Stock Plan for Non-Employee Directors or The Williams Companies, Inc. 1996 Stock Plan, as amended.

1.2Objectives of the Plan. The Plan is intended (a) to allow selected employees and officers of the Company and its Affiliates to acquire or increase equity ownership in the Company, thereby strengthening their commitment to the success of the Company and stimulating their efforts on behalf of the Company, and to assist the Company and its Affiliates in attracting new employees and officers and retaining existing employees and officers, (b) to provide Non-Equity Incentive Award (as defined below) opportunities to employees in the Designated 162(m) Group (as defined below) that are competitive with those of other major corporations, (c) to optimize the profitability and growth of the Company and its Affiliates through incentives which are consistent with the Company’s goals, (d) to provide Grantees with an incentive for excellence in individual performance, (e) to promote teamwork among employees, officers, and Non-Management Directors (as defined below), and (f) to attract and retain highly qualified persons to serve as Non-Management Directors and to promote ownership by such Non-Management Directors of a greater proprietary interest in the Company, thereby aligning such Non-Management Directors’ interests more closely with the interests of the Company’s stockholders.

1.3Duration of the Plan. The Plan commenced on the Effective Date and shall remain in effect, subject to the right of the Board of Directors of the Company (the “Board”) to amend or terminate the Plan at any time pursuant to Article 15 hereof, until all Shares subject to it shall have been purchased or acquired according to the Plan’s provisions, or, if earlier, May 22, 2024. Termination of the Plan will not affect the rights and obligations of the Grantees and the Company arising under Awards theretofore granted and then in effect.

Article 2. - Definitions

Whenever used in the Plan, the following terms shall have the meanings set forth below:

2.1    “Acquired Entity Award” has the meaning set forth in Section 5.6.

2.2    “Affiliate” means any Person that directly or indirectly, through one or more intermediaries, controls, or is controlled by or is under common control with the Company.

2.3    “Annual Meeting of Company Stockholders” has the meaning set forth in Section 14.1.

2.4    “Award” means Options (including Non-Qualified Stock Options and Incentive Stock Options), Shares of Restricted Stock, Restricted Stock Units, Performance Units (which may be paid in cash), Performance Shares, Stock Appreciation Rights, Other Stock-Based Awards, Non-Equity Incentive Awards or Director Annual Grants granted under the Plan.

1

2.5    “Award Agreement” means the written or electronic agreement or other instrument as may be approved from time to time by the Committee or Management Committee (as applicable) by which an Award shall be evidenced. An Award Agreement may be in the form of either (a) an agreement to be either executed by both the Grantee and the Company (or an authorized representative of the Company) or delivered and acknowledged electronically as the Committee shall determine or (b) certificates, notices or similar instruments as approved by the Committee or Management Committee (as applicable).

2.6    “Base Amount” means with respect to a Stock Appreciation Right, the amount with respect to which the appreciation in the value of a Share shall be measured over the period beginning with the Grant Date and ending on the date of exercise of such Stock Appreciation Right.

2.7    “Board” has the meaning set forth in Section 1.3.

2.8    “CEO” means the Chief Executive Officer of the Company.

2.9    “Code” means the Internal Revenue Code of 1986, as amended from time to time. References to a particular section of the Code include references to regulations and rulings thereunder and to successor provisions.

2.10    “Committee” and “Management Committee” have the respective meanings set forth in Article 3.

2.11    “Common Stock” means the common stock, $1.00 par value, of the Company.

2.12    “Controlled Affiliate” means any Person that directly or indirectly, through one or more intermediaries, is controlled by the Company.

2.13    “Covered Employee” means a Grantee who, as of the date that the value of an Award is recognizable as income, is one of the group of “covered employees,” within the meaning of Section 162(m) of the Code, with respect to the Company.

2.14    “Designated 162(m) Group” means that group of persons whom the Committee believes may be Covered Employees with respect to a current or future fiscal year of the Company.

2.15    “Director Annual Grant” means an Award made to a Non-Management Director under Section 14.1.

2.16    “Director Fees” has the meaning set forth in Section 14.2.

2.17    “Disability” means, unless otherwise defined in an Award Agreement, or as otherwise determined under procedures established by the Committee for purposes of the Plan, for purposes of the exercise of an Incentive Stock Option, a disability within the meaning of Section 22(e)(3) of the Code, and for all other purposes, disability as defined in the Company’s long-term disability plan in which the Grantee participates or is eligible to participate, as determined by the Committee.

2.18    “Dividend Equivalent” means a right to receive or accrue, to the extent provided under the respective Award Agreement, payments equal to dividends or property on a specified number of Shares.

2.19    “Eligible Person” means any employee (including any officer) of the Company or an Affiliate, except that only employees in the Designated 162(m) Group shall be Eligible Persons with respect to Non-Equity Incentive Awards.

2.20    “Exchange Act” means the Securities Exchange Act of 1934, as amended from time to time. References to a particular section of the Exchange Act include references to successor provisions.

2.21    “Equity Election” has the meaning set forth in Section 14.2.

2

2.22    “Fair Market Value” means (a) with respect to any property other than Shares, the fair market value of such property determined by such methods or procedures as shall be established from time to time by the Committee, and (b) with respect to Shares, unless otherwise determined in the good faith discretion of the Committee, as of any date: (i) the closing price on the date of determination reported in The Wall Street Journal (or an equivalent alternate or successor) (or, if no sale of Shares was reported for such date, on the most recent trading day prior to such date on which a sale of Shares was reported); (ii) if the Shares are not listed on the New York Stock Exchange, the closing price of the Shares on such other national exchange on which the Shares are principally traded or as reported by the Nasdaq Global Select or Global Market System, or similar securities market, or if no such quotations are available, the average of the high bid and low asked quotations in the over-the-counter market as reported by the Nasdaq Capital Market or similar securities market; or (iii) in the event that there shall be no public market for the Shares, the fair market value of the Shares as determined (which determination shall be conclusive) in good faith by the Committee.

2.23    “Grant Date” means the date on which an Award is granted or, in the case of a grant to an Eligible Person, such later date as specified in advance by the Committee.

2.24    “Grantee” means an Eligible Person or Non-Management Director who has been granted an Award.

2.25    “Incentive Stock Option” means an Option that is intended to meet the requirements of Section 422 of the Code.

2.26    “including” or “includes” means “including, without limitation,” or “includes, without limitation,” respectively.

2.27    “Non-Equity Incentive Award” means an Award granted to a person in the Designated 162(m) Group that is not granted or payable in Shares.

2.28    “Non-Management Director” means a member of the Board who is not an employee of the Company or any Affiliate.

2.29    “Non-Qualified Stock Option” means an Option that is not an Incentive Stock Option. 2.30 “Option” means an option granted under Article 6 of the Plan.

2.30    “Option Price” means the price at which a Share may be purchased by a Grantee pursuant to the exercise of an Option.

2.31    “Option Term” means the period beginning on the Grant Date of an Option and ending on the date such Option expires, terminates or is cancelled.

2.32    “Other Stock-Based Award” means a right, granted under Article 11 of the Plan, that relates to or is valued by reference to Shares or other Awards relating to Shares.

2.33    “Performance-Based Exception” means the performance-based exception from the tax deductibility limitations of Section 162(m) of the Code contained in Section 162(m)(4)(C) of the Code (including the special provisions for options thereunder).

2.34    “Performance Measures” has the meaning set forth in Section 4.4.

2.35    “Performance Period” means the time period over which performance goals shall be determined, but may not be less than one year.

2.36    “Performance Share” and “Performance Unit” have the respective meanings set forth in Article 9.

2.37    “Period of Restriction” means the period during which Shares of Restricted Stock or Restricted Stock Units are subject to forfeiture if the conditions specified in the Award Agreement are not satisfied.

3

2.38    “Person” means any individual, sole proprietorship, partnership, joint venture, limited liability company, trust, unincorporated organization, association, corporation, institution, public benefit corporation, entity or government instrumentality, division, agency, body or department.

2.39    “Restricted Stock Unit” means a right, granted in accordance with Article 8 hereof, to receive a Share or cash payment equal to the value thereof, subject to such Period of Restriction as the Committee shall determine.

2.40    “Rule 16b-3” means Rule 16b-3 promulgated by the SEC under the Exchange Act, as amended from time to time, together with any successor rule.

2.41    “SEC”means the United States Securities and Exchange Commission, or any successor thereto.

2.42    “Section 16 Non-Management Director” means a Non-Management Director who satisfies the requirements to qualify as a “non-employee director” under Rule 16b-3.

2.43    “Section 16 Person” means a person who is subject to potential liability under Section 16(b) of the Exchange Act with respect to transactions involving equity securities of the Company.

2.44    “Share” means a share of Common Stock, and such other securities of the Company as may be substituted or resubstituted for Shares pursuant to Section 4.2 hereof.

2.45    “Shares of Restricted Stock” or “Restricted Stock” means Shares that are subject to forfeiture if the Grantee does not satisfy the conditions specified in the Award Agreement applicable to such Shares.

2.46    “Stock Appreciation Right” or “SAR” has the meaning set forth in Section 10.1 hereof.

2.47    “Termination of Affiliation” occurs on the first day on which an individual is for any reason no longer providing services to the Company or any Affiliate in the capacity of an employee or officer, or with respect to an individual who is solely an employee or officer of an Affiliate, the first day on which such entity ceases to be an Affiliate of the Company. Notwithstanding the foregoing, except as otherwise provided in the Award Agreement with respect to such Award, with respect to an Award subject to Section 409A of the Code, “Termination of Affiliation” means a “separation from service” as defined in Section 409A of the Code and guidance thereunder.

Article 3.- Administration

3.1Committee.

(a)    Subject to Articles 14 and 15, and to Section 3.2, the Plan shall be administered by a committee (the “Committee”). Except to the extent the Board reserves administrative powers to itself or appoints a different committee to administer the Plan, the Committee shall be (i) the Board, with respect to all Non-Management Directors, (ii) the Compensation Committee of the Board, with respect to all executive officers of the Company (which term shall have the same meaning as the term “officer” as defined in Rule 16a-1(f) promulgated under the Exchange Act and shall in any event include all of the members of the Company’s Executive Officer Team (“EOT”)) and any other Eligible Person with respect to whom it elects to act as the Committee, and (iii) except as the Committee may provide, if the CEO is a member of the Board, a committee consisting of the CEO, with respect to any Eligible Person other than an executive officer of the Company. In addition, to the extent the Board considers it desirable to comply with Rule 16b-3 or meet the Performance-Based Exception, the Committee shall consist of two or more directors of the Company, all of whom qualify both as “outside directors” within the meaning of Section 162(m) of the Code and as Section 16 Non-Management Directors (the “Independent Committee”). The number of members of the Committee shall from time to time be increased or decreased, and shall be subject to such conditions, in each case as the Board deems appropriate to permit transactions in Shares pursuant to the Plan to satisfy such conditions of Rule 16b-3 and the Performance-Based Exception as then in effect.

4

(b)    The Board or the Compensation Committee may, by resolution, appoint and delegate to another committee of one or more officers of the Company (including the CEO) (a “Management Committee”) any or all of the authority of the Board or the Committee, as applicable, with respect to Awards to Grantees other than Grantees who are executive officers of the Company, Non-Management Directors, and/or are persons in the Designated 162(m) Group for whom the Board or the Compensation Committee desires to have the Performance-Based Exception apply and/or are Section 16 Persons at the time any such delegated authority is exercised; provided, however, that the resolution so authorizing such Management Committee shall specify the total number of Shares that may be subject to Awards (if any) such Management Committee may award pursuant to such delegated authority, and any such Award shall be subject to the form(s) of Award Agreement theretofore approved by the Compensation Committee. Any delegation of authority pursuant to this Section 3.1(b) shall comply with the requirements of applicable law, including Section 157(c) of the General Corporation Law of the State of Delaware to the extent applicable.

(c)    Unless the context requires otherwise, any references herein to “Committee” include references to the Board, the Compensation Committee of the Board, the Management Committee, the Independent Committee (if distinct from any of the foregoing) or the CEO, as applicable. For avoidance of doubt, notwithstanding any provision of the Plan to the contrary, any action taken by the Compensation Committee of the Board shall be treated as a valid action of the Committee, except as limited by the terms of the Board’s delegation of authority to the Compensation Committee of the Board or in the event that such action would violate applicable law.

3.2Powers of Committee. Subject to and consistent with the provisions of the Plan (including Article 14 and any limitations in scope of authority established in accordance with Section 3.1 above), the Committee has full and final authority and sole discretion as follows:

(a)    to determine when, to whom and in what types and amounts Awards should be granted;

(b)    to grant Awards in any number and amount to Eligible Persons, and to determine the terms and conditions applicable to each Award (including the number of Shares or the amount of cash or other property to which an Award will relate, any exercise price, grant price, Base Amount or purchase price, any limitation or restriction, any schedule for or performance conditions relating to the earning of the Award or the lapse of limitations, forfeiture restrictions, restrictions on exercisability or transferability, any performance goals including those relating to the Company and/or an Affiliate and/or any division thereof and/or an individual, and/or vesting based on the passage of time, based in each case on such considerations as the Committee shall determine); provided that, other than with respect to Awards to Non-Management Directors, no Award of Options, Stock Appreciation Rights or Other Stock-Based Awards that are valued based on appreciation in the value of a Share following the Grant Date may vest or be settled in full prior to the twelfth month following its Grant Date (with partial vesting prior to such date permitted), except that the Committee may (i) provide for the vesting satisfaction and/or lapse of some or all conditions under any such Award in the event of the applicable Eligible Person’s death, disability, Retirement, involuntary separation of service, or in connection with a Change in Control or (ii) grant Awards of Options or Stock Appreciation Rights that may vest or be settled in full prior to the twelfth month following its Grant Date so long as the aggregate number of Shares subject to such Awards does not exceed five percent (5%) of the total share reserve set forth in Section 4.1 below;

(c)    to determine the benefit payable under any Performance Unit, Performance Share, Other Stock-Based Award or Non-Equity Incentive Award and to determine whether any performance or vesting conditions have been satisfied;

(d)    to determine whether or not specific Awards shall be granted in connection with other specific Awards, and if so, whether they shall be exercisable cumulatively with, or alternatively to, such other specific Awards and all other matters to be determined in connection with an Award;

(e)    to determine the Option Term;

(f)    to determine the amount, if any, that a Grantee shall pay for Shares of Restricted Stock, when Shares of Restricted Stock shall be forfeited and whether such Shares shall be held in escrow;

5

(g)    to determine whether, to what extent and under what circumstances an Award may be settled in, or the exercise price of an Award may be paid in, cash, Shares, other Awards or other property, or an Award may be accelerated, vested, canceled, forfeited or surrendered or any terms of the Award may be waived, and to accelerate the exercisability of, and to accelerate or waive any or all of the terms and conditions applicable to, any Award or any group of Awards for any reason and at any time;

(h)    to determine with respect to Awards whether, to what extent and under what circumstances cash, Shares, other Awards, other property and other amounts payable with respect to an Award will be deferred either automatically (whether to limit loss of deductions pursuant to Section 162(m) of the Code or otherwise), at the election of the Committee or at the election of the Grantee;

(i)    to construe and interpret the Plan and to make all determinations, including factual determinations, necessary or advisable for the administration of the Plan;

(j)    to make, amend, suspend, waive and rescind rules and regulations relating to the Plan;

(k)    to appoint such agents as the Committee may deem necessary or advisable to administer the Plan;

(l)    to determine the terms and conditions of all Award Agreements applicable to Eligible Persons and Non-Management Directors (which need not be identical) and, with the consent of the Grantee, to amend any such Award Agreement at any time, among other things, to permit transfers of such Awards to the extent permitted by the Plan; provided that the consent of the Grantee shall not be required for any amendment (i) which does not materially adversely affect the rights of the Grantee, or (ii) which is necessary or advisable (as determined by the Committee) to carry out the purpose of the Award as a result of any new applicable law or change in an existing applicable law, or (iii) to the extent the Award Agreement specifically permits amendment without consent, or (iv) provided for or specifically contemplated in the Plan (such as Section 6.4 or Article 13);

(m)    to make such adjustments or modifications to Awards or to adopt such sub-plans for Grantees working outside the United States as are advisable to fulfill the purposes of the Plan (including to comply with local law);

(n)    to impose such additional terms and conditions upon the grant, exercise or retention of Awards as the Committee may, before or concurrently with the grant thereof, deem appropriate, including, as applicable, limiting the percentage of Awards which may from time to time be exercised by a Grantee;

(o)    to make adjustments in the terms and conditions of, and the criteria in, Awards in recognition of unusual or nonrecurring events (including events described in Section 4.2) affecting the Company or an Affiliate or the financial statements of the Company or an Affiliate, or in response to changes in applicable laws, regulations or accounting principles; provided that in no event shall such adjustment increase the amount payable under an Award for a person included in the Designated 162(m) Group for whom the Committee desires to have the Performance-Based Exception apply so as to cause the Performance-Based Exception to be unavailable;

(p)    to correct any defect or supply any omission or reconcile any inconsistency, and to construe and interpret the Plan, the rules and regulations, and Award Agreement or any other instrument entered into or relating to an Award under the Plan; and

(q)    to take any other action with respect to any matters relating to the Plan for which it is responsible and to make all other decisions and determinations as may be required under the terms of the Plan or as the Committee may deem necessary or advisable for the administration of the Plan.

Any action of the Committee with respect to the Plan shall be final, conclusive and binding on all persons, including the Company, its Affiliates, any Grantee, any person claiming any rights under the Plan from or through any Grantee, and stockholders, except to the extent the Committee may subsequently modify, or take further action not consistent with, its prior action. If not specified in the Plan, the time at which the Committee must or may make any

6

determination shall be determined by the Committee, and any such determination may thereafter be modified by the Committee. The express grant of any specific power to the Committee, and the taking of any action by the Committee, shall not be construed as limiting any power or authority of the Committee. The Committee may delegate to officers or managers of the Company or any Affiliate the authority, subject to such terms as the Committee shall determine, to perform specified functions under the Plan (subject to Sections 3.1(b), 4.3, 4.4 and 5.7(b)).

Article 4.- Shares Subject to the Plan, Maximum Awards, and 162(M) Compliance

4.1Number of Shares Available for Grants. Subject to adjustment as provided in Section 4.2, the number of Shares hereby reserved for delivery under the Plan shall be forty million (40,000,000). The number of Shares available for delivery pursuant to Incentive Stock Options shall be the number set forth in the first sentence of this Section 4.1.

If any Shares subject to an Award granted hereunder are forfeited or such Award is settled in cash or otherwise terminates without the delivery of such Shares, the Shares subject to such Award, to the extent of any such forfeiture, settlement or termination, shall again be available for grant under the Plan. Except with respect to Shares associated with Options or SARs, the aggregate number of shares available for delivery under the Plan at any time shall not be reduced by Shares retained or withheld by the Company to pay the withholding taxes related to an Award. Except with respect to Shares associated with Options or SARs, Shares that have been delivered (either actually or by attestation) to the Company in payment or satisfaction of the purchase price or tax withholding obligation of an Award shall be available for delivery under this Plan. Notwithstanding anything herein to the contrary, Shares retained, withheld by or delivered to the Company to pay the exercise price of an Option or the withholding taxes related to an Option or SAR shall not be made available again for delivery under the Plan. Shares delivered pursuant to the Plan may be, in whole or in part, authorized and unissued Shares, or treasury Shares, including Shares repurchased by the Company for purposes of the Plan.

Notwithstanding the foregoing, the limit set forth in this Section 4.1 shall not be reduced by any Shares issued pursuant to Acquired Entity Awards granted in assumption of, or in substitution for, an outstanding award previously granted by an Acquired Entity, so long as the terms of the acquisition of such awards previously granted by an Acquired Entity do not expressly provide for the issuance of Shares authorized under this Section 4.1.

4.2Adjustments in Authorized Shares and Awards. In the event of any dividend or other distribution (whether in the form of cash, Shares, or other property, but excluding regular, quarterly cash dividends), recapitalization, forward or reverse stock split, subdivision, consolidation or reduction of capital, reorganization, merger, consolidation, scheme of arrangement, split-up, spin-off or combination involving the Company or repurchase or exchange of Shares or other securities of the Company or other rights to purchase Shares or other securities of the Company, or other similar corporate transaction or event that affects the Shares, provided that any such transaction or event referred to heretofore does not involve the receipt of consideration by the Company, then the Committee shall, in such manner as it deems equitable in order to prevent dilution or enlargement of the benefits or potential benefits intended to be made available under the Plan, adjust (a) the number and type of Shares (or other securities or property) with respect to which Awards may be granted, (b) the number and type of Shares (or other securities or property) subject to outstanding Awards, (c) the grant or exercise price or Base Amount with respect to any applicable Award or, if deemed appropriate, make provision for a cash payment to the holder of an outstanding Award, (d) the number and kind of outstanding Shares of Restricted Stock or relating to any other outstanding Award in connection with which Shares are issued or otherwise subject, (e) the number of Shares with respect to which Awards may be granted to a Grantee, as set forth in Section 4.3, (f) the number and type of Shares (or other securities or property) as to which Awards may be settled, and (g) the number of Shares subject to outstanding Restricted Stock or Restricted Stock Units granted under Article 14; provided, in each case, that with respect to Awards of Incentive Stock Options intended as of their Grant Date to qualify as Incentive Stock Options, no such adjustment shall be authorized to the extent that such adjustment would cause the Plan to violate Section 422(b)(1) of the Code; and provided further that the number of Shares subject to any Award denominated in Shares shall always be a whole number. By way of example and not limitation, neither the conversion of any convertible

7

securities of the Company nor any open market purchase of Shares by the Company shall be treated as a transaction that “does not involve the receipt of consideration” by the Company.

4.3Compliance with Section 162(m) of the Code; Annual Individual Limitations. During any calendar year, no Grantee may be granted Awards (other than Awards that cannot be satisfied in Shares) with respect to more than three million five hundred thousand (3,500,000) Shares, subject to adjustment as provided in Section 4.2. The maximum potential value of Awards to be settled in cash or property (other than Shares) that may be granted with respect to any calendar year (or the Company’s fiscal year, if the Company’s fiscal year is not the calendar year) to any Grantee included in the Designated 162(m) Group (regardless of when such Award is settled) shall not exceed Fifteen Million Dollars ($15,000,000.00). (Thus, Awards to be settled in cash or property (other than Shares) with a Performance Period (or other period of time explicitly or implicitly utilized to determine the value to be provided to the Grantee) over more than one calendar year (or fiscal year) may exceed the one-year grant limit in the prior sentence at the time of payment or settlement so long as the total maximum potential value does not exceed the one-year limit multiplied by the number of calendar years (or fiscal years) or portions thereof over which the value of such Award is determined.)

4.4Performance-Based Exception Under Section 162(m). Unless and until the Committee proposes for stockholder vote and stockholders approve a change in the general performance measures set forth in this Section 4.4, for Awards (other than Options or SARs) designed to qualify for the Performance-Based Exception, the objective Performance Measure(s) shall be chosen from among the following:

(a)    Earnings (either in the aggregate or on a per-share basis);

(b)    Net income;

(c)    Operating income;

(d)    Operating profit;

(e)    Cash flow;

(f)    Stockholder returns (including return on assets, investments, equity, or gross sales) (including income applicable to common stockholders or other class of stockholders);

(g)    Return measures (including return on assets, equity, or sales);

(h)    Earnings before or after either, or any combination of, interest, taxes, depreciation or amortization (EBITDA);

(i)    Gross revenues;

(j)    Share price (including growth measures and total stockholder return or attainment by the Shares of a specified value for a specified period of time);

(k)    Reductions in expense levels in each case, where applicable, determined either on a Company-wide basis or in respect of any one or more operating areas;

(l)    Net economic value;

(m)    Market share;

(n)    Annual net income to common stock;

8

(o)    Earnings per share;

(p)    Annual cash flow provided by operations;

(q)    Changes in annual revenues;

(r)    Strategic business criteria, consisting of one or more objectives based on meeting specified revenue, market penetration, geographic business expansion goals, objectively identified project milestones, production volume levels, cost targets, and goals relating to acquisitions or divestitures;

(s)    Economic value added;

(t)    Sales;

(u)    Costs;

(v)    Results of customer satisfaction surveys;

(w)    Results of employee satisfaction and/or engagement surveys;

(x)    Employee turnover;

(y)    Aggregate product price and other product price measures;

(z)    Safety record;

(aa)    Service reliability;

(bb)    Operating and maintenance cost management;

(cc)    Energy production availability performance measures;

(dd)    Debt rating;

and/or

(ee) Market share;

provided that subsections (a) through (g) may be measured on a pre- or post-tax basis; and provided further that the Committee may, on the Grant Date of an Award intended to comply with the Performance-Based Exception, and in the case of other grants, at any time, provide that the formula for such Award may include or exclude items to measure specific objectives, such as losses from discontinued operations, extraordinary gains or losses, the cumulative effect of accounting changes, acquisitions or divestitures, foreign exchange impacts and any unusual, nonrecurring gain or loss. For Awards intended to comply with the Performance-Based Exception, the Committee shall set the Performance Measures within the time period prescribed by Section 162(m) of the Code. The levels of performance required with respect to Performance Measures may be expressed in absolute or relative levels and may be based upon a set increase, set positive result, maintenance of the status quo, set decrease or set negative result, and may be measured annually, cumulatively over a period of years or over such other period determined by the Committee. Performance Measures may differ for Awards to different Grantees. The Committee shall specify the weighting (which may be the same or different for multiple objectives) to be given to each Performance Measure for purposes of determining the final amount payable with respect to any such Award. Any one or more of the Performance Measures may apply to the Grantee, to a department, unit, operating area or function within the Company or any one or more Affiliates; or to the Company and/or any one or more Affiliates; and may apply either alone or relative to the performance of other businesses or individuals (including industry or general market indices).

9

The Committee shall have the discretion to adjust the determinations of the degree of attainment of the pre-established performance goals; provided that Awards which are designed to qualify for the Performance-Based Exception may not be adjusted upward (the Committee shall retain the discretion to adjust such Awards downward) so as to cause the Performance-Based Exception to be unavailable. The Committee may not delegate any responsibility with respect to Awards intended to qualify for the Performance-Based Exception. All determinations by the Committee as to the achievement of the Performance Measure(s) shall be in writing prior to payment of the Award.

In the event that applicable laws change to permit Committee discretion to alter the governing performance measures without obtaining stockholder approval of such changes, and still qualify for the Performance-Based Exception, the Committee shall have sole discretion to make such changes without obtaining stockholder approval.

For purposes of Section 4.3 and this Section 4.4 (and any other provisions of the Plan for which compliance with Section 162(m) of the Code is intended), references to “Committee” means the Compensation Committee of the Board or, if a separate body, the Independent Committee.

Article 5.- Eligibility and General Conditions of Awards

5.1Eligibility. Awards may be granted to any Eligible Person or Non-Management Director, whether or not he or she has previously received an Award; provided that only persons included in the Designated 162(m) Group shall be Eligible Persons with respect to Non-Equity Incentive Awards made under the Plan and Non-Management Directors may only receive Awards granted under Article 14 of the Plan. A prospective employee of the Company or an Affiliate may be granted an Award so long as the Grant Date does not occur prior to the date that such Person commences employment or the performance of services for the Company or an Affiliate.

5.2Award Agreement. To the extent not set forth in the Plan, the terms and conditions of each Award shall be set forth in an Award Agreement.

5.3General Terms and Termination of Affiliation. The Committee may impose on any Award or the exercise or settlement thereof, at the Grant Date or, subject to the provisions of Section 15.2, thereafter, such additional terms and conditions not inconsistent with the provisions of the Plan as the Committee shall determine, including terms requiring forfeiture, acceleration or pro-rata acceleration of Awards in the event of a Termination of Affiliation by the Grantee. Except as may be required under the Delaware General Corporation Law, Awards may be granted for no consideration other than prior and future services. Except as otherwise determined by the Committee pursuant to this Section 5.3, all Awards that have not been exercised and that are subject to (a) a risk of forfeiture, (b) deferral by the Committee (and not voluntary deferral by the Grantee), (c) vesting or (d) unexpired Performance Periods at the time of a Termination of Affiliation, shall be forfeited to the Company.

5.4Nontransferability of Awards.

(a)    Each Award and each right under any Award shall be exercisable only by the Grantee during the Grantee’s lifetime, or, if permissible under applicable law, by the Grantee’s guardian or legal representative or by a transferee receiving such Award pursuant to a domestic relations order (“DRO”).

(b)    No Award (prior to the time, if applicable, Shares are delivered in respect of such Award), and no right under any Award, may be assigned, alienated, pledged, attached, sold or otherwise transferred or encumbered by a Grantee otherwise than by will or by the laws of descent and distribution (or in the case of Shares of Restricted Stock, to the Company) or pursuant to a DRO, and any such purported assignment, alienation, pledge, attachment, sale, transfer or encumbrance shall be void and unenforceable against the Company and any Affiliate; provided that the designation of a beneficiary shall not constitute an assignment, alienation, pledge, attachment, sale, transfer or encumbrance.

10

(c)    Notwithstanding subsections (a) and (b) above, to the extent provided in the Award Agreement, Director Annual Grants, Restricted Stock Units, Stock Appreciation Rights and Awards other than Incentive Stock Options and Non-Equity Incentive Awards, may be transferred to one or more trusts or persons during the lifetime of the Grantee in connection with the Grantee’s estate planning, and may be exercised by such transferee in accordance with the terms of such Award. If so determined by the Committee, a Grantee may, in the manner established by the Committee, designate a beneficiary or beneficiaries to exercise the rights of the Grantee, and to receive any distribution with respect to any Award upon the death of the Grantee. A transferee, beneficiary, guardian, legal representative or other person claiming any rights under the Plan from or through any Grantee shall be subject to and consistent with the provisions of the Plan and any applicable Award Agreement, except to the extent the Plan and Award Agreement otherwise provide with respect to such persons, and to any additional restrictions or limitations deemed necessary or appropriate by the Committee.

(d)    Nothing herein shall be construed as requiring the Committee to honor a DRO except as required under the respective Award Agreement or to the extent required under applicable law.

5.5Cancellation and Rescission of Awards. Unless the Award Agreement specifies otherwise, the Committee may cancel, rescind, suspend, withhold, or otherwise limit or restrict any unexercised Award at any time if the Grantee is not in compliance with all applicable provisions of the Award Agreement and the Plan or if the Grantee has a Termination of Affiliation.

5.6Stand-Alone, Tandem and Substitute Awards.

(a)    Awards granted under the Plan may, in the discretion of the Committee, be granted either alone or in addition to, in tandem with, or in substitution for, any other Award granted under the Plan or any other plan of the Company or any Affiliate; provided that if the stand-alone, tandem or substitute Award is intended to qualify for Performance-Based Exception, it must separately satisfy the requirements of the Performance-Based Exception. In connection with the Company’s acquisition, however effected, of another corporation or entity (the “Acquired Entity”) or the assets thereof, the Committee may, at its discretion, grant Awards (“Substitute Awards”) associated with the stock or other equity interest in such Acquired Entity (“Acquired Entity Award”) held by a Grantee immediately prior to such Acquisition in order to preserve for Grantee the economic value of all or a portion of such Acquired Entity Award on such terms as the Committee determines necessary to achieve preservation of economic value. If an Award is granted in substitution for another Award or any non-Plan award or benefit, the Committee shall require the surrender of such other Award or non-Plan award or benefit in consideration for the grant of the new Award. Awards granted in addition to or in tandem with other Awards or non-Plan awards or benefits may be granted either at the same time as or at a different time from the grant of such other Awards or non-Plan awards or benefits.

(b)    The Committee may, in its discretion and on such terms and conditions as the Committee considers appropriate in the circumstances, grant Awards under the Plan in substitution for stock and stock-based Awards held by employees of another corporation who become employees of the Company or an Affiliate as the result of a merger or consolidation or other combination of the employing corporation with the Company or an Affiliate or the acquisition by the Company or an Affiliate of property or stock of the employing corporation.

5.7Compliance with Rule 16b-3.

(a)Reformation to Comply with Exchange Act Rules. To the extent the Committee determines that a grant or other transaction by a Section 16 Person should comply with applicable provisions of Rule 16b-3 (except for transactions exempted under alternative Exchange Act rules), the Committee shall take such actions as necessary to make such grant or other transaction so comply, and if any provision of this Plan or any Award Agreement relating to a given Award does not comply with the requirements of Rule 16b-3 as then applicable to any such grant or transaction, such provision will be construed or deemed amended, if the Committee so determines, to the extent necessary to conform to the then applicable requirements of Rule 16b-3 without the consent of or notice to the affected Section 16 Person.

11

(b)Rule 16b-3 Administration. Any function relating to a Section 16 Person shall be performed solely by the Committee or the Board if necessary to ensure compliance with applicable requirements of Rule 16b-3, to the extent the Committee determines that such compliance is desired. Each member of the Committee or person acting on behalf of the Committee shall be entitled to, in good faith, rely or act upon any report or other information furnished to him by any officer, manager or other employee of the Company or any Affiliate, the Company’s independent certified public accountants or any executive compensation consultant or attorney or other professional retained by the Company to assist in the administration of the Plan. For purposes of Section 5.7(a) and this Section 5.7(b), references to “Committee” means the Compensation Committee of the Board or, if a separate body, the Independent Committee.

5.8Deferral of Award Payouts. The Committee may permit or require a Grantee to defer receipt of the payment of cash or the delivery of Shares that would otherwise be due by virtue of the lapse or waiver of restrictions with respect to Shares of Restricted Stock, the satisfaction of any requirements or goals with respect to Performance Units or Performance Shares, the lapse or waiver of the Period of Restriction for Restricted Stock Units, or the lapse or waiver of restrictions with respect to Other Stock-Based Awards. The Committee may also require such a deferral of receipt in order to avoid non-deductibility of any amounts associated with such Award or to comply with the requirements of applicable law. If any such deferral is required or permitted, the Committee shall, in its sole discretion, establish rules and procedures for such payment deferrals. Except as otherwise provided in an Award Agreement or this Section 5.8, any payment of any Shares that are subject to such deferral shall be made or delivered to the Grantee upon the Grantee’s Termination of Affiliation. Notwithstanding anything herein to the contrary, in no event will any deferral or payment of a deferred number of Shares or any other payment with respect to any Award be allowed if the Committee determines, in its sole discretion, that the deferral would result in the imposition of the additional tax under Section 409A(a)(1)(B) of the Code.

Article 6.- Stock Options

6.1Grant of Options. Subject to and consistent with the provisions of the Plan, Options may be granted to any Eligible Person in such number, and upon such terms, and at any time and from time to time as shall be determined by the Committee.

6.2Award Agreement. Each Option grant shall be evidenced by an Award Agreement that shall specify the Option Price, the Option Term (which shall be for a period of not more than ten (10) years from its Grant Date), the number of Shares to which the Option pertains, the time or times at which such Option shall be exercisable and such other provisions as the Committee shall determine; provided further that notwithstanding anything to the contrary, any Award to an Eligible Person of an Option shall, to the extent applicable, include the minimum vesting requirement set forth in Section 3.2(b).

6.3Option Price; No Repricing. The Option Price of an Option under this Plan shall be determined in the sole discretion of the Committee, and, except with respect to an Option granted as an Acquired Entity Award, shall be at least equal to 100% of the Fair Market Value of a Share on the Grant Date. Subject to the adjustment under Section 4.2, neither the Committee nor the Board shall have the authority or discretion to reduce, directly or indirectly, the Option Price of any outstanding Option without stockholder approval, including, without limitation, by (a) canceling previously awarded Options and regranting them with a lower Option Price, (b) at any time when the Option Price of a previously awarded Option is above the Fair Market Value of a Share, exchanging or buying out such previously granted Option for a payment in cash, Shares or other Award, notwithstanding any authority otherwise granted the Committee or the Board under the Plan or (c) take any other action with respect to an Option that would be treated as a repricing under the rules and regulations of the principal securities exchange on which the Shares are traded.

12

6.4Grant of Incentive Stock Options. At the time of the grant of any Option, the Committee may in its discretion designate that such Option (or portion thereof) shall be made subject to additional restrictions to permit it to qualify as an Incentive Stock Option. Any Option (or portion thereof) designated as an Incentive Stock Option:

(a)    shall be granted only to an employee of the Company or a Subsidiary Corporation (as defined below);

(b)    shall have an Option Price of not less than 100% of the Fair Market Value of a Share on the Grant Date, and, if granted to a person who owns capital stock (including stock treated as owned under Section 424(d) of the Code) possessing more than 10% of the total combined voting power of all classes of capital stock of the Company or any Subsidiary Corporation (a “10% Owner”), have an Option Price not less than 110% of the Fair Market Value of a Share on its Grant Date;

(c)    shall be for a period of not more than 10 years (five years if the Grantee is a 10% Owner) from its Grant Date, and shall be subject to earlier termination as provided herein or in the applicable Award Agreement;

(d)    shall not have an aggregate Fair Market Value (as of the Grant Date) of the Shares with respect to which Incentive Stock Options (whether granted under the Plan or any other stock option plan of the Grantee’s employer or any parent or Subsidiary Corporation (“Other Plans”)) are exercisable for the first time by such Grantee during any calendar year (“Current Grant”), determined in accordance with the provisions of Section 422 of the Code, which exceeds $100,000 (the “$100,000 Limit”);

(e)    shall require the Grantee to notify the Committee of any disposition of any Shares delivered pursuant to the exercise of the Incentive Stock Option under the circumstances described in Section 421(b) of the Code (relating to holding periods and certain disqualifying dispositions) (a “Disqualifying Disposition”), within 10 days of such a Disqualifying Disposition; and

(f)    shall by its terms not be assignable or transferable other than by will or the laws of descent and distribution and may be exercised, during the Grantee’s lifetime, only by the Grantee; provided that the Grantee may, to the extent provided in the Plan in any manner specified by the Committee, designate in writing a beneficiary to exercise his or her Incentive Stock Option after the Grantee’s death.

For purposes of this Section 6.4, “Subsidiary Corporation” means a corporation other than the Company in an unbroken chain of corporations beginning with the Company if, at the time of granting the Option, each of the corporations other than the last corporation in the unbroken chain owns stock possessing 50% or more of the total combined voting power of all classes of stock in one of the other corporations in such chain. Notwithstanding the foregoing and Section 3.2, the Committee may, without the consent of the Grantee, at any time before the exercise of an Option (whether or not an Incentive Stock Option), take any action necessary to prevent such Option from being treated as an Incentive Stock Option.

Notwithstanding anything in this Section 6.4 to the contrary, Options designated as Incentive Stock Options shall not be eligible for treatment under the Code as Incentive Stock Options (and will be deemed to be Non-Qualified Stock Options) to the extent that either (a) the aggregate Fair Market Value of the Shares (determined on the Grant Date) with respect to the Current Grant and all Incentive Stock Options previously granted under the Plan and any Other Plans which are exercisable for the first time during a calendar year would exceed the $100,000 Limit, or (b) such Options otherwise remain exercisable but are not exercised within three (3) months of Termination of Affiliation (or such other period of time provided in Section 422 of the Code).

6.5Payment. Except as otherwise provided by the Committee in an Award Agreement or otherwise, Options shall be exercised by the delivery of a written notice of exercise to the Company or its designee, setting forth the number of Shares with respect to which the Option is to be exercised, accompanied by full payment for the Shares made by any one or more of the following means, subject to the approval of the Committee:

13

(a)    cash, personal check or wire transfer;

(b)    Shares, valued at their Fair Market Value on the date of exercise;

(c)    withholding of Shares otherwise deliverable upon exercise valued at their Fair Market Value on the date of exercise; or

(d)    subject to applicable law, pursuant to procedures previously approved by the Company, in cash through the sale of the Shares acquired on exercise of the Option through a broker-dealer to whom the Grantee has submitted an irrevocable notice of exercise and irrevocable instructions to deliver promptly to the Company the amount of sale or loan proceeds sufficient to pay for such Shares, together with, if requested by the Company, the mandatory amount of federal, state, local and foreign withholding taxes payable by Grantee by reason of such exercise.

Article 7.- Shares of Restricted Stock

7.1Grant of Shares of Restricted Stock. Subject to and consistent with the provisions of the Plan, the Committee, at any time and from time to time, may grant Shares of Restricted Stock to any Eligible Person in such amounts as the Committee shall determine.

7.2Award Agreement. Each grant of Shares of Restricted Stock shall be evidenced by an Award Agreement that shall specify the Period(s) of Restriction, the number of Shares of Restricted Stock granted, and such other provisions as the Committee shall determine. The Committee may impose such conditions and/or restrictions on any Shares of Restricted Stock granted pursuant to the Plan as it may deem advisable, including restrictions based upon the achievement of specific performance goals, time-based restrictions on vesting following the attainment of the performance goals, and/or restrictions under applicable securities laws; provided that such conditions and/or restrictions may lapse, if so determined by the Committee, in the event of the Grantee’s Termination of Affiliation due to death, Disability, normal or approved early retirement, or involuntary termination by the Company or an Affiliate without “cause.” Except as otherwise determined by the Committee, upon Termination of Affiliation during the applicable Period of Restriction, Shares of Restricted Stock that are at that time subject to forfeiture shall be forfeited and automatically reacquired by the Company.

7.3Consideration for Shares of Restricted Stock. The Committee shall determine the amount, if any, that a Grantee shall pay for Shares of Restricted Stock, subject to the following sentence. Except with respect to Shares of Restricted Stock that are treasury shares, for which no payment need be required, the Committee shall require the Grantee to pay at least the par value of a Share for each Share of Restricted Stock. Such payment shall be made in full in cash and/or other consideration permissible by applicable law (including prior and/or future services, which shall be considered a “benefit to the corporation” within the meaning of Section 152 of the Delaware General Corporation Law) by the Grantee before the delivery of the Shares under terms determined by the Committee.

7.4Effect of Forfeiture. If Shares of Restricted Stock are forfeited, and if the Grantee was required to pay for such Shares with cash or property, the Grantee shall be deemed to have resold such Shares to the Company at a price equal to the lesser of (a) the amount paid in cash or property by the Grantee for such Shares, or (b) the Fair Market Value of such Shares at the close of business on the date of such forfeiture. The Company shall pay to the Grantee the deemed sale price as soon as is administratively practical. Such Shares shall cease to be outstanding, and shall no longer confer on the Grantee thereof any rights as a stockholder of the Company, from and after the date of the event causing the forfeiture, whether or not the Grantee accepts the Company’s tender of payment for such Shares.

14

7.5Escrow; Legends. The Committee may provide that any certificates for any Shares of Restricted Stock (a) shall be held (together with one or more stock powers executed in blank by the Grantee) in escrow by the Secretary of the Company until such Shares become nonforfeitable or are forfeited and/or (b) shall bear an appropriate legend restricting the transfer of such Shares. If any Shares of Restricted Stock become nonforfeitable, the Company shall cause certificates for such Shares to be delivered without such legend, except as may be required under applicable law.

7.6Voting Rights; Dividends and Distributions. Unless otherwise determined by the Committee, individuals holding Shares of Restricted Stock granted hereunder may exercise full voting rights with respect to those shares during the Period of Restriction. Individuals in whose name Shares of Restricted Stock are granted shall be entitled to receive all dividends and other distributions paid with respect to those Shares. Unless otherwise determined by the Committee, such dividends and other distributions shall be paid once the Period of Restriction has ended; provided, however, in no event will dividends or other distributions be paid during the Performance Period with respect to unearned Awards of Restricted Stock that are subject to performance-based vesting criteria.

Article 8.- Restricted Stock Units

8.1Grant of Restricted Stock Units. Subject to and consistent with the provisions of the Plan, the Committee, at any time and from time to time, may grant Restricted Stock Units to any Eligible Person, in such amount and upon such terms as the Committee shall determine.

8.2Delivery and Limitations. Delivery of Shares will occur upon expiration of the Period of Restriction specified for the Award of Restricted Stock Units by the Committee. In addition, an Award of Restricted Stock Units shall be subject to such limitations as the Committee may impose, which limitations may lapse at the end of the Period of Restriction of such Restricted Stock Units or at other specified times, separately or in combination, in installments or otherwise, as the Committee shall determine at the time of grant or thereafter. A Grantee awarded Restricted Stock Units will have no voting rights in respect of such Restricted Stock Units. The Committee may award a Grantee Dividend Equivalents in respect of Restricted Stock Units that are the subject of an Award Agreement, as specified in and according to the terms of such Award Agreement. Unless otherwise determined by the Committee, such Dividend Equivalents shall be paid once the Period of Restriction or other applicable limitations or restrictions have ended; provided, however, in no event will Dividend Equivalents be paid during the Performance Period with respect to unearned Restricted Stock Units that are subject to performance-based vesting criteria.

8.3Forfeiture. Except as otherwise determined by the Committee, upon Termination of Affiliation during the applicable Period of Restriction, Restricted Stock Units that are at that time subject to forfeiture shall be forfeited.

Article 9.- Performance Units and Performance Shares

9.1Grant of Performance Units and Performance Shares. Subject to and consistent with the provisions of the Plan, Performance Units or Performance Shares may be granted to any Eligible Person in such amounts and upon such terms, and at any time and from time to time, as shall be determined by the Committee.

9.2Value/Performance Goals. The Committee shall set performance goals in its discretion which, depending on the extent to which they are met, will determine the number or value of Performance Units or Performance Shares that will be paid to the Grantee. With respect to Covered Employees and to the extent the Committee deems it appropriate to comply with Section 162(m) of the Code, all performance goals shall be objective Performance Measures as set forth in Section 4.4 satisfying the requirements for the Performance-Based Exception, and shall be set by the Committee within the time period prescribed by Section 162(m) of the Code and related regulations.

15

(a)    Performance Unit. Each Performance Unit shall have an initial value that is established by the Committee at the time of grant.

(b)    Performance Share. Each Performance Share shall have an initial value equal to the Fair Market Value of a Share at the close of business on the Grant Date.

9.3Earning of Performance Units and Performance Shares. After the applicable Performance Period has ended, the holder of Performance Units or Performance Shares shall be entitled to payment based on the level of achievement of performance goals set by the Committee. If a Performance Unit or Performance Share Award is intended to comply with the Performance-Based Exception, the Committee shall certify the level of achievement of the performance goals in writing before the Award is settled.

At the discretion of the Committee, the settlement of Performance Units or Performance Shares may be in cash, Shares of equivalent value, or in some combination thereof, as set forth in the Award Agreement or otherwise determined by the Committee.

Other than with respect to Grantees in the Designated 162(m) Group, if a Grantee is promoted, demoted or transferred to a different operating area of the Company during a Performance Period, then, to the extent the Committee determines the performance goals or Performance Period are no longer appropriate, the Committee may adjust, change, eliminate or cancel the performance goals or the applicable Performance Period as it deems appropriate in order to make them appropriate and comparable to the initial performance goals or Performance Period.

The Committee may award a Grantee Dividend Equivalents in respect of Performance Units that are the subject of an Award Agreement, as specified in and according to the terms of such Award Agreement. Any such Dividend Equivalents shall not be paid except with respect to those Performance Units that have been earned based on the level of achievement of applicable performance goals. Grantees to whom Performance Shares are granted shall be entitled to receive all dividends and other distributions paid only with respect to those Shares that have been earned based on the level of achievement of performance goals. In addition, a Grantee may, at the discretion of the Committee, be entitled to exercise his or her voting rights with respect to such Shares to the extent such Shares have been issued to the Grantee.

9.4Forfeiture. Except as otherwise determined by the Committee, upon Termination of Affiliation any unvested and/or unearned Performance Units and Performance Shares shall be forfeited.

Article 10.- Stock Appreciation Rights

10.1Grant of SARs. Subject to and consistent with the provisions of the Plan, stock appreciation rights (“Stock Appreciation Rights” or “SARs”) may be granted to any Eligible Persons in such numbers and upon such terms, and at any time and from time to time, as shall be determined by the Committee. Each SAR shall represent the right of the Grantee to receive upon exercise of the SAR an amount equal to the amount described in Section 10.3, subject to such terms and conditions as the Committee shall determine; provided that notwithstanding anything to the contrary, any Award to an Eligible Person of a SAR shall, to the extent applicable, include the minimum vesting requirement set forth in Section 3.2(b).

10.2Award Agreement. Each grant of SARs shall be evidenced by an Award Agreement that shall specify, as the Committee shall determine, the number of Shares as to which the SAR relates, the Base Amount, the term and such other terms and conditions as the Committee shall determine, including without limitation vesting and forfeiture, provided that as to each SAR:

(a)    except with respect to a SAR granted as an Acquired Entity Award, the Base Amount shall never be less than the Fair Market Value of a Share on the Grant Date; and

(b)    the term shall not exceed ten years from the Grant Date.

16

10.3Payment of SAR Amount. Upon exercise of an SAR, the Grantee shall be entitled to receive payment of an amount determined by multiplying (a) the difference between the Base Amount of the SAR and the Fair Market Value of a Share at the close of business on the date the SAR is exercised by (b) the number of Shares with respect to which the SAR is exercised. In the discretion of the Committee, payment of the SAR amount by the Company may be in cash, Shares or a combination of cash and Shares.

10.4Forfeiture. Except as otherwise determined by the Committee, upon Termination of Affiliation any unvested SARs shall be forfeited.

10.5No Repricing. Subject to the adjustment under Section 4.2, neither the Committee nor the Board shall have the authority or discretion to reduce, directly or indirectly, the Base Amount of any outstanding SAR without stockholder approval, including, without limitation, by (a) canceling previously awarded SARs and regranting them with a lower Base Amount, (b) at any time when the Base Amount of a previously granted SAR is above the Fair Market Value of a Share, exchanging or buying out such previously granted SARs for a payment in cash, Shares or other Award, notwithstanding any authority otherwise granted the Committee under the Plan or

(a)    take any other action with respect to a SAR that would be treated as a repricing under the rules and regulations of the principal securities exchange on which the Shares are traded.

Article 11.- Other Stock-Based Awards

The Committee is authorized, subject to limitations under applicable law, to grant to any Eligible Persons such other Awards that are denominated or payable in, valued in whole or in part by reference to, or otherwise based on, or related to, Shares or other securities, as deemed by the Committee to be consistent with the purposes of the Plan, including Shares awarded which are convertible or exchangeable debt securities or other rights convertible or exchangeable into Shares, Awards valued by reference to the value of securities of or the performance of specified Affiliates, and Awards payable in securities of Affiliates; provided that notwithstanding anything to the contrary, any such Award to an Eligible Person that is valued based on appreciation in the value of a Share following the Grant Date, shall, to the extent applicable, include the minimum vesting requirement set forth in Section 3.2(b). Subject to and consistent with the provisions of the Plan, the Committee shall determine the terms and conditions of such Awards. Except as provided by the Committee, Shares or other securities delivered pursuant to a purchase right granted under this Article 11 shall be purchased for such consideration, paid for by such methods and in such forms, including cash, Shares, outstanding Awards or other property or other consideration permitted by applicable law, as the Committee shall determine.

Article 12.- Non-Equity Incentive Awards

The Committee is authorized to grant Non-Equity Incentive Awards alone or in conjunction with other Awards to individuals who are at the time of the grant of such Non-Equity Incentive Award, included in the Designated 162(m) Group. All terms, conditions and limitations applicable to any Non-Equity Incentive Award shall be determined by the Committee, subject to and consistent with the provisions of the Plan.

Article 13.- Change in Control

13.1Acceleration of Exercisability and Lapse of Restrictions. If, upon or within two (2) years following a Change in Control a Grantee has a Termination of Affiliation with the Company and the Company’s Affiliates (excluding any transfer to the Company or its Affiliates) voluntarily for Good Reason, or involuntarily (other than due to Cause, death, Disability, or Retirement) the following acceleration provisions shall apply to Awards other than Awards granted under Article 14:

(a)    All outstanding Awards pursuant to which the Grantee may have rights, the exercise of which is restricted or limited, shall become fully exercisable; unless the right to lapse restrictions or limitations is waived or deferred by a Grantee prior to such lapse, all restrictions or limitations (including risks of forfeiture) on outstanding Awards subject to restrictions or limitations under the Plan shall lapse; and all performance criteria and other conditions

17

to payment of Awards under which payments of cash, Shares or other property are subject to conditions shall be deemed to be achieved or fulfilled (at the target level, to the extent applicable) and shall be waived by the Company; and

(b)    Notwithstanding any other provision of the Plan or any outstanding Award Agreement, Awards in the form of Non-Qualified Stock Options which are accelerated under this Section 13.1 shall be exercisable after a Grantee’s Termination of Affiliation for a period equal to the lesser of (i) the remaining term of each nonqualified option; or (ii) eighteen (18) months.

Notwithstanding anything herein to the contrary, in the event of a Change in Control in which the acquiring or surviving company in the transaction does not assume or continue outstanding Awards upon the Change in Control or to provide equivalent awards of substantially the same value, immediately prior to the Change in Control, all Awards that are not assumed or continued shall be treated as follows effective immediately prior to the Change in Control: all outstanding Awards pursuant to which the Grantee may have rights, the exercise of which is restricted or limited, shall become fully exercisable; unless the right to lapse restrictions or limitations is waived or deferred by a Grantee prior to such lapse, all restrictions or limitations (including risks of forfeiture) on outstanding Awards subject to restrictions or limitations under the Plan shall lapse; and all performance criteria and other conditions to payment of Awards under which payments of cash, Shares or other property are subject to conditions shall be deemed to be achieved or fulfilled (at the target level, to the extent applicable) and shall be waived by the Company. For the avoidance of doubt, nothing herein shall require the acquiring or surviving company in a Change in Control to assume all Awards previously made under the Plan or to provide equivalent awards of substantially the same value.

In no event shall any action be taken pursuant to this Section 13.1 that would change the payment or settlement date of an Award in a manner that would result in the imposition of any additional taxes or penalties pursuant to Section 409A of the Code.

13.2Definitions. For purposes of this Article 13, the following terms shall have the meanings set forth below:

(a)    “Cause” means, from and after the occurrence of a Change in Control, unless otherwise defined in an Award Agreement or individual employment, change in control, or other severance agreement, the occurrence of any one or more of the following, as determined in the good faith and reasonable judgment of the Committee:

(i)    willful failure by a Grantee to substantially perform his or her duties (as they existed immediately prior to a Change in Control), other than any such failure resulting from a Disability; or

(ii)    Grantee’s conviction of or plea of nolo contendere to a crime involving fraud, dishonesty or any other act constituting a felony involving moral turpitude or causing material harm, financial or otherwise, to the Company or an Affiliate; or

(iii)    Grantee’s willful or reckless material misconduct in the performance of his duties which results in an adverse effect on the Company, the Subsidiary or an Affiliate; or

(iv)    Grantee’s willful or reckless violation or disregard of the code of business conduct or other published policy of the Company or an Affiliate; or

(v)    Grantee’s habitual or gross neglect of duties.

(b)    “Change Date” means, with respect to an Award, the date on which a Change in Control first occurs while the Award is outstanding.

(c)    “Change in Control” means, unless otherwise defined in an Award Agreement or individual Change in Control severance agreement, the occurrence of any one or more of the following:

18

(i)    any person (as such term is used in Rule 13d-5 of the SEC under the Exchange Act) or group (as such term is defined in Sections 3(a)(9) and 13(d)(3) of the Exchange Act), other than a Controlled Affiliate or any employee benefit plan (or any related trust) sponsored or maintained by the Company or any of its Controlled Affiliates (a “Related Party”), becomes the beneficial owner (as defined in Rule 13d-3 under the Exchange Act) of 20% or more of the common stock of the Company or of Voting Securities representing 20% or more of the combined voting power of all Voting Securities of the Company, except that no Change in Control shall be deemed to have occurred solely by reason of such beneficial ownership by a Person with respect to which both more than 75% of the common stock of such Person and Voting Securities representing more than 75% of the combined voting power of the Voting Securities of such Person are then owned, directly or indirectly, by the persons who were the direct or indirect owners of the common stock and Voting Securities of the Company immediately before such acquisition, in substantially the same proportions as their ownership, immediately before such acquisition, of the common stock and Voting Securities of the Company, as the case may be; or

(ii)    the Company’s Incumbent Directors (determined using the date of the Award as the baseline date) cease for any reason to constitute at least a majority of the directors of the Company then serving; or

(iii)    consummation of a merger, reorganization, recapitalization, consolidation, or similar transaction (any of the foregoing, a “Reorganization Transaction”), other than a Reorganization Transaction that results in the Persons who were the direct or indirect owners of the outstanding common stock and Voting Securities of the Company immediately before such Reorganization Transaction becoming, immediately after the consummation of such Reorganization Transaction, the direct or indirect owners, of both at least 65% of the then-outstanding common stock of the Surviving Corporation and Voting Securities representing at least 65% of the combined voting power of the then-outstanding Voting Securities of the Surviving Corporation, in substantially the same respective proportions as such Persons’ ownership of the common stock and Voting Securities of the Company immediately before such Reorganization Transaction; or

(iv)    consummation of a plan or agreement for the sale or other disposition of all or substantially all of the consolidated assets of the Company or a plan of complete liquidation of the Company, other than any such transaction that would result in (A) a Related Party owning or acquiring more than 50% of the assets owned by the Company immediately prior to the transaction or (B) the Persons who were the direct or indirect owners of the outstanding common stock and Voting Securities of the Company immediately before such transaction becoming, immediately after the consummation of such transaction, the direct or indirect owners, of more than 50% of the assets owned by the Company immediately prior to the transaction.

Notwithstanding the occurrence of any of the foregoing events and subject to Section 17.18, a Change in Control shall not occur with respect to a Grantee if, in advance of such event, the Grantee agrees in writing that such event shall not constitute a Change in Control.

(d)    “Good Reason” means, unless otherwise defined in an Award Agreement or individual employment, change in control or other severance agreement, the occurrence, upon or within two years following a Change in Control and without a Grantee’s prior written consent, of any one or more of the following:

(i)    a material adverse reduction in the nature or scope of the Grantee’s duties from the most significant of those assigned at any time in the 90-day period prior to a Change in Control; or

(ii)    a significant reduction in the authority and responsibility assigned to the Grantee; or

(iii)    any material reduction in or failure to pay Grantee’s base salary; or

19

(iv)    a material reduction of Grantee’s aggregate compensation and/or aggregate benefits from the amounts and/or levels in effect on the Change Date, unless such reduction is part of a policy applicable to peer employees of the Employer and of any successor entity; or

(v)    a requirement by the Company or an Affiliate that the Grantee’s principal duties be performed at a location more than fifty (50) miles from the location where the Grantee was employed immediately preceding the Change in Control, without the Grantee’s consent (except for travel reasonably required in the performance of the Grantee’s duties); provided such new location is farther from Grantee’s residence than the prior location.

Notwithstanding anything in this Article 13 to the contrary, no act or omission shall constitute grounds for “Good Reason”:

(i)    Unless, at least 30 days prior to his termination, Grantee gives a written notice to the Company or the Affiliate that employs Grantee of his intent to terminate his employment for Good Reason which describes the alleged act or omission giving rise to Good Reason;

(ii)    Unless such notice is given within 90 days of Grantee’s first actual knowledge of such act or omission; and

(iii)    Unless the Company or the Affiliate that employs Grantee fails to cure such act or omission within the 30 day period after receiving such notice.

Further, no act or omission shall be “Good Reason” if Grantee has consented in writing to such act or omission.

(e)    “Incumbent Directors” means, determined as of any date by reference to any baseline date:

(i)    the members of the Board on the date of such determination who have been members of the Board since such baseline date; and

(ii)    the members of the Board on the date of such determination who were appointed or elected after such baseline date and whose election, or nomination for election by stockholders of the Company or the Surviving Corporation, as applicable, was approved by a vote or written consent of two-thirds of the directors comprising the Company’s Incumbent Directors on the date of such vote or written consent, but excluding each such member whose initial assumption of office was in connection with (A) an actual or threatened election contest, including a consent solicitation, relating to the election or removal of one or more members of the Board or (B) a “tender offer” (as such term is used in Section 14(d) of the Exchange Act).

(f)    “Retirement” shall have the meaning ascribed to such term in the Company’s governing tax-qualified retirement plan applicable to the Grantee, or if no such plan is applicable to the Grantee, in the good faith determination of the Committee.

(g)    “Surviving Corporation” means the corporation resulting from a Reorganization Transaction or, if securities representing at least 50% of the aggregate voting power of all Voting Securities of such resulting corporation are directly or indirectly owned by another corporation, such other corporation.

(h)    “Voting Securities” of a corporation means securities of such corporation that are entitled to vote generally in the election of directors of such corporation.

20

Article 14.- Non-Management Director Awards

14.1Director Annual Grant.

(a)Automatic Grant of Director Annual Grant. Subject to adjustment as provided in Section 4.2, annually each Non-Management Director shall be granted an annual Award payable, as determined by the Board, in the form of one or a combination of Restricted Stock or Restricted Stock Units (determined by rounding up to the next higher whole number of Shares any fractional portion of a Share equal to or in excess of one-half Share, and otherwise rounding down to the next lower whole number of Shares) having a Fair Market Value at the close of business on the Grant Date of up to Three Hundred Thousand Dollars ($300,000); provided, however, that with respect to a Non-Management Director who is designated as Chairman of the Board or Lead Director, the annual Award granted to the Non-Management Director may have a Fair Market Value of up to two hundred percent (200%) of the foregoing limit (“Director Annual Grant”). Notwithstanding the foregoing, the Board, in its sole discretion, may reduce or eliminate an annual Award that would otherwise be granted to a Non-Management Director. The Grant Date for such Director Annual Grant shall be the date of the annual meeting of company stockholders (“Annual Meeting of Company Stockholders”) commencing with the Annual Meeting of Company Stockholders in 2014. If no Annual Meeting of Company Stockholders is held prior to June 1 of any calendar year, the Grant Date for the Director Annual Grant shall be May 31. Notwithstanding the foregoing, the Board may, in its discretion exercised at any time prior to the date a Director Annual Grant is granted for a year, provide that the Director Annual Grant for such year shall be granted in installments, so that only a portion (which portion shall be the same for each Non-Management Director) of the Director Annual Grant shall be granted on the date of the Annual Meeting of Company Stockholders (or May 31, as applicable) of such year, and the remaining portion or portions shall be granted at such time or times in such year as the Board may specify at the time it determines to grant the Director Annual Grant in installments. A person who first becomes a Non-Management Director after the conclusion of the Annual Meeting of Company Stockholders and prior to August 1 of any year shall be granted the full Director Annual Grant for such year as of December 15.

(b)Prorated Director Annual Grant.

(i)    Subject to adjustment as provided in Section 4.2, a person who first becomes a Non-Management Director on or after August 1 of any year and prior to the first Annual Meeting of Company Stockholders following the date the person becomes a Non-Management Director shall be granted a prorated Director Annual Grant for such first year with a Grant Date following the date such person becomes a Non-Management Director determined as follows:

(A)    The Grant Date shall be December 15 if the person first becomes a Non-Management Director on or before December 15 of the year.

(B)    The Grant Date shall be the date of the next Annual Meeting of Company Stockholders if the person first becomes a Non-Management Director on or after December 16 of the year. If no Annual Meeting of Company Stockholders is held prior to the next following June 1, the Grant Date shall be May 31 of the year following the date the person becomes a Non-Management Director.

(ii)    The prorated portion of the Director Annual Grant shall be determined by multiplying the value of such Director Annual Grant by a fraction, the numerator of which is the number of full and fractional calendar months elapsing between the date such person first becomes a Non-Management Director and the date of the first Annual Meeting of Company Stockholders following the date the person becomes a Non-Management Director and the denominator of which is twelve; provided that with respect to any component of a Director Annual Grant denominated in Shares, including but not limited to Shares of Restricted Stock or Restricted Stock Units, only whole numbers of Shares shall be granted, determined by rounding up to the next higher whole number of Shares any fractional portion of a Share equal to or in excess of one-half Share, and otherwise rounding down to the next lower whole number of Shares. If no Annual Meeting of Company Stockholders is scheduled as of a December 15 Grant Date or held as of a May 31 Grant Date, such prorated Director Annual Grant shall be determined by multiplying each component of such Director Annual Grant by

21

a fraction, the numerator of which is the number of full and fractional calendar months elapsing between the date such person first becomes a Non-Management Director and May 31 of the year following the date such person becomes a Non-Management Director and the denominator of which is twelve. As to any component denominated in Shares, including without limitation Shares of Restricted Stock or Restricted Stock Units, only whole numbers of Shares shall be granted, determined by rounding up to the next higher whole number of Shares any fractional portion of a Share equal to or in excess of one-half Share, and otherwise rounding down to the next lower whole number of Shares.

(iii)    In the event the Board has determined that the Director Annual Grant for a year shall be granted in installments, the Board shall make appropriate provisions for prorating installments with respect to Non-Management Directors entitled to a prorated Director Annual Grant, consistent with the preceding provisions of this Section 14.1(b).

(c)Non-Management Director Status. A person must be a Non-Management Director on the Grant Date of a Director Annual Grant (or any installment thereof) in order to be granted such Director Annual Grant (or installment thereof). For a Director Annual Grant granted on the date of the Annual Meeting of Company Stockholders, other than a prorated Director Annual Grant, the person must be a Non-Management Director at the conclusion of the Annual Meeting of Company Stockholders.

(d)Vesting and Payment. Each Director Annual Grant shall vest and be paid out in Shares as determined by the Committee.

14.2 Election to Receive Director Fees in Shares or Restricted Stock Units in Lieu of Cash.

(a)Payment of Director Fees in Shares. A Non-Management Director may elect (“Equity Election”) to be paid all or a portion of cash fees, if any, earned in his or her capacity as a Non-Management Director (including any retainer fees, fees for service as chairman of a Board committee and any other cash fees paid to directors (“Director Fees”)), in the form of Shares in lieu of cash. An Equity Election may be made at any time prior to the date Director Fees would otherwise have been paid in cash, subject to such restrictions and advance filing requirements as the Company may impose, including, but not limited to, restrictions designed to comply with the requirements of Section 409A of the Code. Equity Elections made pursuant to The Williams Companies, Inc. 1996 Stock Plan for Non-Employee Directors or The Williams Companies, Inc. 2002 Incentive Plan, as amended from time to time, that were in effect on the date stockholders approve this Plan shall remain in effect under this Plan, subject to the remainder of this Section 14.2(a). Each Equity Election shall be irrevocable, shall specify the portion of the Director Fees to be paid in the form of Shares and shall remain in effect with respect to future Director Fees until the Non-Management Director revokes or changes such Equity Election. Any such revocation or change shall have prospective application only. Shares delivered pursuant to an Equity Election shall be that whole number of Shares (determined by rounding up to the next higher whole number of Shares any fractional portion of a Share equal to or in excess of one-half Share, and otherwise rounding down to the next lower whole number of Shares), determined by dividing the amount of Director Fees to be paid in Shares by the Fair Market Value of a Share at the close of business on the date such Director Fees would otherwise be paid.

(b)Payment of Director Fees in Restricted Stock Units. A Non-Management Director who makes a Deferral Election in accordance with Section 14.3 shall receive all or part (as he or she elects) of his or her Director Fees in the form of a number of Restricted Stock Units equal to the quotient of the amount of Director Fees to be paid in the form of Restricted Stock Units divided by the Fair Market Value of a Share at the close of business on the date such Director Fees would otherwise be paid in cash.

14.3Deferral Elections. To the extent permitted by the Committee from time to time, each member of the Board who is a Non-Management Director may make an election (“Deferral Election”) to be paid any or all of the following (“Deferrable Amounts”) in the form of Restricted Stock Units in lieu of cash or Shares, as applicable: (a) Director Annual Grants as provided in Section 14.1; or (b) Director Fees as provided in 14.2(a).

22

(a)Timing of Deferral Elections. An initial Deferral Election must be filed with the Human Resources Department of the Company no later than December 31 of the year preceding the calendar year in which the Deferrable Amounts to which the Deferral Election applies would otherwise be paid or delivered, subject to such restrictions and advance filing requirements as the Company may impose; provided that any newly elected or appointed Non-Management Director may file a Deferral Election not later than 30 days after the date such person first becomes a Non-Management Director. A Deferral Election shall be irrevocable as of the filing deadline and shall only apply with respect to Deferrable Amounts otherwise payable after the filing of such election. Each Deferral Election (including a deferral election filed under The Williams Companies, Inc. 1996 Stock Plan for Non-Employee Directors or The Williams Companies, Inc. 2002 Incentive Plan that was in effect on the date stockholders approved this Plan) shall remain in effect with respect to subsequently earned Deferrable Amounts unless the Non-Management Director revokes or changes such Deferral Election. Any such revocation or change shall have prospective application only and shall in no event apply with respect to compensation earned in the calendar year in which the revocation or change is made.

(b)Content of Deferral Elections. A Deferral Election must specify the following:

(i)    (A) The number of shares (including shares subject to Restricted Stock Units granted under Section 14.1(a) or Section 14.1(b)) subject to the Director Annual Grant to be deferred and paid in Restricted Stock Units under this Section 14.3 and/or (B) the dollar amount of Director Fees to be deferred and paid in Restricted Stock Units under this Section 14.3, as applicable; and

(ii)    the date such Restricted Stock Units shall be paid (subject to such Period of Restriction and other limitations as may be specified by counsel to the Company).

(c)Deferral Account. The Company shall establish an account (“Deferral Account”) on its books for each Non-Management Director who makes a Deferral Election. A number of Restricted Stock Units (determined in the case of a Deferrable Amount otherwise payable in cash by dividing the amount of cash to be deferred by the Fair Market Value of a Share at the close of business on the date such cash would otherwise be paid) shall be credited to the Non-Management Director’s Deferral Account as of each date a Deferrable Amount subject to a Deferral Election would otherwise be paid. Deferral Accounts shall be maintained for recordkeeping purposes only and the Company shall not be obligated to segregate or set aside assets representing securities or other amounts credited to Deferral Accounts. The obligation to make distributions of securities or other amounts credited to Deferral Accounts shall be an unfunded unsecured obligation of the Company.

(d)Settlement of Deferral Accounts. The Company shall settle a Non-Management Director’s Deferral Account by delivering to the holder thereof (which may be the Non-Management Director or his or her beneficiary) a number of Shares equal to the number of Restricted Stock Units then credited to such Deferral Account (or a specified portion in the event of any partial settlement); provided that if less than the value of a whole Share remains in the Deferral Account at the time of any such distribution, the number of Shares distributed shall be rounded up to the next higher whole number of Shares if the fractional portion of a Share remaining is equal to or in excess of one-half Share, and otherwise shall be rounded down to the next lower whole number of Shares. Such settlement shall be made at the time or times specified in the applicable Deferral Election.

14.4Insufficient Number of Shares. If at any date insufficient Shares are available under the Plan for the automatic grant of Director Annual Grants, or the delivery of Shares in lieu of cash payment of Director Fees, or crediting Restricted Stock Units pursuant to a Deferral Election, (a) Director Annual Grants under Section 14.1 automatically shall be granted proportionately to each Non-Management Director eligible for such a grant to the extent Shares are then available (provided that no Director Annual Grant shall be granted with respect to a fractional number of Shares), and (b) then, if any Shares remain available, Director Fees elected to be received in Shares shall be paid in the form of Shares or Restricted Stock Units proportionately among Non-Management Directors then eligible to participate to the extent Shares are then available and otherwise in the form of cash.

14.5Non-Forfeitability. The interest of each Non-Management Director in Director Annual Grants granted or delivered under the Plan at all times shall be non-forfeitable, except to the extent the Board provides otherwise.

23

14.6No Duplicate Payments. No payments or Awards shall be made or granted under this Plan with respect to any services as a Non-Management Director if a payment or award has been or will be made for the same services under The Williams Companies, Inc. 1996 Stock Plan for Non Employee Directors or The Williams Companies, Inc. 2002 Incentive Plan, as amended from time to time.

Article 15.- Amendment, Modification, and Termination

15.1Amendment, Modification, and Termination. Subject to Section 15.2, the Board may, at any time and from time to time, alter, amend, suspend, discontinue or terminate the Plan in whole or in part without the approval of the Company’s stockholders, except that (a) any amendment or alteration shall be subject to the approval of the Company’s stockholders if such stockholder approval is required by any federal or state law or regulation or the rules of any securities exchange or other form of securities market on which the Shares may then be listed or quoted, (b) the Board may otherwise, in its discretion, determine to submit other such amendments or alterations to stockholders for approval and (c) no amendment or alteration of Section 6.3 or Section 10.5 (except to correct a scrivener’s error) shall be made without the approval of the Company’s stockholders.

15.2Awards Previously Granted. Except as otherwise specifically permitted in the Plan or an Award Agreement, no termination, amendment, or modification of the Plan, other than amendments or modifications required by applicable law, shall adversely affect in any material way any Award previously granted under the Plan, without the written consent of the Grantee of such Award; provided that at any time prior to a Change in Control, Article 13 may be removed, amended or modified in a manner that adversely affects Awards previously granted under the Plan, without the consent of any Grantee.

Article 16.- Withholding

16.1Mandatory Tax Withholding.

(a)    Whenever, under the Plan, (i) Shares are to be delivered upon payment of an Award, (ii) Shares of Restricted Stock become nonforfeitable, (iii) a cash payment is made for any Award, or (iv) any other payment event occurs with respect to rights and benefits hereunder, the Company or any Affiliate shall be entitled to require (A) that the Grantee remit an amount in cash or in Shares (valued at their Fair Market Value on the date the withholding obligation arises) sufficient to satisfy all of the employer’s federal, state, and local tax withholding requirements related thereto but no more than the minimum amount necessary to satisfy such amounts (“Required Withholding”), (B) the withholding of such Required Withholding from compensation otherwise due to the Grantee or from any Shares valued at their Fair Market Value at the date the withholding obligation arises, or from any other payment due to the Grantee under the Plan or otherwise or (C) any combination of the foregoing.

(b)    If any Grantee makes an election under Section 83(b) of the Code, the Company or any Affiliate shall be entitled to require (i) that the Grantee remit an amount in cash or in Shares (valued at their Fair Market Value on the date the withholding obligation arises) sufficient to satisfy the resulting Required Withholding, (ii) the withholding of such Required Withholding from compensation otherwise due to the Grantee or from any Shares or other payment due to the Grantee under the Plan or otherwise or (iii) any combination of the foregoing.

16.2Notification under Code Section 83(b). If any Grantee makes the election permitted under Section 83(b) of the Code to include in such Grantee’s gross income in the year of transfer the amounts specified in Section 83(b) of the Code, then such Grantee shall notify the Company of such election within ten (10) days of filing the notice of the election with the Internal Revenue Service, in addition to any filing and notification required pursuant to regulations issued under Section 83(b) of the Code. The Committee may, in connection with the grant of an Award or at any time thereafter, prohibit a Grantee from making the election described above.

24

Article 17.- Additional Provisions

17.1Successors. All obligations of the Company under the Plan with respect to Awards granted hereunder shall be binding on any successor to the Company, whether the existence of such successor is the result of a direct or indirect purchase, merger, consolidation, or otherwise of all or substantially all of the business and/or assets of the Company.

17.2Severability. If any part of the Plan is declared by any court or governmental authority to be unlawful or invalid, such unlawfulness or invalidity shall not invalidate any other part of the Plan. Any Section or part of a Section so declared to be unlawful or invalid shall, if possible, be construed in a manner which will give effect to the terms of such Section or part of a Section to the fullest extent possible while remaining lawful and valid.

17.3Requirements of Law. The granting of Awards and the delivery of Shares under the Plan shall be subject to all applicable laws, rules, and regulations, and to such approvals by any governmental agencies or securities exchanges as may be required. Notwithstanding any provision of the Plan or any Award, Grantees shall not be entitled to exercise, or receive benefits under, any Award, and the Company (and any Affiliate) shall not be obligated to deliver any Shares or deliver benefits to a Grantee, if such exercise or delivery would constitute a violation by the Grantee or the Company of any applicable law or regulation.

17.4Securities Law Compliance.

(a)    If the Committee deems it necessary to comply with any applicable securities law, or the requirements of any securities exchange or other form of securities market upon which Shares may be listed, the Committee may impose any restriction on Shares acquired pursuant to Awards under the Plan as it may deem advisable. All certificates for Shares delivered under the Plan pursuant to any Award or the exercise thereof shall be subject to such stop transfer orders and other restrictions as the Committee may deem advisable under the rules, regulations and other requirements of the SEC, any securities exchange or other form of securities market upon which Shares are then listed, any applicable securities law, and the Committee may cause a legend or legends to be put on any such certificates to make appropriate reference to such restrictions. If so requested by the Company, the Grantee shall make a written representation to the Company that he or she will not sell or offer to sell any Shares unless a registration statement shall be in effect with respect to such Shares under the Securities Act of 1933, as amended, and any applicable state or foreign securities law or unless he or she shall have furnished to the Company, in form and substance satisfactory to the Company, that such registration is not required.

(b)    If the Committee determines that the exercise, nonforfeitability of, or delivery of benefits pursuant to, any Award would violate any applicable provision of securities laws or the listing requirements of any securities exchange or other form of securities market on which are listed any of the Company’s equity securities, then the Committee may postpone any such exercise, nonforfeitability or delivery, as applicable, but the Company shall use all reasonable efforts to cause such exercise, nonforfeitability or delivery to comply with all such provisions at the earliest practicable date.

17.5No Rights as a Stockholder. No Grantee shall have any rights as a stockholder of the Company with respect to the Shares (other than Shares of Restricted Stock) which may be deliverable upon exercise or payment of such Award until such Shares have been delivered to him or her. Shares of Restricted Stock, whether held by a Grantee or in escrow by the Secretary of the Company, shall confer on the Grantee all rights of a stockholder of the Company, except as otherwise provided in the Plan or Award Agreement. At the time of a grant of Shares of Restricted Stock, the Committee may require the payment of cash dividends thereon to be deferred and, if the Committee so determines, reinvested in additional Shares of Restricted Stock. Stock dividends and deferred cash dividends issued with respect to Shares of Restricted Stock shall be subject to the same restrictions and other terms as apply to the Shares of Restricted Stock with respect to which such dividends are issued. The Committee may in its discretion provide for payment or crediting of interest on deferred cash dividends.

17.6Nature of Payments. Unless otherwise specified in the Award Agreement, Awards shall be special incentive payments to the Grantee and shall not be taken into account in computing the amount of salary or compensation of the Grantee for purposes of determining any pension, retirement, death or other benefit under (a) any pension, retirement,

25

profit-sharing, bonus, insurance or other employee benefit plan of the Company or any Affiliate, except as such plan shall otherwise expressly provide, or (b) any agreement between (i) the Company or any Affiliate and (ii) the Grantee, except as such agreement shall otherwise expressly provide.

17.7Non-Exclusivity of Plan. Neither the adoption of the Plan by the Board nor its submission to the stockholders of the Company for approval shall be construed as creating any limitations on the power of the Board to adopt such other compensatory arrangements for employees or Non-Management Directors as it may deem desirable.

17.8Governing Law. The Plan, and all agreements hereunder, shall be construed in accordance with and governed by the laws of the State of Delaware, other than its laws respecting choice of law.

17.9Share Certificates. Any certificates for Shares delivered under the terms of the Plan shall be subject to such stop-transfer orders and other restrictions as the Committee may deem advisable under federal or state securities laws, rules and regulations thereunder, and the rules of any foreign securities laws, rules and regulations thereunder, and the rules of any national securities exchange or other form of securities market on which Shares are listed or quoted. The Committee may cause a legend or legends to be placed on any such certificates to make appropriate reference to such restrictions or any other restrictions or limitations that may be applicable to Shares. In addition, during any period in which Awards or Shares are subject to restrictions or limitations under the terms of the Plan or any Award Agreement, or during any period during which delivery or receipt of an Award or Shares has been deferred by the Committee or a Grantee, the Committee may require any Grantee to enter into an agreement providing that certificates representing Shares deliverable or delivered pursuant to an Award shall remain in the physical custody of the Company or such other person as the Committee may designate.

17.10Unfunded Status of Awards; Creation of Trusts. The Plan is intended to constitute an “unfunded” plan for incentive and deferred compensation. With respect to any payments not yet made to a Grantee pursuant to an Award, nothing contained in the Plan or any Award Agreement shall give any such Grantee any rights that are greater than those of a general creditor of the Company; provided that the Committee may authorize the creation of trusts or make other arrangements to meet the Company’s obligations under the Plan to deliver cash, Shares or other property pursuant to any Award which trusts or other arrangements shall be consistent with the “unfunded” status of the Plan unless the Committee otherwise determines.

17.11Employment. Nothing in the Plan or an Award Agreement shall interfere with or limit in any way the right of the Company or any Affiliate to terminate any Grantee’s employment at any time, for any reason or no reason, or shall confer upon any Grantee the right to continue in the employ or as an officer of the Company or any Affiliate.

17.12Participation. No employee or officer shall have the right to be selected to receive an Award under this Plan or, having been so selected, to be selected to receive a future Award.

17.13Military Service. Awards shall be administered in accordance with Section 414(u) of the Code and the Uniformed Services Employment and Reemployment Rights Act of 1994 to the extent required by law or as determined by the Committee.

17.14Construction; Gender and Number. The following rules of construction will apply to the Plan: (a) the word “or” is disjunctive but not necessarily exclusive, and (b) words in the singular include the plural, words in the plural include the singular, and words in the neuter gender include the masculine and feminine genders and words in the masculine or feminine gender include the other neuter genders.

17.15Headings. The headings of articles and sections are included solely for convenience of reference, and if there is any conflict between such headings and the text of this Plan, the text shall control.

17.16Obligations. Unless otherwise specified in an Award Agreement, the obligation to deliver, pay or transfer any amount of money or other property pursuant to Awards under this Plan shall be the sole obligation of a Grantee’s employer; provided that the obligation to deliver or transfer any Shares pursuant to Awards under this Plan shall be the sole obligation of the Company.

26

17.17No Right to Continue as Director. Nothing in the Plan or any Award Agreement shall confer upon any Non-Management Director the right to continue to serve as a director of the Company.

17.18Code Section 409A Compliance. The Board intends that, except as may be otherwise determined by the Committee, any Awards under the Plan satisfy the requirements of Section 409A of the Code and related regulations and Treasury pronouncements (“Section 409A”) to avoid the imposition of any taxes, including additional income taxes, thereunder. If the Committee determines that an Award, Award Agreement, payment, distribution, deferral election, transaction or any other action or arrangement contemplated by the provisions of the Plan would, if undertaken, cause a Grantee to become subject to Section 409A, unless the Committee expressly determines otherwise, such grant of Award, payment, distribution, deferral election, transaction or other action or arrangement shall not be undertaken and the related provisions of the Plan and/or Award Agreement will be amended or deemed modified in as close a manner as possible to give effect to the original terms of the Award, or, only if necessary because a modification or deemed modification would not be reasonably effective in avoiding the additional income tax under Section 409A(a)(1)(B) of the Code, rescinded in order to comply with the requirements of Section 409A to the extent determined by the Committee without the consent of or notice to the Grantee. Notwithstanding the foregoing, with respect to any Award intended by the Committee to be exempt from the requirements of Section 409A which is to be paid out when vested, such payment shall be made as soon as administratively feasible after the Award becomes vested, but in no event shall such payment be made later than 2-1/2 months after the end of the calendar year in which the Award became vested unless (a) deferred pursuant to Section 5.8 or 14.3 or (b) otherwise permitted under the exemption provisions of Section 409A.

17.19Recoupment Policy. Subject to the terms and conditions of the Plan, the Committee may provide that any Grantee and/or any Award, including any Shares subject to an Award, is subject to any recovery, recoupment, clawback and/or other forfeiture policy maintained by the Company from time to time.

END OF DOCUMENT

27

EX-12

Exhibit 12

The Williams Companies, Inc.

Computation of Ratio of Earnings to Fixed Charges

	Years Ended December 31,
	2016			2015			2014			2013			2012
	(Millions)
Earnings:
Income (loss) from continuing operations before income taxes (2)	$	(375	)	$	(1,713	)	$	3,584		$	1,080		$	1,289
Less: Equity earnings	(397		)	(335		)	(144		)	(134		)	(111		)
Income (loss) from continuing operations before income taxes and equity earnings (2)	(772		)	(2,048		)	3,440			946			1,178
Add:
Fixed charges:
Interest incurred (1)	1,217			1,118			888			611			568
Rental expense representative of interest factor	11			10			9			11			11
Total fixed charges	1,228			1,128			897			622			579
Distributed income of equity-method investees	739			617			409			245			161
Less:
Interest capitalized	(38		)	(74		)	(141		)	(101		)	(59		)
Total earnings as adjusted (2)	$	1,157		$	(377	)	$	4,605		$	1,712		$	1,859
Fixed charges	$	1,228		$	1,128		$	897		$	622		$	579
Ratio of earnings to fixed charges	0.94			*			5.13			2.75			3.21

(1) Does not include interest related to income taxes, including interest related to liabilities for uncertain tax positions, which is included in Provision (benefit) for income taxes in our Consolidated Statement of Operations.

(2) Includes a $2.544 billion non-cash gain in 2014 resulting from remeasuring our previous equity-method investment in ACMP to its preliminary acquisition-date fair value in conjunction with accounting for the ACMP Acquisition.

* Earnings were inadequate to cover fixed charges by $1,505 million for 2015.

EX-21

Exhibit 21

ENTITY	JURISDICTION
ACMP Finance Corp.	Delaware
Alliance Canada Marketing L.P.	Alberta
Alliance Canada Marketing LTD	Alberta
Appalachia Midstream Services, L.L.C.	Oklahoma
Aux Sable Liquid Products Inc.	Delaware
Aux Sable Liquid Products LP	Delaware
Aux Sable Midstream LLC	Delaware
Bargath LLC	Delaware
Baton Rouge Fractionators LLC	Delaware
Baton Rouge Pipeline LLC	Delaware
Black Marlin Pipeline LLC	Texas
Blue Racer Midstream, LLC	Delaware
Bluestem Gas Services, L.L.C.	Oklahoma
Caiman Energy II, LLC	Delaware
Caiman Ohio Midstream, LLC	Texas
Carbon County UCG, Inc.	Delaware
Carbonate Trend Pipeline LLC	Delaware
Cardinal Gas Services, L.L.C.	Delaware
Cardinal Operating Company, LLC	Delaware
Cardinal Pipeline Company, LLC	North Carolina
Constitution Pipeline Company LLC	Delaware
Discovery Gas Transmission LLC	Delaware
Discovery Producer Services LLC	Delaware
DMP New York, Inc.	New York
Gulfstar One LLC	Delaware
Gulfstream Management & Operating Services, L.L.C.	Delaware
Gulfstream Natural Gas System, L.L.C.	Delaware
HB Construction Company Ltd.	Alberta
HI-BOL Pipeline LLC	Delaware
Inland Ports, Inc.	Tennessee
Jackalope Gas Gathering Services, L.L.C.	Oklahoma
Laurel Mountain Midstream Operating LLC	Delaware
Laurel Mountain Midstream, LLC	Delaware
Louisiana Midstream Gas Services, L.L.C.	Oklahoma
Magnolia Midstream Gas Services, L.L.C.	Oklahoma
Marsh Resources, LLC	Delaware
Mid-Continent Fractionation and Storage, LLC	Delaware
Mockingbird Midstream Gas Services, L.L.C.	Oklahoma
Northwest Pipeline LLC	Delaware
Oklahoma Midstream Gas Services, L.L.C.	Oklahoma
Overland Pass Pipeline Company LLC	Delaware

Exhibit 21

Pacific Connector Gas Pipeline, LLC	Delaware
Pacific Connector Gas Pipeline, LP	Delaware
Parachute Pipeline LLC	Delaware
Pecan Hill Water Solutions	Delaware
Pennant Midstream LLC	Delaware
Pine Needle LNG Company, LLC	North Carolina
Pine Needle Operating Company, LLC	Delaware
Ponder Midstream Gas Services, L.L.C.	Delaware
Ranch Westex JV LLC	Delaware
Reserveco Inc.	Delaware
SCMS LLC	Delaware
Texas Midstream Gas Services, L.L.C.	Oklahoma
The Williams Companies Foundation, Inc.	Oklahoma
The Williams Companies, International Holdings B.V.	Dutch BV
Three Rivers Midstream LLC	Delaware
TransCardinal Company, LLC	Delaware
TransCarolina LNG Company, LLC	Delaware
Transco Exploration Company	Delaware
Transcontinental Gas Pipe Line Company, LLC	Delaware
TWC Holdings C.V.	Netherlands
Utica East Ohio Midstream, L.L.C.	Delaware
Utica Gas Services, L.L.C.	Oklahoma
Wamsutter LLC	Delaware
WFS - Liquids LLC	Delaware
WFS - Pipeline LLC	Delaware
WFS Enterprises LLC	Delaware
WFS Gathering Company, L.L.C.	Delaware
Williams ACM Holdings ULC	British Columbia
Williams Acquisition Holding Company LLC	New Jersey
Williams Alaska Petroleum, Inc.	Alaska
Williams Bayou Ethane Pipeline, LLC	Delaware
Williams Blu Operating LLC	Delaware
Williams Bluegrass Pipeline LLC	Delaware
Williams Compression, L.L.C.	Oklahoma
Williams CV Holdings LLC	Delaware
Williams Energy Canada GP ULC	Alberta
Williams Energy Canada LP	Alberta
Williams Energy de Mexico, S. de. R.L. de C.V.	Mexico
Williams Energy Resources LLC	Delaware
Williams Energy Solutions LLC	Delaware
Williams Express LLC	Delaware
Williams Express, Inc.	Alaska
Williams Field Services - Gulf Coast Company, L.P.	Delaware
Williams Field Services Company, LLC	Delaware
Williams Field Services Group, LLC	Delaware
Williams Flexible Generation, LLC	Delaware

Exhibit 21

Williams Four Corners LLC	Delaware
Williams Gas Pipeline Company, LLC	Delaware
Williams Gas Processing - Gulf Coast Company, L.P.	Delaware
Williams Global Energy (Cayman) Limited	Cayman Islands
Williams Global Holdings LLC	Delaware
Williams Gulf Coast Gathering Company, LLC	Delaware
Williams Gulf Coast Transportation Company LLC	Delaware
Williams Headquarters Building LLC	Delaware
Williams Holdings and Manufacturing LLC	Delaware
Williams Hutch Rail Company, LLC	Delaware
Williams Information Technology LLC	Delaware
Williams International Company LLC	Delaware
Williams International El Furrial Limited	Cayman Islands
Williams International Pigap Limited	Cayman Islands
Williams International Services Company	Nevada
Williams International Venezuela Limited	Cayman Islands
Williams Laurel Mountain, LLC	Delaware
Williams Mexico Holdings B.V.	Netherlands
Williams Mexico Sub-Holdings B.V.	Netherlands
Williams Midstream Gas Services, L.L.C.	Oklahoma
Williams MLP Operating, L.L.C.	Delaware
Williams Mobile Bay Producer Services, L.L.C.	Delaware
Williams New Soda, Inc.	Delaware
Williams Ohio Valley Midstream LLC	Texas
Williams Ohio Valley Pipeline LLC	Delaware
Williams Oil Gathering, L.L.C.	Delaware
Williams Olefins Development, LLC	Delaware
Williams Olefins Feedstock Pipelines, L.L.C.	Delaware
Williams Olefins, L.L.C.	Delaware
Williams Pacific Connector Gas Operator, LLC	Delaware
Williams Partners Cooperatief U.A.	Netherlands
Williams Partners Finance Corporation	Delaware
Williams Partners International Holdings LLC	Delaware
Williams Partners International Sub-Holdings LLC	Delaware
Williams Partners L.P.	Delaware
Williams Partners Operating LLC	Delaware
Williams PERK, LLC	Delaware
Williams Permian Midstream, L.L.C.	Oklahoma
Williams Petroleum Services, LLC	Delaware
Williams Pipeline Services LLC	Delaware
Williams Propylene Company LLC	Delaware
Williams Purity Pipelines, LLC	Delaware
Williams Resource Center, L.L.C.	Delaware
Williams Soda Holdings, LLC	Delaware
Williams Sodium Products Company	Delaware
Williams Strategic Sourcing Company	Delaware

Exhibit 21

Williams West Texas Processing, L.L.C.	Oklahoma
Williams WPC - I, LLC	Delaware
WilPro Energy Services (El Furrial) Limited	Cayman Islands
WilPro Energy Services (Pigap II) Limited	Cayman Islands
WPZ GP LLC	Delaware

EX-23.1

Exhibit 23.1

Consent of Independent Registered Public Accounting Firm

We consent to the incorporation by reference in the following Registration Statements:

(1) Registration Statement (Form S-3 Nos. 333-29185 and 333-204077) of The Williams

Companies, Inc.,

(2) Registration Statement (Form S-8 No. 333-03957) pertaining to The Williams Companies, Inc. 1996 Stock
Plan for Non-Employee Directors,

(3) Registration Statement (Form S-8 No. 333-85542) pertaining to The Williams Investment Plus Plan,

(4) Registration Statement (Form S-8 No. 333-85546) pertaining to The Williams Companies, Inc. 2002 Incentive
Plan,

(5) Registration Statement (Form S-8 No. 333-142985) pertaining to The Williams Companies, Inc. 2007 Employee Stock Purchase Plan and The Williams Companies, Inc. 2007 Incentive Plan,

(6) Registration Statement (Form S-8 No. 333-167123) pertaining to The Williams Companies, Inc. 2007 Incentive Plan, and

(7) Registration Statement (Form S-8 No. 333-198050) pertaining to The Williams Companies, Inc. 2007 Incentive
Plan and The Williams Companies, Inc. 2007 Employee Stock Purchase Plan;

of our reports dated February 22, 2017, with respect to the consolidated financial statements and schedules of The Williams Companies, Inc. and the effectiveness of internal control over financial reporting of The Williams Companies, Inc. included in this Annual Report (Form 10-K) of The Williams Companies, Inc. for the year ended December 31, 2016.

/s/ Ernst & Young LLP

Tulsa, Oklahoma
February 22, 2017

EX-23.2

Exhibit 23.2

Consent of Independent Registered Public Accounting Firm

We consent to the incorporation by reference in Registration Statement Nos. 333-03957, 333-85542, 333-85546, 333-142985, 333-167123 and 333-198050 of The Williams Companies, Inc. on Form S-8, and Registration Statement Nos. 333-29185 and 333-204077 of The Williams Companies Inc. on Form S-3 of our report dated February 22, 2017, relating to the financial statements of Gulfstream Natural Gas System, L.L.C., appearing in this Annual Report on Form 10-K of The Williams Companies, Inc. for the year ended December 31, 2016.

/s/ DELOITTE & TOUCHE LLP

Houston, Texas

February 22, 2017

EX-24

EXHIBIT 24    

THE WILLIAMS COMPANIES, INC.

POWER OF ATTORNEY

KNOW ALL MEN BY THESE PRESENTS that each of the undersigned individuals, in their capacity as a director or officer, or both, as hereinafter set forth below their signature, of THE WILLIAMS COMPANIES, INC., a Delaware corporation ("Williams"), does hereby constitute and appoint SARAH C. MILLER, JOSHUA De REINZIS, and TED T. TIMMERMANS their true and lawful attorneys and each of them (with full power to act without the others) their true and lawful attorneys for them and in their name and in their capacity as a director or officer, or both, of Williams, as hereinafter set forth below their signature, to sign Williams' Annual Report to the Securities and Exchange Commission on Form 10-K for the fiscal year ended December 31, 2016, and any and all amendments thereto or all instruments necessary or incidental in connection therewith; and

Each of said attorneys shall have full power of substitution and resubstitution, and said attorneys or any of them or any substitute appointed by any of them hereunder shall have full power and authority to do and perform in the name and on behalf of each of the undersigned, in any and all capacities, every act whatsoever requisite or necessary to be done in the premises, as fully to all intents and purposes as each of the undersigned might or could do in person, the undersigned hereby ratifying and approving the acts of said attorneys or any of them or of any such substitute pursuant hereto.

IN WITNESS WHEREOF, the undersigned have executed this instrument, all as of the ______day of February, 2017.

(Signature page follows)

/s/ Alan S. Armstrong        /s/ Stephen W. Bergstrom    

Alan S. Armstrong        Stephen W. Bergstrom

Director, Chief Executive Officer,        Director

and President

/s/ Stephen I. Chazen         /s/ Charles I. Cogut        

Stephen I. Chazen        Charles I. Cogut

Director        Director

/s/ Kathleen B. Cooper        /s/ Michael A. Creel        

Kathleen B. Cooper        Michael A. Creel

Chairman of the Board        Director

/s/ Pater A. Ragauss        /s/ Scott D. Sheffield        

Pater A. Ragauss        Scott D. Sheffield

Director         Director

/s/ Murray D. Smith        /s/ William H. Spence        

Murray D. Smith        William H. Spence

Director        Director

/s/ Janice D. Stoney    

Janice D. Stoney

Director

EX-31.1

Exhibit 31.1

CERTIFICATIONS

I, Alan S. Armstrong, certify that:

1. I have reviewed this annual report on Form 10-K of The Williams Companies, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: February 22, 2017

/s/ Alan S. Armstrong

Alan S. Armstrong

President and Chief Executive Officer

(Principal Executive Officer)

EX-31.2

Exhibit 31.2

CERTIFICATIONS

I, Donald R. Chappel, certify that:

1. I have reviewed this annual report on Form 10-K of The Williams Companies, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: February 22, 2017

/s/ Donald R. Chappel

Donald R. Chappel

Senior Vice President and Chief Financial Officer

(Principal Financial Officer)

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report of The Williams Companies, Inc. (the “Company”) on Form 10-K for the period ending December 31, 2016, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), each of the undersigned hereby certifies, in his capacity as an officer of the Company, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that to his knowledge:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Alan S. Armstrong

Alan S. Armstrong

President and Chief Executive Officer

February 22, 2017

/s/ Donald R. Chappel

Donald R. Chappel

Chief Financial Officer

February 22, 2017

A signed original of this written statement required by Section 906 has been provided to, and will be retained by, the Company and furnished to the Securities and Exchange Commission or its staff upon request.

The foregoing certification is being furnished to the Securities and Exchange Commission as an exhibit to the Report and shall not be considered filed as part of the Report.

XML

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2016	Feb. 17, 2017	Jun. 30, 2016
Document and Entity Information [Abstract]
Entity Registrant Name	Williams Companies Inc
Entity Central Index Key	0000107263
Document Type	10-K
Document Period End Date	Dec. 31, 2016
Amendment Flag	false
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		825,823,918
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 16,207,908,251

XML

Consolidated Statement of Operations - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2016		Dec. 31, 2015		Dec. 31, 2014
Revenues:
Service revenues	$ 5,171		$ 5,164		$ 4,116
Product sales	2,328		2,196		3,521
Total revenues	7,499		7,360		7,637
Costs and expenses:
Product costs	1,725		1,779		3,016
Operating and maintenance expenses	1,580		1,655		1,492
Depreciation and amortization expenses	1,763		1,738		1,176
Selling, general, and administrative expenses	723		741		661
Impairment of goodwill (Note 17)	0		1,098		0
Impairment of certain assets (Note 17)	873		209		52
Net insurance recoveries – Geismar Incident	(7)		(126)		(232)
Other (income) expense – net	142		40		(97)
Total costs and expenses	6,799		7,134		6,068
Operating income (loss)	700		226		1,569
Equity earnings (losses)	397		335		144
Gain on remeasurement of equity-method investment (Note 2)	0		0		2,544
Impairment of equity-method investments (Note 17)	(430)		(1,359)		0
Other investing income (loss) – net	63		27		43
Interest incurred	(1,217)		(1,118)		(888)
Interest capitalized	38		74		141
Other income (expense) – net	74		102		31
Income (loss) from continuing operations before income taxes	(375)		(1,713)		3,584
Provision (benefit) for income taxes	(25)		(399)		1,249
Income (loss) from continuing operations	(350)		(1,314)		2,335
Income (loss) from discontinued operations	0		0		4
Net income (loss)	(350)		(1,314)		2,339
Less: Net income (loss) attributable to noncontrolling interests	74		(743)		225
Net income (loss) attributable to The Williams Companies, Inc.	(424)		(571)		2,114
Amounts attributable to The Williams Companies, Inc.:
Income (loss) from continuing operations	(424)		(571)		2,110
Income (loss) from discontinued operations	0		0		4
Net income (loss) attributable to The Williams Companies, Inc.	$ (424)		$ (571)		$ 2,114
Basic earnings (loss) per common share:
Income (loss) from continuing operations	$ (0.57)		$ (0.76)		$ 2.93
Income (loss) from discontinued operations	0.00		0.00		0.01
Net income (loss)	$ (0.57)		$ (0.76)		$ 2.94
Weighted-average shares (thousands)	750,673		749,271		719,325
Diluted earnings (loss) per common share:
Income (loss) from continuing operations	$ (0.57)		$ (0.76)		$ 2.91
Income (loss) from discontinued operations	0.00		0.00		0.01
Net income (loss)	$ (0.57)		$ (0.76)		$ 2.92
Weighted-average shares (thousands)	750,673	[1]	749,271	[1]	723,641

[1] For the years ended December 31, 2016 and December 31, 2015, 0.6 million and 1.7 million weighted-average nonvested restricted stock units, and 0.5 million and 1.5 million weighted-average stock options have been excluded from the computation of diluted earnings (loss) per common share as their inclusion would be antidilutive due to our loss from continuing operations attributable to The Williams Companies, Inc.

XML

Consolidated Statement of Comprehensive Income (Loss) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Comprehensive income (loss):
Net income (loss)	$ (350)	$ (1,314)	$ 2,339
Cash flow hedging activities:
Net unrealized gain (loss) from derivative instruments, net of taxes of ($1) in 2016	4	6	0
Reclassifications into earnings of net derivative instruments (gain) loss, net of taxes of $1 in 2016 and 2015	(2)	(6)	0
Foreign currency translation activities:
Foreign currency translation adjustments, net of taxes of ($37), $31, and $18 in 2016, 2015, and 2014, respectively	50	(204)	(96)
Reclassification into earnings upon sale of foreign entities, net of taxes of ($36) in 2016	119	0	0
Pension and other postretirement benefits:
Prior service credit (cost) arising during the year (Note 10)	0	0	(1)
Amortization of prior service cost (credit) included in net periodic benefit cost, net of taxes of $2, $3 and $3 in 2016, 2015 and 2014, resepctively	(4)	(3)	(5)
Net actuarial gain (loss) arising during the year, net of taxes of $8, ($5) and $60 in 2016, 2015, and 2014, respectively (Note 10)	(15)	8	(100)
Amortization of actuarial (gain) loss included in net periodic benefit cost, net of taxes of ($12), ($18) and ($15) in 2016, 2015, and 2014, respectively	20	28	26
Other comprehensive income (loss)	172	(171)	(176)
Comprehensive income (loss)	(178)	(1,485)	2,163
Less: Comprehensive income (loss) attributable to noncontrolling interests	143	(813)	206
Comprehensive Income (loss) attributable to The Williams Companies, Inc.	$ (321)	$ (672)	$ 1,957

XML

Consolidated Statement of Comprehensive Income (Loss) (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash flow hedging activities:
Other Comprehensive Income, Unrealized Gain (Loss) on Derivatives Arising During Period, Tax	$ (1)	$ 0	$ 0
Other Comprehensive Income Loss Reclassification Adjustment On Derivatives Included In Net Income Tax	1	1	0
Foreign currency translation activities:
Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Tax	(37)	31	18
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Reclassification Adjustment from AOCI, Realized upon Sale or Liquidation, Tax	(36)	0	0
Pension and other postretirement benefits:
Other Comprehensive Income Loss Pension And Other Postretirement Benefit Plans, Benefit Plan Improvement, Tax Effect	0	0	0
Other Comprehensive Income Amortization Of Defined Benefit Plan Net Prior Service Cost Recognized In Net Periodic Pension Cost Tax	2	3	3
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, Tax	8	(5)	60
Other Comprehensive Income Loss Reclassification Pension And Other Postretirement Benefit Plans Net Gain Loss Recognized In Net Periodic Benefit Cost Tax	$ (12)	$ (18)	$ (15)

XML

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 170	$ 100
Trade accounts and other receivables (net of allowance of $6 at December 31, 2016 and $3 at December 31, 2015)	938	1,041
Inventories	138	127
Other current assets and deferred charges	216	259
Total current assets	1,462	1,527
Investments	6,701	7,336
Property, plant, and equipment – net	28,428	29,579
Intangible assets – net of accumulated amortization	9,663	10,017
Regulatory assets, deferred charges, and other	581	561
Total assets	46,835	49,020
Current liabilities:
Accounts payable	623	744
Accrued liabilities	1,448	1,078
Commercial paper	93	499
Long-term debt due within one year	785	176
Total current liabilities	2,949	2,497
Long-term debt	22,624	23,812
Deferred income tax liabilities	4,238	4,218
Regulatory liabilities, deferred income, and other	2,978	2,268
Contingent liabilities and commitments (Note 18)
Stockholders’ equity:
Common stock (960 million shares authorized at $1 par value; 785 million shares issued at December 31, 2016 and 784 million shares issued at December 31, 2015)	785	784
Capital in excess of par value	14,887	14,807
Retained deficit	(9,649)	(7,960)
Accumulated other comprehensive income (loss)	(339)	(442)
Treasury stock, at cost (35 million shares of common stock)	(1,041)	(1,041)
Total stockholders’ equity	4,643	6,148
Noncontrolling interests in consolidated subsidiaries	9,403	10,077
Total equity	14,046	16,225
Total liabilities and equity	$ 46,835	$ 49,020

XML

Consolidated Balance Sheet (Parenthetical) - USD ($) shares in Millions, $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Stockholders’ equity:
Common stock, shares authorized	960	960
Common stock, par value per share	$ 1	$ 1
Common Stock, shares issued	785	784
Treasury stock, shares of common stock	35	35
Allowance for trade accounts and other receivables	$ 6	$ 3

XML

Consolidated Statement of Changes in Equity - USD ($) $ in Millions	Total	Common Stock	Capital in Excess of Par Value	Retained Earnings	Accumulated Other Comprehensive Income (Loss)	Treasury Stock	Total Stockholders' Equity	Noncontrolling Interests
Beginning balance at Dec. 31, 2013	$ 8,921	$ 718	$ 11,599	$ (6,248)	$ (164)	$ (1,041)	$ 4,864	$ 4,057
Net income (loss)	2,339	0	0	2,114	0	0	2,114	225
Other comprehensive income (loss)	(176)	0	0	0	(157)	0	(157)	(19)
Issuance of common stock for acquisition of business (Note 15)	3,378	61	3,317	0	0	0	3,378	0
Noncontrolling interest resulting from acquisition of business (Note 2)	7,502	0	0	0	0	0	0	7,502
Cash dividends - common stock (Note 15)	(1,412)	0	0	(1,412)	0	0	(1,412)	0
Dividends and distributions to noncontrolling interests	(840)	0	0	0	0	0	0	(840)
Stock-based compensation and related common stock issuances, net of tax	88	3	85	0	0	0	88	0
Sales of limited partner units of Williams Partners L.P.	55	0	0	0	0	0	0	55
Changes in ownership of consolidated subsidiaries, net	44	0	(73)	0	(20)	0	(93)	137
Contributions from noncontrolling interests	340	0	0	0	0	0	0	340
Deconsolidation of Bluegrass Pipeline (Note 6)	(63)	0	0	0	0	0	0	(63)
Other	(4)	0	(3)	(2)	0	0	(5)	1
Net increase (decrease) in equity	11,251	64	3,326	700	(177)	0	3,913	7,338
Ending balance at Dec. 31, 2014	20,172	782	14,925	(5,548)	(341)	(1,041)	8,777	11,395
Net income (loss)	(1,314)	0	0	(571)	0	0	(571)	(743)
Other comprehensive income (loss)	(171)	0	0	0	(101)	0	(101)	(70)
Cash dividends - common stock (Note 15)	(1,836)	0	0	(1,836)	0	0	(1,836)	0
Dividends and distributions to noncontrolling interests	(942)	0	0	0	0	0	0	(942)
Stock-based compensation and related common stock issuances, net of tax	30	2	28	0	0	0	30	0
Sales of limited partner units of Williams Partners L.P.	59	0	0	0	0	0	0	59
Changes in ownership of consolidated subsidiaries, net	94	0	(160)	0	0	0	(160)	254
Contributions from noncontrolling interests	111	0	0	0	0	0	0	111
Other	22	0	14	(5)	0	0	9	13
Net increase (decrease) in equity	(3,947)	2	(118)	(2,412)	(101)	0	(2,629)	(1,318)
Ending balance at Dec. 31, 2015	16,225	784	14,807	(7,960)	(442)	(1,041)	6,148	10,077
Net income (loss)	(350)	0	0	(424)	0	0	(424)	74
Other comprehensive income (loss)	172	0	0	0	103	0	103	69
Cash dividends - common stock (Note 15)	(1,261)	0	0	(1,261)	0	0	(1,261)	0
Dividends and distributions to noncontrolling interests	(940)	0	0	0	0	0	0	(940)
Stock-based compensation and related common stock issuances, net of tax	57	1	56	0	0	0	57	0
Sales of limited partner units of Williams Partners L.P.	114	0	0	0	0	0	0	114
Changes in ownership of consolidated subsidiaries, net	(6)	0	12	0	0	0	12	(18)
Contributions from noncontrolling interests	29	0	0	0	0	0	0	29
Other	6	0	12	(4)	0	0	8	(2)
Net increase (decrease) in equity	(2,179)	1	80	(1,689)	103	0	(1,505)	(674)
Ending balance at Dec. 31, 2016	$ 14,046	$ 785	$ 14,887	$ (9,649)	$ (339)	$ (1,041)	$ 4,643	$ 9,403

XML

Consolidated Statement of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
OPERATING ACTIVITIES:
Net income (loss)	$ (350)	$ (1,314)	$ 2,339
Adjustments to reconcile to net cash provided (used) by operating activities:
Depreciation and amortization	1,763	1,738	1,176
Provision (benefit) for deferred income taxes	(26)	(337)	1,264
Impairment of goodwill	0	1,098	0
Impairment of equity-method investments	430	1,359	0
Impairment of and net (gain) loss on sale of assets and businesses	918	215	67
Amortization of stock-based awards	73	82	53
Gain on remeasurement of equity-method investment	0	0	(2,544)
Cash provided (used) by changes in current assets and liabilities:
Accounts and notes receivable	82	39	(276)
Inventories	(25)	105	(36)
Other current assets and deferred charges	(4)	4	(44)
Accounts payable	25	(90)	(8)
Accrued liabilities	506	26	(203)
Other, including changes in noncurrent assets and liabilities	272	(247)	327
Net cash provided (used) by operating activities	3,664	2,678	2,115
FINANCING ACTIVITIES:
Proceeds from (payments of) commercial paper – net	(409)	(306)	572
Proceeds from long-term debt	6,528	9,772	7,321
Payments of long-term debt	(7,091)	(6,516)	(1,828)
Proceeds from issuance of common stock	9	27	3,416
Proceeds from sale of limited partner units of consolidated partnership	114	59	55
Dividends paid	(1,261)	(1,836)	(1,412)
Dividends and distributions paid to noncontrolling interests	(940)	(942)	(840)
Contributions from noncontrolling interests	29	111	340
Payments for debt issuance costs	(9)	(35)	(40)
Special distribution from Gulfstream	0	396	0
Contribution to Gulfstream for repayment of debt	(148)	(248)	0
Other – net	0	(1)	17
Net cash provided (used) by financing activities	(3,178)	481	7,601
INVESTING ACTIVITIES:
Capital expenditures (1)	(2,051)	(3,167)	(4,031)
Net proceeds from dispositions	30	3	34
Proceeds from sale of businesses, net of cash divested	1,020	0	0
Purchases of businesses, net of cash acquired	0	(112)	(5,958)
Purchases of and contributions to equity-method investments	(177)	(595)	(482)
Distributions from unconsolidated affiliates in excess of cumulative earnings	472	404	206
Other – net	290	168	74
Net cash provided (used) by investing activities	(416)	(3,299)	(10,157)
Increase (decrease) in cash and cash equivalents	70	(140)	(441)
Cash and cash equivalents at beginning of year	100	240	681
Cash and cash equivalents at end of year	170	100	240
(1) Increases to property, plant, and equipment	(1,912)	(3,024)	(3,916)
Changes in related accounts payable and accrued liabilities	(139)	(143)	(115)
Capital expenditures (1)	$ (2,051)	$ (3,167)	$ (4,031)

XML

General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

General, Description of Business, Basis of Presentation and Summary Of Significant Accounting Policies [Text Block]

Note 1 – General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies

General

Unless the context clearly indicates otherwise, references in this report to “Williams,” “we,” “our,” “us,” or like terms refer to The Williams Companies, Inc. and its subsidiaries. Unless the context clearly indicates otherwise, references to “Williams,” “we,” “our,” and “us” include the operations in which we own interests accounted for as equity-method investments that are not consolidated in our financial statements. When we refer to our equity investees by name, we are referring exclusively to their businesses and operations.

Financial Repositioning

In January 2017, we announced agreements with Williams Partners L.P. (WPZ), wherein we permanently waived the general partner’s incentive distribution rights (IDRs) and converted our 2 percent general partner interest in WPZ to a non-economic interest in exchange for 289 million newly issued WPZ common units. Pursuant to this agreement, we also purchased approximately 277 thousand WPZ common units for $10 million. Additionally, we purchased approximately 59 million common units of WPZ at a price of $36.08586 per unit in a private placement transaction, funded with proceeds from our equity offering (see Note 15 – Stockholders’ Equity). According to the terms of this agreement, following WPZ’s quarterly distribution in February 2017, we paid additional consideration of approximately $50 millionto WPZ for these units. Following these transactions, we own a 74 percent limited partner interest in WPZ.

Termination of WPZ Merger Agreement

On May 12, 2015, we entered into an agreement for a unit-for-stock transaction whereby we would have acquired all of the publicly held outstanding common units of WPZ in exchange for shares of our common stock (WPZ Merger Agreement).

On September 28, 2015, we entered into a Termination Agreement and Release (Termination Agreement), terminating the WPZ Merger Agreement. Under the terms of the Termination Agreement, we were required to pay a $428 million termination fee to WPZ, at which time we owned approximately 60 percent, including the interests of the general partner and IDRs. Such termination fee settled through a reduction of quarterly incentive distributions we were entitled to receive from WPZ (such reduction not to exceed $209 million per quarter). The distributions from WPZ in November 2015, February 2016, and May 2016 were reduced by $209 million, $209 million, and $10 million, respectively, related to this termination fee.

ACMP Merger

On February 2, 2015, Williams Partners L.P. merged with and into Access Midstream Partners, L.P. (ACMP Merger). For the purpose of these financial statements and notes, WPZ refers to the renamed merged partnership, while Pre-merger Access Midstream Partners, L.P. (ACMP) and Pre-merger Williams Partners L.P. (Pre-merger WPZ) refer to the separate partnerships prior to the consummation of the ACMP Merger and subsequent name change. The net assets of Pre-merger WPZ and ACMP were combined at our historical basis. Our basis in ACMP reflected our business combination accounting resulting from acquiring control of ACMP on July 1, 2014.

Description of Business

We are a Delaware corporation whose common stock is listed and traded on the New York Stock Exchange. Our operations are located principally in the United States and are organized into the Williams Partners and Williams NGL & Petchem Services reportable segments. All remaining business activities are included in Other. For periods after the ACMP Acquisition (see Note 2 – Acquisitions), the acquired ACMP business is reported within Williams Partners. For periods prior to the ACMP Acquisition, the results associated with our former equity-method investment in ACMP are reported within Other.

Williams Partners

Williams Partners consists of our consolidated master limited partnership, WPZ, and primarily includes gas pipeline and midstream businesses.

WPZ’s gas pipeline businesses primarily consist of two interstate natural gas pipelines, which are Transcontinental Gas Pipe Line Company, LLC (Transco) and Northwest Pipeline LLC (Northwest Pipeline), and several joint venture investments in interstate and intrastate natural gas pipeline systems, including a 50 percent equity-method investment in Gulfstream Natural Gas System, L.L.C. (Gulfstream), and a 41 percent interest in Constitution Pipeline Company, LLC (Constitution) (a consolidated entity), which is under development.

WPZ’s midstream businesses primarily consist of (1) natural gas gathering, treating, compression, and processing; (2) natural gas liquid (NGL) fractionation, storage, and transportation; (3) crude oil production handling and transportation; and (4) olefins production. The primary service areas are concentrated in major producing basins in Colorado, Texas, Oklahoma, Kansas, New Mexico, Wyoming, the Gulf of Mexico, Louisiana, Pennsylvania, West Virginia, New York, and Ohio which include the Barnett, Eagle Ford, Haynesville, Marcellus, Niobrara, and Utica Shale plays as well as the Mid-Continent region.

The midstream businesses include equity-method investments in natural gas gathering and processing assets and NGL fractionation and transportation assets, including a 62 percent equity-method investment in Utica East Ohio Midstream, LLC (UEOM), a 50 percent equity-method investment in the Delaware basin gas gathering system (DBJV) in the Mid-Continent region, a 69 percent equity-method investment in Laurel Mountain Midstream, LLC (Laurel Mountain), a 58 percent equity-method investment in Caiman Energy II, LLC (Caiman II), a 60 percent equity-method investment in Discovery Producer Services, LLC (Discovery), a 50 percent equity-method investment in Overland Pass Pipeline, LLC (OPPL), and Appalachia Midstream Services, LLC, which owns equity-method investments with an approximate average 41 percent interest in multiple gathering systems in the Marcellus Shale (Appalachia Midstream Investments).

The midstream businesses also included our Canadian midstream operations, which were comprised of an oil sands offgas processing plant located near Fort McMurray, Alberta, and an NGL/olefin fractionation facility at Redwater, Alberta. In September 2016, we completed the sale of our Canadian operations. (See Note 3 – Divestiture.)

Williams NGL & Petchem Services

Williams NGL & Petchem Services includes certain other domestic olefins pipeline assets, a liquids extraction plant located near Fort McMurray, Alberta, that began operations in March 2016, and a propane dehydrogenation facility under development in Canada. In September 2016, we completed the sale of our Canadian operations. (See Note 3 – Divestiture.)

Other

Other includes other business activities that are not operating segments, as well as corporate operations.

Basis of Presentation

Canada Dropdown

In February 2014, we contributed certain Canadian operations to Pre-merger WPZ (Canada Dropdown) for total consideration of $56 million of cash from Pre-merger WPZ (including a $31 million post-closing adjustment received in the second quarter of 2014), 25,577,521 Pre-merger WPZ Class D limited-partner units, and an increase in the capital account of its general partner to allow us to maintain our 2 percent general partner interest. In lieu of cash distributions, the Class D units received quarterly distributions of additional paid-in-kind Class D units.

In October 2014, a purchase price adjustment was finalized whereby we paid $56 million in cash to Pre-merger WPZ in the fourth quarter and waived $2 million in payment of IDRs with respect to the November 2014 distribution.

Consolidated master limited partnership

As of December 31, 2016, we owned approximately 60 percent of the interests in WPZ, a variable interest entity (VIE) (see Note 4 – Variable Interest Entities), including the interests of the general partner, which are wholly owned by us, and IDRs.

During 2016, WPZ issued 3,273,601 common units pursuant to an equity distribution agreement between WPZ and certain banks resulting in net proceeds of $115 million. WPZ also implemented a distribution reinvestment program in the third quarter of 2016 resulting in 7,891,414 common units issued associated with reinvested distributions of $260 million, of which $250 million related to our participation. In addition, in August 2016, WPZ completed an equity issuance of 6,975,446 common units sold to us in a private placement transaction for an aggregate purchase price of $250 million.

The above transactions, WPZ’s quarterly distribution of additional paid-in-kind Class B units to us, and other equity issuances by WPZ had the combined net impact of decreasing Noncontrolling interests in consolidated subsidiaries by $18 million, and increasing Capital in excess of par value by $12 million and Deferred income tax liabilities by $6 million in the Consolidated Balance Sheet.

WPZ is self-funding and maintains separate lines of bank credit and cash management accounts and also has a commercial paper program. (See Note 14 – Debt, Banking Arrangements, and Leases.) Cash distributions from WPZ to all partners, including us, are governed by WPZ’s partnership agreement.

Discontinued operations

Unless indicated otherwise, the information in the Notes to Consolidated Financial Statements relates to our continuing operations.

Significant risks and uncertainties

We have announced plans to monetize our olefins production plant in Geismar, Louisiana, as well as other select assets that are not core to our strategy. As we pursue these other select asset monetizations, it is possible that we may incur impairments of certain equity-method investments, property, plant, and equipment, and intangible assets. Such impairments could potentially be caused by indications of fair value implied through the monetization process or, in the case of asset dispositions that are part of a broader asset group, the impact of the loss of future estimated cash flows.

Summary of Significant Accounting Policies

Principles of consolidation

The consolidated financial statements include the accounts of all entities that we control and our proportionate interest in the accounts of certain ventures in which we own an undivided interest. Management’s judgment is required to evaluate whether we control an entity. Key areas of that evaluation include:

• Determining whether an entity is a VIE;

• Determining whether we are the primary beneficiary of a VIE, including evaluating which activities of the VIE most significantly impact its economic performance and the degree of power that we and our related parties have over those activities through our variable interests;

• Identifying events that require reconsideration of whether an entity is a VIE and continuously evaluating whether we are a VIE’s primary beneficiary;

• Evaluating whether other owners in entities that are not VIEs are able to effectively participate in significant decisions that would be expected to be made in the ordinary course of business such that we do not have the power to control such entities.

We apply the equity method of accounting to investments over which we exercise significant influence but do not control.

Equity-method investment basis differences

Differences between the cost of our equity-method investments and our underlying equity in the net assets of investees are accounted for as if the investees were consolidated subsidiaries. Equity earnings (losses) in the Consolidated Statement of Operations includes our allocable share of net income (loss) of investees adjusted for any depreciation and amortization, as applicable, associated with basis differences.

Use of estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual results could differ from those estimates.

Significant estimates and assumptions include:

• Impairment assessments of investments, property, plant, and equipment, goodwill, and other identifiable intangible assets;

• Litigation-related contingencies;

• Environmental remediation obligations;

• Realization of deferred income tax assets;

• Depreciation and/or amortization of equity-method investment basis differences;

• Asset retirement obligations;

• Pension and postretirement valuation variables;

• Acquisition related purchase price allocations.

These estimates are discussed further throughout these notes.

Regulatory accounting

Transco and Northwest Pipeline are regulated by the Federal Energy Regulatory Commission (FERC). Their rates, which are established by the FERC, are designed to recover the costs of providing the regulated services, and their competitive environment makes it probable that such rates can be charged and collected. Therefore, our management has determined that it is appropriate under Accounting Standards Codification (ASC) Topic 980, “Regulated Operations,” to account for and report regulatory assets and liabilities related to these operations consistent with the economic effect of the way in which their rates are established. Accounting for these operations that are regulated can differ from the accounting requirements for nonregulated operations. For example, for regulated operations, allowance for funds used during construction (AFUDC) represents the estimated cost of debt and equity funds applicable to utility plant in process of construction and is capitalized as a cost of property, plant, and equipment because it constitutes an actual cost of construction under established regulatory practices; nonregulated operations are only allowed to capitalize the cost of debt funds related to construction activities, while a component for equity is prohibited. The components of our regulatory assets and liabilities relate to the effects of deferred taxes on equity funds used during construction, asset retirement obligations, fuel cost differentials, levelized incremental depreciation, negative salvage, and pension and other postretirement benefits. Our current and noncurrent regulatory asset and liability balances for the years ended December 31, 2016 and 2015 are as follows:

	December 31,
	2016		2015
	(Millions)
Current assets reported within Other current assets and deferred charges	$	91	$	84
Noncurrent assets reported within Regulatory assets, deferred charges, and other	387		370
Total regulated assets	$	478	$	454
Current liabilities reported within Accrued liabilities	$	11	$	4
Noncurrent liabilities reported within Regulatory liabilities, deferred income, and other	498		434
Total regulated liabilities	$	509	$	438

Cash and cash equivalents

Cash and cash equivalents in the Consolidated Balance Sheet includes amounts primarily invested in funds with high-quality, short-term securities and instruments that are issued or guaranteed by the U.S. government. These have maturity dates of three months or less when acquired.

Accounts receivable

Accounts receivable are carried on a gross basis, with no discounting, less an allowance for doubtful accounts. We estimate the allowance for doubtful accounts based on existing economic conditions, the financial condition of our customers, and the amount and age of past due accounts. We consider receivables past due if full payment is not received by the contractual due date. Interest income related to past due accounts receivable is generally recognized at the time full payment is received or collectability is assured. Past due accounts are generally written off against the allowance for doubtful accounts only after all collection attempts have been exhausted.

Inventories

Inventories in the Consolidated Balance Sheet primarily consist of natural gas liquids, olefins, natural gas in underground storage, and materials and supplies and are stated at the lower of cost or market. The cost of inventories is primarily determined using the average-cost method.

Property, plant, and equipment

Property, plant, and equipment is recorded at cost. We base the carrying value of these assets on estimates, assumptions, and judgments relative to capitalized costs, useful lives, and salvage values.

As regulated entities, Northwest Pipeline and Transco provide for depreciation using the straight-line method at FERC-prescribed rates. Depreciation for nonregulated entities is provided primarily on the straight-line method over estimated useful lives, except for certain offshore facilities that apply an accelerated depreciation method.

Gains or losses from the ordinary sale or retirement of property, plant, and equipment for regulated pipelines are credited or charged to accumulated depreciation. Other gains or losses are recorded in Other (income) expense – net included in Operating income (loss) in the Consolidated Statement of Operations.

Ordinary maintenance and repair costs are generally expensed as incurred. Costs of major renewals and replacements are capitalized as property, plant, and equipment.

We record a liability and increase the basis in the underlying asset for the present value of each expected future asset retirement obligation (ARO) at the time the liability is initially incurred, typically when the asset is acquired or constructed. As regulated entities, Northwest Pipeline and Transco offset the depreciation of the underlying asset that is attributable to capitalized ARO cost to a regulatory asset as management expects to recover these amounts in future rates. We measure changes in the liability due to passage of time by applying an interest rate to the liability balance. This amount is recognized as an increase in the carrying amount of the liability and as a corresponding accretion expense included in Operating and maintenance expenses in the Consolidated Statement of Operations, except for regulated entities, for which the liability is offset by a regulatory asset. The regulatory asset is amortized commensurate with our collection of those costs in rates.

Measurements of AROs include, as a component of future expected costs, an estimate of the price that a third party would demand, and could expect to receive, for bearing the uncertainties inherent in the obligations, sometimes referred to as a market-risk premium.

Goodwill

Goodwill included within Intangible assets – net of accumulated amortization in the Consolidated Balance Sheet represents the excess of the consideration, plus the fair value of any noncontrolling interest or any previously held equity interest, over the fair value of the net assets acquired. It is not subject to amortization but is evaluated annually as of October 1 for impairment or more frequently if impairment indicators are present that would indicate it is more likely than not that the fair value of the reporting unit is less than its carrying amount. As part of the evaluation, we compare our estimate of the fair value of the reporting unit with its carrying value, including goodwill. If the carrying value of the reporting unit exceeds its fair value, a computation of the implied fair value of the goodwill is compared with its related carrying value. If the carrying value of the reporting unit goodwill exceeds the implied fair value of that goodwill, an impairment loss is recognized in the amount of the excess. Judgments and assumptions are inherent in our management’s estimates of fair value.

Other intangible assets

Our identifiable intangible assets included within Intangible assets – net of accumulated amortization in the Consolidated Balance Sheet are primarily related to gas gathering, processing, and fractionation contractual customer relationships. Our intangible assets are amortized on a straight-line basis over the period in which these assets contribute to our cash flows. We evaluate these assets for changes in the expected remaining useful lives and would reflect any changes prospectively through amortization over the revised remaining useful life.

Impairment of property, plant, and equipment, other identifiable intangible assets, and investments

We evaluate our property, plant, and equipment and other identifiable intangible assets for impairment when events or changes in circumstances indicate, in our management’s judgment, that the carrying value of such assets may not be recoverable. When an indicator of impairment has occurred, we compare our management’s estimate of undiscounted future cash flows attributable to the assets to the carrying value of the assets to determine whether an impairment has occurred and we may apply a probability-weighted approach to consider the likelihood of different cash flow assumptions and possible outcomes including selling in the near term or holding for the remaining estimated useful life. If an impairment of the carrying value has occurred, we determine the amount of the impairment recognized in the financial statements by estimating the fair value of the assets and recording a loss for the amount that the carrying value exceeds the estimated fair value. This evaluation is performed at the lowest level for which separately identifiable cash flows exist.

For assets identified to be disposed of in the future and considered held for sale, we compare the carrying value to the estimated fair value less the cost to sell to determine if recognition of an impairment is required. Until the assets are disposed of, the estimated fair value, which includes estimated cash flows from operations until the assumed date of sale, is recalculated when related events or circumstances change.

We evaluate our investments for impairment when events or changes in circumstances indicate, in our management’s judgment, that the carrying value of such investments may have experienced an other-than-temporary decline in value. When evidence of loss in value has occurred, we compare our estimate of fair value of the investment to the carrying value of the investment to determine whether an impairment has occurred. If the estimated fair value is less than the carrying value and we consider the decline in value to be other-than-temporary, the excess of the carrying value over the fair value is recognized in the consolidated financial statements as an impairment charge.

Judgments and assumptions are inherent in our management’s estimate of undiscounted future cash flows and an asset’s or investment’s fair value. Additionally, judgment is used to determine the probability of sale with respect to assets considered for disposal.

Deferred income

We record a liability for deferred income related to cash received from customers in advance of providing our services.  Such amounts are generally recognized in revenue upon satisfying our performance obligations, primarily providing services based on units of production or over remaining contractual service periods ranging from 1 to 25 years.  Deferred incomeis reflected within Accrued liabilitiesand Regulatory liabilities, deferred income, and otheron the Consolidated Balance Sheet.  (See Note 13 – Accrued Liabilities.) 

During 2016, we received cash proceeds totaling $820 million associated with restructuring certain gas gathering contracts in the Barnett Shale and Mid-Continent regions. The proceeds were recorded as deferred incomeand are being amortized into income in 2016 and future periods.

In October 2016, we received $104 million of newly constructed assets as part of a noncash investing transaction with a customer for which we provide production handling and other services. The transaction was recorded in Property, plant, and equipment – net and deferred income in the Consolidated Balance Sheet and is being amortized based on units of production through 2024. Due to the noncash nature of this transaction, it is not presented within the Consolidated Statement of Cash Flows.

Contingent liabilities

We record liabilities for estimated loss contingencies, including environmental matters, when we assess that a loss is probable and the amount of the loss can be reasonably estimated. These liabilities are calculated based upon our assumptions and estimates with respect to the likelihood or amount of loss and upon advice of legal counsel, engineers, or other third parties regarding the probable outcomes of the matters. These calculations are made without consideration of any potential recovery from third parties. We recognize insurance recoveries or reimbursements from others when realizable. Revisions to these liabilities are generally reflected in income when new or different facts or information become known or circumstances change that affect the previous assumptions or estimates.

Cash flows from revolving credit facilities and commercial paper program

Proceeds and payments related to borrowings under our credit facilities are reflected in the financing activities in the Consolidated Statement of Cash Flows on a gross basis. Proceeds and payments related to borrowings under our commercial paper program are reflected in the financing activities in the Consolidated Statement of Cash Flows on a net basis, as the outstanding notes generally have maturity dates less than three months from the date of issuance. (See Note 14 – Debt, Banking Arrangements, and Leases.)

Treasury stock

Treasury stock purchases are accounted for under the cost method whereby the entire cost of the acquired stock is recorded as Treasury stock in the Consolidated Balance Sheet. Gains and losses on the subsequent reissuance of shares are credited or charged to Capital in excess of par value in the Consolidated Balance Sheet using the average-cost method.

Derivative instruments and hedging activities

We may utilize derivatives to manage a portion of our commodity price risk. These instruments consist primarily of swaps, futures, and forward contracts involving short- and long-term purchases and sales of energy commodities. We report the fair value of derivatives, except those for which the normal purchases and normal sales exception has been elected, in Other current assets and deferred charges; Regulatory assets, deferred charges, and other;Accrued liabilities; or Regulatory liabilities, deferred income, and other in the Consolidated Balance Sheet. We determine the current and noncurrent classification based on the timing of expected future cash flows of individual trades. We report these amounts on a gross basis. Additionally, we report cash collateral receivables and payables with our counterparties on a gross basis. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk.)

The accounting for the changes in fair value of a commodity derivative can be summarized as follows:

Derivative Treatment	Accounting Method
Normal purchases and normal sales exception	Accrual accounting
Designated in a qualifying hedging relationship	Hedge accounting
All other derivatives	Mark-to-market accounting

We may elect the normal purchases and normal sales exception for certain short- and long-term purchases and sales of physical energy commodities. Under accrual accounting, any change in the fair value of these derivatives is not reflected on the balance sheet after the initial election of the exception.

We may also designate a hedging relationship for certain commodity derivatives. For a derivative to qualify for designation in a hedging relationship, it must meet specific criteria and we must maintain appropriate documentation. We establish hedging relationships pursuant to our risk management policies. We evaluate the hedging relationships at the inception of the hedge and on an ongoing basis to determine whether the hedging relationship is, and is expected to remain, highly effective in achieving offsetting changes in fair value or cash flows attributable to the underlying risk being hedged. We also regularly assess whether the hedged forecasted transaction is probable of occurring. If a derivative ceases to be or is no longer expected to be highly effective, or if we believe the likelihood of occurrence of the hedged forecasted transaction is no longer probable, hedge accounting is discontinued prospectively, and future changes in the fair value of the derivative are recognized currently in Product sales or Product costsin the Consolidated Statement of Operations.

For commodity derivatives designated as a cash flow hedge, the effective portion of the change in fair value of the derivative is reported in Accumulated other comprehensive income (loss) (AOCI) in the Consolidated Balance Sheet and reclassified into earnings in the period in which the hedged item affects earnings. Any ineffective portion of the derivative’s change in fair value is recognized currently in Product sales or Product costs in the Consolidated Statement of Operations. Gains or losses deferred in AOCI associated with terminated derivatives, derivatives that cease to be highly effective hedges, derivatives for which the forecasted transaction is reasonably possible but no longer probable of occurring, and cash flow hedges that have been otherwise discontinued remain in AOCI until the hedged item affects earnings. If it becomes probable that the forecasted transaction designated as the hedged item in a cash flow hedge will not occur, any gain or loss deferred in AOCI is recognized in Product sales or Product costs in the Consolidated Statement of Operations at that time. The change in likelihood of a forecasted transaction is a judgmental decision that includes qualitative assessments made by management.

For commodity derivatives that are not designated in a hedging relationship, and for which we have not elected the normal purchases and normal sales exception, we report changes in fair value currently in Product salesorProduct costsin the Consolidated Statement of Operations.

Certain gains and losses on derivative instruments included in the Consolidated Statement of Operations are netted together to a single net gain or loss, while other gains and losses are reported on a gross basis. Gains and losses recorded on a net basis include unrealized gains and losses on all derivatives that are not designated as hedges and for which we have not elected the normal purchases and normal sales exception.

Realized gains and losses on derivatives that require physical delivery, as well as natural gas derivatives for NGL processing activities and which are not held for trading purposes nor were entered into as a pre-contemplated buy/sell arrangement, are recorded on a gross basis.

Revenue recognition

Revenues

As a result of the ratemaking process, certain revenues collected by us may be subject to refunds upon the issuance of final orders by the FERC in pending rate proceedings. We record estimates of rate refund liabilities considering our and other third-party regulatory proceedings, advice of counsel, and other risks.

Service revenues

Revenues from our interstate natural gas pipeline businesses include services pursuant to long-term firm transportation and storage agreements. These agreements provide for a reservation charge based on the volume of contracted capacity and a commodity charge based on the volume of gas delivered, both at rates specified in our FERC tariffs. We recognize revenues for reservation charges ratably over the contract period regardless of the volume of natural gas that is transported or stored. Revenues for commodity charges, from both firm and interruptible transportation services and storage injection and withdrawal services, are recognized when natural gas is delivered at the agreed upon delivery point or when natural gas is injected or withdrawn from the storage facility.

Certain revenues from our midstream operations include those derived from natural gas gathering, processing, treating, and compression services and are performed under volumetric-based fee contracts. These revenues are recorded when services have been performed.

Certain of our gas gathering and processing agreements have minimum volume commitments. If a customer under such an agreement fails to meet its minimum volume commitment for a specified period, generally measured on an annual basis, it is obligated to pay a contractually determined fee based upon the shortfall between actual production volumes and the minimum volume commitment for that period. The revenue associated with minimum volume commitments is recognized in the period that the actual shortfall is determined and is no longer subject to future reduction or offset, which is generally at the end of the annual period or fourth quarter.

Crude oil gathering and transportation revenues and offshore production handling fees are recognized when the services have been performed. Certain offshore production handling contracts contain fixed payment terms that result in the deferral of revenues until such services have been performed or such capacity has been made available.

Storage revenues from our midstream operations associated with prepaid contracted storage capacity contracts are recognized on a straight-line basis over the life of the contract as services are provided.

Product sales

In the course of providing transportation services to customers of our interstate natural gas pipeline businesses, we may receive different quantities of gas from shippers than the quantities delivered on behalf of those shippers. The resulting imbalances are primarily settled through the purchase and sale of gas with our customers under terms provided for in our FERC tariffs. Revenue is recognized from the sale of gas upon settlement of the transportation and exchange imbalances.

We market NGLs, crude oil, natural gas, and olefins that we purchase from our producer customers as part of the overall service provided to producers. Revenues from marketing NGLs are recognized when the products have been sold and delivered.

Under our keep-whole and percent-of-liquids processing contracts, we retain the rights to all or a portion of the NGLs extracted from the producers’ natural gas stream and recognize revenues when the extracted NGLs are sold and delivered.

Our domestic olefins business produces olefins from purchased or produced feedstock and we recognize revenues when the olefins are sold and delivered.

Our Canadian businesses that were sold in September 2016 had processing and fractionation operations where we retained certain NGLs and olefins from an upgrader’s offgas stream and we recognized revenues when the fractionated products were sold and delivered.

Interest capitalized

We capitalize interest during construction on major projects with construction periods of at least 3 months and a total project cost in excess of $1 million. Interest is capitalized on borrowed funds and, where regulation by the FERC exists, on internally generated funds (equity AFUDC). The latter is included in Other income (expense) – net below Operating income (loss) in the Consolidated Statement of Operations. The rates used by regulated companies are calculated in accordance with FERC rules. Rates used by nonregulated companies are based on our average interest rate on debt.

Employee stock-based awards

We recognize compensation expense on employee stock-based awards, net of estimated forfeitures, on a straight-line basis. (See Note 16 – Equity-Based Compensation.)

Pension and other postretirement benefits

The funded status of each of the pension and other postretirement benefit plans is recognized separately in the Consolidated Balance Sheet as either an asset or liability. The funded status is the difference between the fair value of plan assets and the plan’s benefit obligation. The plans’ benefit obligations and net periodic benefit costs are actuarially determined and impacted by various assumptions and estimates. (See Note 10 – Employee Benefit Plans.)

The discount rates are determined separately for each of our pension and other postretirement benefit plans based on an approach specific to our plans. The year-end discount rates are determined considering a yield curve comprised of high-quality corporate bonds and the timing of the expected benefit cash flows of each plan.

The expected long-term rates of return on plan assets are determined by combining a review of the historical returns within the portfolio, the investment strategy included in the plans’ investment policy statement, and capital market projections for the asset classes in which the portfolio is invested, as well as the weighting of each asset class.

Unrecognized actuarial gains and losses and unrecognized prior service costs and credits are deferred and recorded in AOCI or, for Transco and Northwest Pipeline, as a regulatory asset or liability, until amortized as a component of net periodic benefit cost. Unrecognized actuarial gains and losses in excess of 10 percent of the greater of the benefit obligation or the market-related value of plan assets are amortized over the participants’ average remaining future years of service, which is approximately 13 years for our pension plans and approximately 7 years for our other postretirement benefit plans. Unrecognized prior service costs and credits for the other postretirement benefit plans are amortized on a straight line basis over the average remaining years of service to eligibility for eligible plan participants, which is approximately 4 years.

The expected return on plan assets component of net periodic benefit cost is calculated using the market-related value of plan assets. For our pension plans, the market-related value of plan assets is equal to the fair value of plan assets adjusted to reflect the amortization of gains or losses associated with the difference between the expected and actual return on plan assets over a 5-year period. Additionally, the market-related value of assets may be no more than 110 percent or less than 90 percent of the fair value of plan assets at the beginning of the year. The market-related value of plan assets for our other postretirement benefit plans is equal to the unadjusted fair value of plan assets at the beginning of the year.

Income taxes

We include the operations of our domestic corporate subsidiaries and income from our subsidiary partnerships in our consolidated federal income tax return and also file tax returns in various foreign and state jurisdictions as required. Deferred income taxes are computed using the liability method and are provided on all temporary differences between the financial basis and the tax basis of our assets and liabilities. Our management’s judgment and income tax assumptions are used to determine the levels, if any, of valuation allowances associated with deferred tax assets.

Earnings (loss) per common share

Basic earnings (loss) per common share in the Consolidated Statement of Operations is based on the sum of the weighted-average number of common shares outstanding and vested restricted stock units. Diluted earnings (loss) per common share in the Consolidated Statement of Operations includes any dilutive effect of stock options, nonvested restricted stock units, and convertible debt, unless otherwise noted. Diluted earnings (loss) per common share are calculated using the treasury-stock method.

Foreign currency translation

Certain of our foreign subsidiaries that used the Canadian dollar as their functional currency were sold in 2016. The assets and liabilities of such foreign subsidiaries were translated at the spot rate in effect at the applicable reporting date, and the combined statements of operations were translated into the U.S. dollar at the average exchange rates in effect during the applicable period. The resulting cumulative translation adjustment was recorded as a separate component of AOCI in the Consolidated Balance Sheet.

Transactions denominated in currencies other than the functional currency were recorded based on exchange rates at the time such transactions arose. Subsequent changes in exchange rates when the transactions were settled resulted in transaction gains and losses which were reflected in Other (income) expense – net within Costs and expenses in the Consolidated Statement of Operations. Substantially all of our Canadian operations were sold in September 2016.

Accounting standards issued but not yet adopted

In January 2017, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2017-04 “Intangibles - Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment” (ASU 2017-04). ASU 2017-04 modifies the concept of goodwill impairment to represent the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill. Under ASU 2017-04, entities will no longer be required to determine the implied fair value of goodwill by assigning the fair value of a reporting unit to its individual assets and liabilities as if that reporting unit had been acquired in a business combination. ASU 2017-04 is effective for goodwill impairment testing for interim and annual periods beginning after December 15, 2019, and requires a prospective transition. Early adoption is permitted for interim and annual goodwill impairment tests performed after January 1, 2017, and we plan to adopt this standard in 2017. Our Williams Partners reportable segment has $47 million of goodwill included in Intangible assets – net of accumulated amortization in the Consolidated Balance Sheet (see Note 12 – Goodwill and Other Intangible Assets).

In August 2016, the FASB issued ASU 2016-15 “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments” (ASU 2016-15). ASU 2016-15 provides specific guidance on eight cash flow classification issues, including debt prepayment or debt extinguishment costs and distributions received from equity method investees, to reduce diversity in practice. ASU 2016-15 is effective for interim and annual periods beginning after December 15, 2017. Early adoption is permitted. ASU 2016-15 requires a retrospective transition. We are evaluating the impact of ASU 2016-15 on our consolidated financial statements.

In June 2016, the FASB issued ASU 2016-13 “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments” (ASU 2016-13). ASU 2016-13 changes the impairment model for most financial assets and certain other instruments. For trade and other receivables, held-to-maturity debt securities, loans, and other instruments, entities will be required to use a new forward-looking “expected loss” model that generally will result in the earlier recognition of allowances for losses. The guidance also requires increased disclosures. ASU 2016-13 is effective for interim and annual periods beginning after December 15, 2019. Early adoption is permitted. ASU 2016-13 requires varying transition methods for the different categories of amendments. We are evaluating the impact of ASU 2016-13 on our consolidated financial statements. Although we do not expect ASU 2016-13 to have a significant impact, it will impact our trade receivables as the related allowance for credit losses will be recognized earlier under the expected loss model than under our current policy.

In March 2016, the FASB issued ASU 2016-09 “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting” (ASU 2016-09). The objective of ASU 2016-09 is to simplify several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. ASU 2016-09 is effective for interim and annual periods beginning after December 15, 2016. We adopted ASU 2016-09 effective January 1, 2017. The standard requires varying transition methods for the different categories of amendments. ASU 2016-09 will not have a material effect on our consolidated financial statements.

In February 2016, the FASB issued ASU 2016-02 “Leases (Topic 842)” (ASU 2016-02). ASU 2016-02 establishes a comprehensive new lease accounting model. ASU 2016-02 clarifies the definition of a lease, requires a dual approach to lease classification similar to current lease classifications, and causes lessees to recognize leases on the balance sheet as a lease liability with a corresponding right-of-use asset. ASU 2016-02 is effective for interim and annual periods beginning after December 15, 2018. Early adoption is permitted. ASU 2016-02 requires a modified retrospective transition for capital or operating leases existing at or entered into after the beginning of the earliest comparative period presented in the financial statements. We are reviewing contracts to identify leases, particularly reviewing the applicability of ASU 2016-02 to contracts involving easements/rights-of-way.

In May 2014, the FASB issued ASU 2014-09 establishing Accounting Standards Codification (ASC) Topic 606, “Revenue from Contracts with Customers” (ASC 606). ASC 606 establishes a comprehensive new revenue recognition model designed to depict the transfer of goods or services to a customer in an amount that reflects the consideration the entity expects to be entitled to receive in exchange for those goods or services and requires significantly enhanced revenue disclosures. In August 2015, the FASB issued ASU 2015-14 “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date” (ASU 2015-14). Per ASU 2015-14, the standard is effective for interim and annual reporting periods beginning after December 15, 2017. ASC 606 allows either full retrospective or modified retrospective transition and early adoption is permitted for annual periods beginning after December 15, 2016.

We continue to evaluate the impact the standard may have on our financial statements. For each revenue contract type, we are conducting a formal contract review process to evaluate the impact, if any, that the new revenue standard may have. We have substantially completed that process, but continue to evaluate our accounting for noncash consideration, which exists in contracts where we receive commodities as full or partial consideration, contracts with a significant financing component, which may exist in situations where the timing of the consideration we received varies significantly from the timing of the service we provide, and the accounting for contributions in aid of construction. As such, we are unable to determine the potential impact upon the amount and timing of revenue recognition and related disclosures. Additionally, we have identified possible financial system and internal control changes necessary for adoption. We currently anticipate utilizing a modified retrospective transition upon the adoption of ASC 606 as of January 1, 2018.

XML

Acquisitions

12 Months Ended

Dec. 31, 2016

Business Combinations [Abstract]

Acquisitions [Text Block]

Note 2 – Acquisitions

ACMP

On December 20, 2012, we purchased approximately 24 percent of ACMP’s outstanding limited partnership units and 50 percent of the ACMP general partner 2 percent interest which included IDRs for approximately $2.19 billion in cash, including transaction costs. We accounted for these acquired interests as equity-method investments.

On July 1, 2014, we acquired control of ACMP (ACMP Acquisition) through the acquisition of an additional 26 percent of ACMP’s outstanding limited partnership units and the remaining 50 percent interest in the general partner for $5.995 billion in cash. The acquisition was funded through the issuance of equity (see Note 15 – Stockholders' Equity) and debt, credit facility borrowings, and cash on hand.

At the time of acquisition, ACMP owned, operated, developed, and acquired natural gas gathering systems and other midstream energy assets. The purpose of the acquisition was to enhance our position in the Marcellus and Utica Shale plays, provide additional diversity via the Eagle Ford, Haynesville, Barnett, Mid-Continent, and Niobrara areas, and to fortify our stable, fee-based business model and support our dividend growth strategy.

Our basis in ACMP reflects business combination accounting, which, among other things, requires identifiable assets acquired and liabilities assumed to be measured at their acquisition-date fair values. Prior to the ACMP Acquisition we accounted for our investment in ACMP using the equity method. The acquisition-date fair value of our equity-method investment in ACMP was $4.6 billion. As a result of remeasuring our equity-method investment to fair value, for the year ended December 31, 2014 we recognized a $2.5 billion noncash gain within the Gain on remeasurement of equity-method investment line item in the Consolidated Statement of Operations.

The valuation techniques used to measure the acquisition-date fair value of the ACMP Acquisition, including our previous equity-method investment in ACMP, consisted of valuing the limited partner units and general partner interest separately. The limited partner units, consisting of common and Class B units, were valued based on ACMP’s closing common unit price at July 1, 2014. The general partner interest, including IDRs, was valued on a noncontrolling basis using an income approach based on a discounted cash flow analysis and a market comparison analysis based on comparable guideline companies and an implied fair value from our purchase.

The following table presents the allocation of the acquisition-date fair value of the major classes of the assets acquired, which are presented in the Williams Partners segment, liabilities assumed, and noncontrolling interest at July 1, 2014. The fair value of accounts receivable acquired equaled contractual amounts receivable. Changes to the preliminary allocation disclosed in Exhibit 99.1 of our Form 8-K dated May 6, 2015, which were recorded in the first quarter of 2015, reflect an increase of $150 million in Property, plant, and equipment and $25 million in Goodwill, and a decrease of $168 million in Other intangible assets and $7 million in Investments. These adjustments during the measurement period were not considered significant to require retrospective revisions of our financial statements.

	(Millions)
Accounts receivable	$	168
Other current assets	63
Investments	5,865
Property, plant, and equipment	7,165
Goodwill	499
Other intangible assets	8,841
Current liabilities	(408		)
Debt	(4,052		)
Other noncurrent liabilities	(9		)
Noncontrolling interest in ACMP’s subsidiaries	(958		)
Noncontrolling interest in ACMP	(6,544		)

Other intangible assets recognized in the acquisition are related to contractual customer relationships from gas gathering agreements with our customers. The basis for determining the value of these intangible assets was estimated future net cash flows to be derived from acquired contractual customer relationships discounted using a risk-adjusted discount rate. These intangible assets are being amortized on a straight-line basis over 30 years during which contractual customer relationships are expected to contribute to our cash flows. As estimated at the time of acquisition, approximately 56 percent of the expected future revenues from these contractual customer relationships were impacted by our ability and intent to renew or renegotiate existing customer contracts. We expense costs incurred to renew or extend the terms of our gas gathering, processing, and fractionation contracts with customers. Based on the estimated future revenues during the current contract periods (as estimated at the time of acquisition), the weighted-average periods to the next renewal or extension of the existing customer contracts were approximately 17 years.

The noncash adjustment to record the fair value of the noncontrolling interest in ACMP was determined based on the common units and ACMP’s closing common unit price at July 1, 2014.

The following unaudited pro forma Total revenues and Net income (loss) attributable to The Williams Companies, Inc. for the year ended December 31, 2014, are presented as if the ACMP Acquisition had been completed on January 1, 2014. These pro forma amounts are not necessarily indicative of what the actual results would have been if the acquisition had in fact occurred on the date or for the period indicated, nor do they purport to project Total revenues or Net income (loss) attributable to The Williams Companies, Inc. for any future periods or as of any date. These amounts do not give effect to any potential cost savings, operating synergies, or revenue enhancements to result from the transactions or the potential costs to achieve these cost savings, operating synergies, and revenue enhancements.

	December 31,
	2014
	(Millions)
Total revenues	$	8,181
Net income (loss) attributable to The Williams Companies, Inc.	$	622

Significant adjustments to pro forma Net income (loss) attributable to The Williams Companies, Inc. include the removal of the previously described $2.5 billion gain on remeasurement of equity-method investment, and include additional depreciation and amortization expense associated with reflecting the acquired investments, property, plant, and equipment, and other intangible assets at fair value. The adjustments assume estimated useful lives of 30 years. Other significant adjustments to pro forma Net income (loss) attributable to The Williams Companies, Inc. include interest expense related to debt financing associated with the acquisition as well as Net income (loss) attributable to noncontrolling interests.

During the year ended December 31, 2014, ACMP contributed Total revenues of $781 million and Net income (loss) attributable to The Williams Companies, Inc. of $165 million.

Costs related to this acquisition were $16 million in 2014 and are reported within our Williams Partners segment and included in Selling, general, and administrative expenses in the Consolidated Statement of Operations. Direct transaction costs associated with financing commitments were $9 million in 2014 and reported within Interest incurred in the Consolidated Statement of Operations. Equity earnings (losses) within the Consolidated Statement of Operations in 2014 includes $19 million of equity losses associated with certain compensation-related costs at ACMP that were triggered by the acquisition.

Eagle Ford Gathering System

In May 2015, WPZ acquired a gathering system comprised of approximately 140 miles of pipeline and a sour gas compression facility in the Eagle Ford Shale for $112 million. The acquisition was accounted for as a business combination, and the allocation of the acquisition-date fair value of the major classes of assets acquired includes $80 million of Property, plant, and equipment – net and $32 million of Intangible assets – net of accumulated amortization in the Consolidated Balance Sheet. Changes to the preliminary allocation disclosed in the second quarter of 2015 reflect an increase of $20 million in Property, plant, and equipment – net, and a decrease of $20 million in Intangible assets – net of accumulated amortization.

UEOM Equity-Method Investment

In June 2015, WPZ acquired an approximate 13 percent additional interest in its equity-method investment, UEOM, for $357 million. Following the acquisition WPZ owns approximately 62 percent of UEOM. However, WPZ continues to account for this as an equity-method investment because WPZ does not control UEOM due to the significant participatory rights of its partner. In connection with the acquisition of the additional interest, we agreed to waive approximately $2 million of our WPZ IDR payments each quarter through 2017. See Note 1 – General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies for discussion of agreement with WPZ wherein we permanently waived IDR payment obligations from WPZ.

XML

Divestiture

12 Months Ended

Dec. 31, 2016

Discontinued Operations and Disposal Groups [Abstract]

Divestiture [Text Block]

Note 3 – Divestiture

In September 2016, we completed the sale of subsidiaries conducting Canadian operations, including subsidiaries of WPZ, (such subsidiaries, the disposal group). Consideration received to date totaled $1.020 billion, net of $31 million of cash divested and subject to customary working capital adjustments. In connection with the sale, we waived $150 million of incentive distributions otherwise payable by WPZ to us in the fourth quarter of 2016 in recognition of certain affiliate contracts wherein WPZ’s Canadian operations provided services to certain of our other businesses. The proceeds were primarily used to reduce borrowings on credit facilities.

During the second quarter of 2016, we designated these operations as held for sale. As a result, we measured the fair value of the disposal group as of June 30, 2016, resulting in an impairment charge of $747 million, reflected in Impairment of certain assets in the Consolidated Statement of Operations. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk.) During the second half of 2016 we recorded an additional loss of $66 million upon completion of the sale, primarily reflecting revisions to the sales price and estimated contingent consideration and including a $15 million benefit related to transactions to hedge our foreign currency exchange risk on the Canadian proceeds, reflected in Other (income) expense – net within Costs and expenses in the Consolidated Statement of Operations. The total loss consists of a loss of $34 million at Williams Partners and $32 million at Williams NGL & Petchem Services.

The following table presents the results of operations for the disposal group, excluding the impairment and loss noted above:

	Years Ended December 31,
	2016			2015
	(Millions)
Income (loss) before income taxes of disposal group	$	(98	)	$	17
Income (loss) before income taxes of disposal group attributable to The Williams Companies, Inc.	(95		)	15

XML

Variable Interest Entities

12 Months Ended

Dec. 31, 2016

Variable Interest Entity Disclosures [Abstract]

Variable Interest Entities [Text Block]

Note 4 – Variable Interest Entities

On January 1, 2016, we adopted ASU 2015-02 “Amendments to the Consolidation Analysis," which eliminated certain presumptions related to a general partner interest in a master limited partnership. As a result of adopting this new accounting standard, our consolidated master limited partnership is now a VIE. We are the primary beneficiary of WPZ because we have the power to direct the activities that most significantly impact WPZ’s economic performance.

The following table presents amounts included in our Consolidated Balance Sheet that are for the use or obligation of WPZ and/or its subsidiaries, and which comprise a significant portion of our consolidated assets and liabilities:

	December 31,
	2016			2015			Classification
	(Millions)
Assets (liabilities):
Cash and cash equivalents	$	145		$	73		Cash and cash equivalents
Trade accounts and other receivables – net	925			1,026			Trade accounts and other receivables
Inventories	138			127			Inventories
Other current assets	205			190			Other current assets and deferred charges
Investments	6,701			7,336			Investments
Property, plant, and equipment – net	28,021			28,593			Property, plant, and equipment – net
Intangible assets – net	9,662			10,016			Intangible assets – net of accumulated amortization
Regulatory assets, deferred charges, and other noncurrent assets	467			479			Regulatory assets, deferred charges, and other
Accounts payable	(589		)	(625		)	Accounts payable
Accrued liabilities including current asset retirement obligations	(1,122		)	(757		)	Accrued liabilities
Commercial paper	(93		)	(499		)	Commercial paper
Long-term debt due within one year	(785		)	(176		)	Long-term debt due within one year
Long-term debt	(17,685		)	(19,001		)	Long-term debt
Deferred income tax liabilities	(20		)	(119		)	Deferred income tax liabilities
Noncurrent asset retirement obligations	(798		)	(857		)	Regulatory liabilities, deferred income, and other
Regulatory liabilities, deferred income, and other noncurrent liabilities	(1,860		)	(1,066		)	Regulatory liabilities, deferred income, and other

The assets and liabilities presented in the table above also include the consolidated interests of the following individual VIEs within WPZ:

Gulfstar One

WPZ owns a 51 percentinterest in Gulfstar One LLC (Gulfstar One), a subsidiary that, due to certain risk-sharing provisions in its customer contracts, is a VIE. Gulfstar One includes a proprietary floating-production system, Gulfstar FPS, and associated pipelines which provide production handling and gathering services for the Tubular Bells oil and gas discovery in the eastern deepwater Gulf of Mexico. WPZ is the primary beneficiary because it has the power to direct the activities that most significantly impact Gulfstar One’s economic performance.

Constitution

WPZ owns a 41 percent interest in Constitution, a subsidiary that, due to shipper fixed-payment commitments under its long-term firm transportation contracts, is a VIE. WPZ is the primary beneficiary because it has the power to direct the activities that most significantly impact Constitution’s economic performance. WPZ, as construction manager for Constitution, is responsible for constructing the proposed pipeline connecting its gathering system in Susquehanna County, Pennsylvania, to the Iroquois Gas Transmission and the Tennessee Gas Pipeline systems. The total remaining cost of the project is estimated to be approximately $687 million, which is expected to be funded with capital contributions from WPZ and the other equity partners on a proportional basis.

In December 2014, we received approval from the FERC to construct and operate the Constitution pipeline. However, in April 2016, the New York State Department of Environmental Conservation (NYSDEC) denied a necessary water quality certification for the New York portion of the Constitution pipeline. We remain steadfastly committed to the project, and in May 2016, Constitution appealed the NYSDEC's denial of the certification and filed an action in federal court seeking a declaration that the State of New York's authority to exercise permitting jurisdiction over certain other environmental matters is preempted by federal law. The oral argument before the Second Circuit Court of Appeals regarding the NYSDEC’s denial of Constitution’s application for water quality certification under Section 401 of the Clean Water Act was held on November 16, 2016. We anticipate a decision from the Second Circuit Court of Appeals as early as second quarter 2017. In light of the NYSDEC's denial of the water quality certification and the actions taken to challenge the decision, the project in-service date is targeted as early as the second half of 2018, which assumes that the legal challenge process is satisfactorily and promptly concluded. An unfavorable resolution could result in the impairment of a significant portion of the capitalized project costs, which total $381 million on a consolidated basis at December 31, 2016, and are included within Property, plant, and equipment – netin the Consolidated Balance Sheet. Beginning in April 2016, we discontinued capitalization of development costs related to this project. It is also possible that we could incur certain supplier-related costs in the event of a prolonged delay or termination of the project.

Cardinal

WPZ owns a 66 percent interest in Cardinal Gas Services, L.L.C. (Cardinal), a subsidiary that provides gathering services for the Utica Shale region and is a VIE due to certain risks shared with customers. WPZ is the primary beneficiary because it has the power to direct the activities that most significantly impact Cardinal’s economic performance. Future expansion activity is expected to be funded with capital contributions from WPZ and the other equity partner on a proportional basis.

Jackalope

WPZ owns a 50 percent interest in Jackalope Gas Gathering Services, L.L.C. (Jackalope), a subsidiary that provides gathering and processing services for the Powder River basin and is a VIE due to certain risks shared with customers. WPZ is the primary beneficiary because it has the power to direct the activities that most significantly impact Jackalope’s economic performance. Future expansion activity is expected to be funded with capital contributions from WPZ and the other equity partner on a proportional basis.

XML

Related Party Transactions

12 Months Ended

Dec. 31, 2016

Related Party Transactions [Abstract]

Related Party Transactions [Text Block]

Note 5 – Related Party Transactions

Transactions with Equity-Method Investees

We have purchases from our equity-method investees included in Product costs in the Consolidated Statement of Operationsof $180 million, $187 million, and $197 million for the years ended 2016, 2015, and 2014, respectively. We have $19 million and $12 million included in Accounts payablein the Consolidated Balance Sheetwith our equity-method investees at December 31, 2016 and 2015, respectively.

WPZ has operating agreements with certain equity-method investees. These operating agreements typically provide for reimbursement or payment to WPZ for certain direct operational payroll and employee benefit costs, materials, supplies, and other charges and also for management services. We supplied a portion of these services, primarily those related to employees since WPZ does not have any employees, to certain equity-method investees. The total charges to equity-method investees for these fees are $66 million, $64 million, and $65 million for the years ended 2016, 2015, and 2014, respectively.

Board of Directors

A former member of our Board of Directors, who was elected in 2013 and resigned during 2016, is also the current chairman, president, and chief executive officer of an energy services company that is a customer of ours. We recorded $144 million, $111 million, and $115 million in Service revenues in the Consolidated Statement of Operations from this company for transportation and storage of natural gas for the years ended December 31, 2016, 2015, and 2014, respectively.

XML

Investing Activities

12 Months Ended

Dec. 31, 2016

Investments [Abstract]

Investing Activities [Text Block]

Note 6 – Investing Activities

Impairment of equity-method investments

The following table presents other-than-temporary impairment charges related to certain equity-method investments (see Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk):

	Years Ended December 31,
	2016		2015
	(Millions)
Williams Partners
Appalachia Midstream Investments	$	294	$	562
DBJV	59		503
Laurel Mountain	50		45
UEOM	—		241
Ranch Westex	24		—
Other	3		8
	$	430	$	1,359

Equity earnings (losses)

Equity earnings (losses) in 2015 includes a loss of $19 million associated with WPZ’s share of underlying property impairments at certain of the Appalachia Midstream Investments. This loss is reported within the Williams Partners segment.

Equity earnings (losses) in 2014 includes:

• Write-offs of capitalized project development costs on our discontinued investments in Bluegrass Pipeline Company LLC (Bluegrass) of $67 million and Moss Lake Fractionation LLC and Moss Lake LPG Terminal LLC (collectively referred to as Moss Lake) of $4 million;

• A $7 million equity loss recognized from our interest in ACMP that was accounted for under the equity-method of accounting for the first six months of the year, including $19 million of equity losses associated with certain compensation-related costs at ACMP that were triggered by the acquisition and $30 million noncash amortization of the difference between the cost of our investment and our underlying share of the net assets for the first six months of the year.

Other investing income (loss) – net

In 2016, we recognized a $27 million gain from the sale of an equity-method investment interest in a gathering system that was part of the Appalachia Midstream Investments within the Williams Partners segment.

Other investing income (loss) – net also includes $36 million, $27 million, and $41 million of interest income for 2016, 2015 and 2014, respectively, associated with a receivable related to the sale of certain former Venezuela assets. Due to changes in circumstances that led to late payments and increased uncertainty regarding the recovery of the receivable, we began accounting for the receivable under a cost recovery model in first quarter 2015. Subsequently, we received payments greater than the remaining carrying amount of the receivable, which resulted in the recognition of interest income.

Investments

	Ownership Interest at December 31, 2016	December 31,
		2016		2015
		(Millions)
Equity-method investments:
Appalachia Midstream Investments	(1)	$	2,062	$	2,464
UEOM	62%	1,448		1,525
DBJV	50%	988		977
Discovery	60%	572		602
OPPL	50%	430		445
Caiman II	58%	426		418
Laurel Mountain	69%	324		391
Gulfstream	50%	261		293
Other	Various	190		221
		$	6,701	$	7,336

___________

(1) Includes equity-method investments in multiple gathering systems in the Marcellus Shale with an approximate average 41 percent interest.

We have differences between the carrying value of our equity-method investments and the underlying equity in the net assets of the investees of $1.9 billion at December 31, 2016 and $2.4 billion at December 31, 2015. These differences primarily relate to our investments in Appalachian Midstream Investments, DBJV, and UEOM resulting from property, plant, and equipment, as well as customer-based intangible assets and goodwill.

Purchases of and contributions to equity-method investments

We generally fund our portion of significant expansion or development projects of these investees through additional capital contributions. These transactions increased the carrying value of our investments and included:

	Years Ended December 31,
	2016		2015		2014
	(Millions)
DBJV	$	105	$	57	$	20
Appalachia Midstream Investments	28		93		84
Caiman II	22		—		175
UEOM	—		357		57
Discovery	—		35		106
Other	22		53		40
	$	177	$	595	$	482

Dividends and distributions

The organizational documents of entities in which we have an equity-method interest generally require distribution of available cash to members on at least a quarterly basis. These transactions reduced the carrying value of our investments and included:

	Years Ended December 31,
	2016		2015		2014
	(Millions)
Appalachia Midstream Investments	$	211	$	219	$	130
Discovery	141		116		36
Gulfstream	100		88		81
UEOM	92		42		—
OPPL	69		45		27
Caiman II	40		33		13
DBJV	39		33		—
Laurel Mountain	28		31		39
ACMP	—		—		64
Other	22		26		50
	$	742	$	633	$	440

In addition, on September 24, 2015, WPZ received a special distribution of $396 million from Gulfstream reflecting its proportional share of the proceeds from new debt issued by Gulfstream. The new debt was issued to refinance Gulfstream’s debt maturities. Subsequently, WPZ contributed $248 million and $148 million to Gulfstream for its proportional share of amounts necessary to fund debt maturities of $500 million due on November 1, 2015, and $300 million due on June 1, 2016, respectively.

Summarized Financial Position and Results of Operations of All Equity-Method Investments

	December 31,
	2016			2015
	(Millions)
Assets (liabilities):
Current assets	$	508		$	773
Noncurrent assets	9,695			9,549
Current liabilities	(412		)	(633		)
Noncurrent liabilities	(1,484		)	(1,450		)

	Years Ended December 31,
	2016		2015		2014
	(Millions)
Gross revenue	$	1,883	$	1,707	$	1,623
Operating income	799		690		534
Net income	726		611		460

XML

Other Income and Expenses

12 Months Ended

Dec. 31, 2016

Other Income and Expenses [Abstract]

Other Income and Expense [Text Block]

Note 7 – Other Income and Expenses

The following table presents certain gains or losses reflected in Other (income) expense – net within Costs and expenses in the Consolidated Statement of Operations:

	Years Ended December 31,
	2016			2015			2014
	(Millions)
Williams Partners
Loss on sale of Canadian operations (Note 3)	$	34		$	—		$	—
Amortization of regulatory assets associated with asset retirement obligations	33			33			33
Accrual of regulatory liability related to overcollection of certain employee expenses	25			20			14
Project development costs related to Constitution (Note 4)	28			—			—
Net foreign currency exchange (gains) losses (1)	10			(10		)	(3		)
Contingency gain settlement (2)	—			—			(154		)
Net gain related to partial acreage dedication release	—			—			(12		)
Gain on asset retirement	(11		)	—			—
Loss related to sale of certain assets	—			—			10
Williams NGL & Petchem Services
Loss on sale of Canadian operations (Note 3)	32			—			—
Gain on sale of unused pipe	(10		)	—			—

________________

(1) Primarily relates to gains and losses incurred on foreign currency transactions and the remeasurement of U.S. dollar-denominated current assets and liabilities within our former Canadian operations (see Note 3 – Divestiture).

(2) In November 2014, we settled a claim arising from the resolution of a contingent gain related to claims associated with the purchase of a business in a prior period. Pursuant to the settlement, we received $154 million in cash, all of which was recognized as a gain in the fourth quarter of 2014.

ACMP Acquisition, Merger, and Transition

Certain ACMP acquisition, merger, and transition costs included in the Consolidated Statement of Operations are as follows:

• Selling, general, and administrative expensesincludes $26 million in 2015 and $27 million in 2014 (including $16 million of acquisition costs) primarily related to professional advisory fees within the Williams Partners segment.

• Selling, general, and administrative expensesincludes $9 million in 2015 and $15 million in 2014 of related employee transition costs within the Williams Partners segment and $32 million in 2015 and $10 million in 2014 of general corporate expenses associated with integration and realignment of resources within the Other segment.

• Operating and maintenance expensesincludes $12 million in 2015 and $15 million in 2014 primarily related to employee transition costs within the Williams Partners segment.

• Interest incurredincludes transaction-related financing costs of $2 million in 2015 from the merger and $9 million in 2014 from the acquisition.

Additional Items

Certain additional items included in the Consolidated Statement of Operations are as follows:

• Service revenuesincludes $173 million associated with the amortization of deferred income related to the restructuring of certain gas gathering contracts in the Barnett Shale and Mid-Continent regions within the Williams Partners segment. Service revenues also includes $58 million, $239 million, and $167 million recognized in the fourth quarter of 2016, 2015, and 2014, respectively, from minimum volume commitment feesin the Barnett Shale and Mid-Continent regions within the Williams Partners segment.

• Selling, general, and administrative expensesand Operating and maintenance expenses include $42 million in 2016 of severance and other related costs.

• Other income (expense) – net below Operating income (loss) includes $89 million, $95 million, and $44 million for equity AFUDC for 2016, 2015, and 2014, respectively, primarily within the Williams Partners segment.

• Other income (expense) – net below Operating income (loss) includes a $14 million gain in 2015 resulting from the early retirement of certain debt within the Williams Partners segment.

XML

Provision (Benefit) for Income Taxes

12 Months Ended

Dec. 31, 2016

Income Tax Disclosure [Abstract]

Provision (Benefit) for Income Taxes [Text Block]

Note 8 – Provision (Benefit) for Income Taxes

The Provision (benefit) for income taxes includes:

	Years Ended December 31,
	2016			2015			2014
	(Millions)
Current:
Federal	$	—		$	—		$	(9	)
State	2			(7		)	2
Foreign	(1		)	(55		)	10
	1			(62		)	3
Deferred:
Federal	(6		)	(317		)	1,108
State	61			(25		)	119
Foreign	(81		)	5			19
	(26		)	(337		)	1,246
Provision (benefit) for income taxes	$	(25	)	$	(399	)	$	1,249

Reconciliations from the Provision (benefit) at statutory rate to recorded Provision (benefit) for income taxes are as follows:

	Years Ended December 31,
	2016			2015			2014
	(Millions)
Provision (benefit) at statutory rate	$	(131	)	$	(600	)	$	1,255
Increases (decreases) in taxes resulting from:
Impact of nontaxable noncontrolling interests	(22		)	263			(75		)
State income taxes (net of federal benefit)	3			(21		)	82
State deferred income tax rate change	43			—			—
Foreign operations – net (Including tax effect of Canadian Sale)	78			8			(11		)
Taxes on undistributed earnings of foreign subsidiaries – net	—			—			(37		)
Translation adjustment of certain unrecognized tax benefits	(1		)	(71		)	—
Other – net	5			22			35
Provision (benefit) for income taxes	$	(25	)	$	(399	)	$	1,249

Income (loss) from continuing operations before income taxes includes $885 million of foreign loss in 2016, and $20 million and $102 million of foreign income in 2015 and 2014, respectively.

Foreign operations – net (Including tax effect of Canadian Sale) increased in 2016 due to a valuation allowance associated with impairments and losses on the sale of our Canadian operations (see Note 3 – Divestiture) and the reversal of anticipatory foreign tax credits, partially offset by the tax effect of the impairments associated with our Canadian disposition.

The Translation adjustment of certain unrecognized tax benefits in 2016 and 2015 reflects the impact of changes in foreign currency exchange rates on the remeasurement of a foreign currency denominated unrecognized tax benefit, including associated penalties and interest.

The 2015 federal and state income tax provisions include the tax effect of a $2.7 billion impairment loss associated with certain goodwill, equity-method investments, and other assets. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk.) The 2014 federal and state income tax provisions include the tax effect of a $2.5 billion gain associated with remeasuring our equity-method investment to fair value as a result of the ACMP Acquisition. (See Note 2 – Acquisitions.)

Taxes on undistributed earnings of foreign subsidiaries - net decreased in 2014 due to revisions of our estimate of the undistributed earnings, partially offset by an increase of tax expense, which decreased our share of the foreign tax credit due to the Canada Dropdown.

During the course of audits of our business by domestic and foreign tax authorities, we frequently face challenges regarding the amount of taxes due. These challenges include questions regarding the timing and amount of deductions and the allocation of income among various tax jurisdictions. In evaluating the liability associated with our various filing positions, we apply the two-step process of recognition and measurement. In association with this liability, we record an estimate of related interest and tax exposure as a component of our tax provision. The impact of this accrual is included within Other – net in our reconciliation of the Provision (benefit) at statutory rate to recorded Provision (benefit) for income taxes.

Significant components of Deferred income tax liabilities and Deferred income tax assets are as follows:

	December 31,
	2016		2015
	(Millions)
Deferred income tax liabilities:
Property, plant, and equipment	$	—	$	4
Investments	5,300		5,272
Other	29		15
Total deferred income tax liabilities	5,329		5,291
Deferred income tax assets:
Accrued liabilities	145		150
Minimum tax credits	139		139
Foreign tax credit	140		193
Federal loss carryovers	651		485
State losses and credits	313		296
Other	37		42
Total deferred income tax assets	1,425		1,305
Less valuation allowance	334		190
Net deferred income tax assets	1,091		1,115
Overall net deferred income tax liabilities	$	4,238	$	4,176

The valuation allowance at December 31, 2016 and 2015 serves to reduce the available deferred income tax assets to an amount that will, more likely than not, be realized. We consider all available positive and negative evidence, including projected future taxable income and management’s estimate of future reversals of existing taxable temporary differences, and have determined that a portion of our deferred income tax assets related to State losses and credits and Federal loss carryovers may not be realized. The change in Valuation allowance is partially due to this evaluation. The amounts presented in the table above are, with respect to state items, before any federal benefit. The change from prior year for the State losses and creditsis primarily due to increases in losses and credits generated in the current and prior years less losses and/or credits utilized in the current year. We have loss and credit carryovers in multiple state taxing jurisdictions. These attributes generally expire between 2017 and 2036 with some carryovers having indefinite carryforward periods. Federal loss carryovers includes the tax effect of a capital loss carryover of $364 million, incurred with the sale of our Canadian operations, which, if unused, will expire in 2021. The Valuation allowance change from prior year is primarily due to a valuation allowance on the deferred tax asset associated with this capital loss carryover. We reasonably anticipate that this valuation allowance could be released in the near future due to tax impacts of the potential monetization of certain assets as previously announced by management. The federal tax Minimum tax credits of $139 million currently has no expiration date. Foreign tax credit of $140 million is expected to be utilized prior to expiration in 2026.

Federal net operating loss carryovers and charitable contribution carryovers of $1.6 billion at the end of 2016 are expected to be utilized by us prior to expiration between 2018 and 2036. Employee share-based compensation attributable to the exercise of stock options and vesting of restricted stock is deductible by us for tax purposes. To the extent these tax deductions exceed the previously accrued deferred income tax benefit for these items, the additional tax benefit is not recognized until the deduction reduces current income taxes payable. Since the additional tax benefit does not reduce our current income taxes payable for 2014 through 2016, these tax benefits are not included in our Federal loss carryovers deferred income tax assets. The additional tax benefits deductible for tax purposes but not included in our Federal loss carryovers deferred income tax assets were $38 million through 2016.

Cash payments for income taxes (net of refunds) were $5 million and $29 million in 2016 and 2014, respectively. Cash refunds for income taxes (net of payments and discontinued operations) were $136 million in 2015.

As of December 31, 2016, we had approximately $50 million of unrecognized tax benefits. If recognized, income tax expense would be reduced by $49 million and $51 million for 2016 and 2015, respectively, including the effect of these changes on other tax attributes, with state income tax amounts included net of federal tax effect. A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows:

	2016			2015
	(Millions)
Balance at beginning of period	$	55		$	89
Additions for tax positions of prior years	—			2
Reductions for tax positions of prior years	(4		)	—
Changes due to currency translation	(1		)	(36		)
Balance at end of period	$	50		$	55

We recognize related interest and penalties as a component of Provision (benefit) for income taxes. Total interest and penalties recognized as part of income tax provision were expenses of $300 thousand and $8 million for 2016 and 2014, respectively, and a benefit of $22 million for 2015, including a $35 million benefit due to currency fluctuation. Approximately $3 million and $2 million of interest and penalties primarily relating to uncertain tax positions have been accrued as of December 31, 2016 and 2015, respectively. Changes due to currency translation in 2015 reflects the unrecognized tax benefit portion of the previously described impact of changes in foreign currency exchange rates on the remeasurement of a foreign currency denominated balance.

During the next 12 months, we do not expect ultimate resolution of any unrecognized tax benefit associated with domestic or international matters to have a material impact on our unrecognized tax benefit position.

Consolidated U.S Federal income tax returns are open to Internal Revenue Service (IRS) examination for years after 2010. As of December 31, 2016, examinations of tax returns for 2011 through 2013 are currently in process. We do not expect material changes in our financial position resulting from these examinations. The statute of limitations for most states expires one year after expiration of the IRS statute. Generally, tax returns for our Canadian entities are open to audit for tax years after 2011. Tax years 2013 and 2014 are currently under examination. We have indemnified the purchaser of our Canadian operations for any adjustments to Canadian tax returns for periods prior to the sale of our Canadian operations in September 2016.

In November 2015, the FASB issued ASU 2015-17 “Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes” (ASU 2015-17). The standard requires that deferred income tax liabilities and assets, along with any related valuation allowance, be presented as noncurrent in a classified statement of financial position. The standard is effective for interim and annual periods beginning after December 15, 2016 and early adoption is permitted. We have elected to early adopt ASU 2015-17 prospectively as of December 31, 2016. TheConsolidated Balance Sheetas of December 31, 2015 was not retrospectively adjusted.

On September 13, 2013, the IRS issued final regulations providing guidance on the treatment of amounts paid to acquire, produce, or improve tangible property. On August 18, 2014, the IRS issued final regulations providing guidance on the dispositions of such property. The implementation date for these regulations was January 1, 2014. The IRS is expected to issue additional procedural guidance regarding how the requirements may be implemented for the gas transmission and distribution industry. Pending the issuance of this additional procedural guidance from the IRS, we cannot at this time estimate the impact of implementing the regulations for our gas transmission business, although we anticipate that it will result in an immaterial balance sheet only impact.

XML

Earnings (Loss) Per Common Share from Continuing Operations

12 Months Ended

Dec. 31, 2016

Earnings Per Share [Abstract]

Earnings (Loss) Per Common Share from Continuing Operations [Text Block]

Note 9 – Earnings (Loss) Per Common Share from Continuing Operations

	Years Ended December 31,
	2016			2015			2014
	(Dollars in millions, except per-share amounts; shares in thousands)
Income (loss) from continuing operations attributable to The Williams Companies, Inc. available to common stockholders for basic and diluted earnings (loss) per common share	$	(424	)	$	(571	)	$	2,110
Basic weighted-average shares	750,673			749,271			719,325
Effect of dilutive securities:
Nonvested restricted stock units	—			—			2,234
Stock options	—			—			2,064
Convertible debentures	—			—			18
Diluted weighted-average shares (1)	750,673			749,271			723,641
Earnings (loss) per common share from continuing operations:
Basic	$	(.57	)	$	(.76	)	$	2.93
Diluted	$	(.57	)	$	(.76	)	$	2.91

(1) For the years ended December 31, 2016 and December 31, 2015, 0.6 million and 1.7 million weighted-average nonvested restricted stock units, and 0.5 million and 1.5 million weighted-average stock options have been excluded from the computation of diluted earnings (loss) per common share as their inclusion would be antidilutive due to our loss from continuing operations attributable to The Williams Companies, Inc.

XML

Employee Benefit Plans

12 Months Ended

Dec. 31, 2016

Compensation and Retirement Disclosure [Abstract]

Employee Benefit Plans [Text Block]

Note 10 – Employee Benefit Plans

We have noncontributory defined benefit pension plans in which all eligible employees participate. Currently, eligible employees earn benefits primarily based on a cash balance formula. Various other formulas, as defined in the plan documents, are utilized to calculate the retirement benefits for plan participants not covered by the cash balance formula. At the time of retirement, participants may elect, to the extent they are eligible for the various options, to receive annuity payments, a lump sum payment, or a combination of a lump sum and annuity payments. In addition to our pension plans, we currently provide subsidized retiree medical and life insurance benefits (other postretirement benefits) to certain eligible participants. Generally, employees hired after December 31, 1991, are not eligible for the subsidized retiree medical benefits, except for participants that were employees or retirees of Transco Energy Company on December 31, 1995, and other miscellaneous defined participant groups. Subsidized retiree medical benefits for eligible participants age 65 and older are paid through contributions to health reimbursement accounts. Subsidized retiree medical benefits for eligible participants under age 65 are provided through a self-insured medical plan sponsored by us. The self-insured retiree medical plan provides for retiree contributions and contains other cost-sharing features such as deductibles, co-payments, and co-insurance. The accounting for these plans anticipates estimated future increases to our contribution levels to the health reimbursement accounts for participants age 65 and older, as well as future cost-sharing that is consistent with our expressed intent to increase the retiree contribution level generally in line with health care cost increases for participants under age 65.

Funded Status

The following table presents the changes in benefit obligations and plan assets for pension benefits and other postretirement benefits for the years indicated:

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
	(Millions)
Change in benefit obligation:
Benefit obligation at beginning of year	$	1,464		$	1,544		$	202		$	233
Service cost	54			59			1			2
Interest cost	62			58			8			9
Plan participants’ contributions	—			—			2			2
Benefits paid	(130		)	(101		)	(15		)	(13		)
Actuarial loss (gain)	20			(91		)	(1		)	(31		)
Settlements	(4		)	(5		)	—			—
Net increase (decrease) in benefit obligation	2			(80		)	(5		)	(31		)
Benefit obligation at end of year	1,466			1,464			197			202
Change in plan assets:
Fair value of plan assets at beginning of year	1,241			1,293			201			208
Actual return on plan assets	82			(11		)	13			(1		)
Employer contributions	65			65			7			5
Plan participants’ contributions	—			—			2			2
Benefits paid	(130		)	(101		)	(15		)	(13		)
Settlements	(4		)	(5		)	—			—
Net increase (decrease) in fair value of plan assets	13			(52		)	7			(7		)
Fair value of plan assets at end of year	1,254			1,241			208			201
Funded status — overfunded (underfunded)	$	(212	)	$	(223	)	$	11		$	(1	)
Accumulated benefit obligation	$	1,440		$	1,432

The overfunded (underfunded) status of our pension plans and other postretirement benefit plans presented in the previous table are recognized in the Consolidated Balance Sheet within the following accounts:

	December 31,
	2016			2015
	(Millions)
Underfunded pension plans:
Current liabilities	$	(2	)	$	(2	)
Noncurrent liabilities	(210		)	(221		)
Overfunded (underfunded) other postretirement benefit plans:
Current liabilities	(7		)	(7		)
Noncurrent assets (liabilities)	18			6

The plan assets within our other postretirement benefit plans are intended to be used for the payment of benefits for certain groups of participants. The Current liabilities for the other postretirement benefit plans represent the current portion of benefits expected to be payable in the subsequent year for the groups of participants whose benefits are not expected to be paid from plan assets.

The pension plans’ benefit obligation Actuarial loss (gain) of $20 million in 2016 is primarily due to the impact of a decrease in the discount rates utilized to calculate the benefit obligation. The pension plans’ benefit obligation Actuarial loss (gain)of$(91) million in 2015 is primarily due to the impact of a decrease in the assumed future interest crediting rate for the cash balance pension formula and an increase in the discount rates utilized to calculate the benefit obligation.

The 2015 benefit obligation Actuarial loss (gain) of $(31) million for our other postretirement benefit plans is primarily due to an increase in the discount rate used to calculate the benefit obligation, tax law changes, and other assumption changes.

At December 31, 2016 and 2015, all of our pension plans had a projected benefit obligation and accumulated benefit obligation in excess of plan assets.

Pre-tax amounts not yet recognized in Net periodic benefit cost at December 31 are as follows:

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
	(Millions)
Amounts included in Accumulated other comprehensive income (loss):
Prior service credit	$	—		$	—		$	5		$	11
Net actuarial loss	(535		)	(544		)	(18		)	(18		)
Amounts included in regulatory liabilities associated with Transco and Northwest Pipeline:
Prior service credit	N/A			N/A			$	10		$	19
Net actuarial gain	N/A			N/A			8			6

In addition to the regulatory liabilities included in the previous table, differences in the amount of actuarially determined Net periodic benefit cost for our other postretirement benefit plans and the other postretirement benefit costs recovered in rates for Transco and Northwest Pipeline are deferred as a regulatory asset or liability. We have regulatory liabilities of $94 million at December 31, 2016 and $78 million at December 31, 2015, related to these deferrals. Additionally, Transco recognizes a regulatory liability for rate collections in excess of its amount funded to the tax-qualified pension plans. At December 31, 2016 and 2015, these regulatory liabilities were $21 million and $8 million, respectively. These pension and other postretirement plans amounts will be reflected in future rates based on the rate structures of these gas pipelines.

Net Periodic Benefit Cost

Net periodic benefit cost for the years ended December 31 consist of the following:

	Pension Benefits									Other Postretirement  Benefits
	2016			2015			2014			2016			2015			2014
	(Millions)
Components of net periodic benefit cost:
Service cost	$	54		$	59		$	40		$	1		$	2		$	2
Interest cost	62			58			62			8			9			10
Expected return on plan assets	(85		)	(75		)	(76		)	(12		)	(12		)	(12		)
Amortization of prior service credit	—			—			—			(15		)	(17		)	(20		)
Amortization of net actuarial loss	30			42			39			—			2			—
Net actuarial (gain) loss from settlements and curtailments	2			2			1			—			—			(1		)
Reclassification to regulatory liability	—			—			—			4			3			4
Net periodic benefit cost	$	63		$	86		$	66		$	(14	)	$	(13	)	$	(17	)

Items Recognized in Other Comprehensive Income (Loss) and Regulatory Assets/Liabilities

Other changes in plan assets and benefit obligations recognized in Other comprehensive income (loss) before taxes for the years ended December 31 consist of the following:

	Pension Benefits								Other Postretirement  Benefits
	2016			2015		2014			2016			2015			2014
	(Millions)
Other changes in plan assets and benefit obligations recognized in Other comprehensive income (loss):
Net actuarial gain (loss)	$	(23	)	$	5	$	(142	)	$	—		$	8		$	(18	)
Prior service (cost) credit	—			—		—			—			—			(1		)
Amortization of prior service credit	—			—		—			(6		)	(6		)	(8		)
Amortization of net actuarial loss	30			42		39			—			2			—
Loss from settlements and curtailments	2			2		1			—			—			1
Other changes in plan assets and benefit obligations recognized in Other comprehensive income (loss)	$	9		$	49	$	(102	)	$	(6	)	$	4		$	(26	)

Other changes in plan assets and benefit obligations for our other postretirement benefit plans associated with Transco and Northwest Pipeline are recognized in regulatory assets/liabilities.Amounts recognized in regulatory assets/ liabilities for the years ended December 31 consist of the following:

	2016			2015			2014
	(Millions)
Other changes in plan assets and benefit obligations recognized in regulatory (assets) liabilities:
Net actuarial gain (loss)	$	2		$	10		$	(2	)
Amortization of prior service credit	(9		)	(11		)	(12		)

Pre-tax amounts expected to be amortized in Net periodic benefit cost in 2017 are as follows:

	Pension Benefits		Other Postretirement Benefits
	(Millions)
Amounts included in Accumulated other comprehensive income (loss):
Prior service credit	$	—	$	(5	)
Net actuarial loss	28		—
Amounts included in regulatory liabilities associated with Transco and Northwest Pipeline:
Prior service credit	N/A		$	(8	)
Net actuarial loss	N/A		—

Key Assumptions

The weighted-average assumptions utilized to determine benefit obligations as of December 31 are as follows:

	Pension Benefits				Other Postretirement Benefits
	2016		2015		2016		2015
Discount rate	4.17	%	4.38	%	4.27	%	4.50	%
Rate of compensation increase	4.87		4.88		N/A		N/A

The weighted-average assumptions utilized to determine Net periodic benefit cost for the years ended December 31 are as follows:

	Pension Benefits						Other Postretirement  Benefits
	2016		2015		2014		2016		2015		2014
Discount rate	4.37	%	3.96	%	4.68	%	4.50	%	4.12	%	4.80	%
Expected long-term rate of return on plan assets	6.85		6.38		6.85		6.11		5.70		6.11
Rate of compensation increase	4.88		4.62		4.56		N/A		N/A		N/A

The mortality assumptions used to determine the benefit obligations for our pension and other postretirement benefit plans reflect generational projection mortality tables.

The assumed health care cost trend rate for 2017 is 7.5 percent. This rate decreases to 4.5 percent by 2025. A one-percentage-point change in assumed health care cost trend rates would have the following effects:

	Point increase		Point decrease
	(Millions)
Effect on total of service and interest cost components	$	—	$	—
Effect on other postretirement benefit obligation	6		(5		)

Plan Assets

Plan assets for our pension and other postretirement benefit plans consist primarily of equity and fixed income securities including mutual funds and commingled investment funds invested in equity and fixed income securities. The plans’ investment policy provides for a strategy in accordance with the Employee Retirement Income Security Act (ERISA), which governs the investment of the assets in a diversified portfolio. The plans follow a policy of diversifying the investments across various asset classes and investment managers. Additionally, the investment returns on approximately 38 percent of the other postretirement benefit plan assets are subject to income tax; therefore, certain investments are managed in a tax efficient manner.

The investment policy for the pension plans includes a general target asset allocation at December 31, 2016 of 60 percent equity securities and 40 percent fixed income securities. The target allocation includes the investments in equity and fixed income mutual funds and commingled investment funds. The investment policy allows for a broad range of asset allocations that permit the plans to de-risk in response to changes in the plans’ funded status.

Equity securities may include U.S. equities and non-U.S. equities. Investment in Williams’ securities or an entity in which Williams has a majority ownership is prohibited except where these securities may be owned in a commingled investment fund in which the plans’ trusts invest. No more than 5 percent of the total stock portfolio valued at market may be invested in the common stock of any one corporation.

Fixed income securities may consist of U.S. as well as international instruments, including emerging markets. The fixed income strategies may invest in government, corporate, asset-backed securities, and mortgage-backed obligations. The weighted-average credit rating of the fixed income strategies must be at least “investment grade” including ratings by Moody’s and/or Standard & Poor’s. No more than 5 percent of the total fixed income portfolio may be invested in the fixed income securities of any one issuer with the exception of bond index funds and U.S. government guaranteed and agency securities.

The following securities and transactions are not authorized: unregistered securities, commodities or commodity contracts, short sales or margin transactions, or other leveraging strategies. Investment strategies using direct investments in derivative securities require approval and, historically, have not been used; however, these instruments may be used in mutual funds and commingled investment funds held by the plans’ trusts. Additionally, real estate equity, natural resource property, venture capital, leveraged buyouts, and other high-return, high-risk investments are generally restricted.

There are no significant concentrations of risk within the plans’ investment securities because of the diversity of the types of investments, diversity of the various industries, and the diversity of the fund managers and investment strategies. Generally, the investments held in the plans are publicly traded, therefore, minimizing liquidity risk in the portfolio.

The fair values of our pension plan assets at December 31, 2016 and 2015 by asset class are as follows:

	2016
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(Millions)
Pension assets:
Cash management fund	$	14	$	—	$	—	$	14
Equity securities:
U.S. large cap	87		—		—		87
U.S. small cap	77		—		—		77
Fixed income securities (1):
U.S. Treasury securities	68		—		—		68
Government and municipal bonds	—		10		—		10
Mortgage and asset-backed securities	—		80		—		80
Corporate bonds	—		148		—		148
Insurance company investment contracts and other	—		5		—		5
	$	246	$	243	$	—	489
Commingled investment funds measured at net asset value practical expedient (3):
Equities — U.S. large cap							369
Equities — International small cap							27
Equities — International emerging markets							50
Equities — International developed markets							149
Fixed income — U.S. long duration							88
Fixed income — Corporate bonds							82
Total assets at fair value at December 31, 2016							$	1,254

	2015
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(Millions)
Pension assets:
Cash management fund	$	8	$	—	$	—	$	8
Equity securities:
U.S. large cap	83		—		—		83
U.S. small cap	64		—		—		64
Fixed income securities (1):
U.S. Treasury securities	65		—		—		65
Government and municipal bonds	—		8		—		8
Mortgage and asset-backed securities	—		87		—		87
Corporate bonds	—		145		—		145
Insurance company investment contracts and other	—		5		—		5
	$	220	$	245	$	—	465
Commingled investment funds measured at net asset value practical expedient (3):
Equities — U.S. large cap							367
Equities — International small cap							27
Equities — International emerging markets							50
Equities — International developed markets							153
Fixed income — U.S. long duration							95
Fixed income — Corporate bonds							84
Total assets at fair value at December 31, 2015							$	1,241

The fair values of our other postretirement benefits plan assets at December 31, 2016 and 2015 by asset class are as follows:

	2016
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(Millions)
Other postretirement benefit assets:
Cash management funds	$	11	$	—	$	—	$	11
Equity securities:
U.S. large cap	24		—		—		24
U.S. small cap	15		—		—		15
International developed markets large cap growth	—		5		—		5
Fixed income securities (2):
U.S. Treasury securities	7		—		—		7
Government and municipal bonds	—		1		—		1
Mortgage and asset-backed securities	—		8		—		8
Corporate bonds	—		15		—		15
Mutual fund — Municipal bonds	42		—		—		42
	$	99	$	29	$	—	128
Commingled investment funds measured at net asset value practical expedient (3):
Equities — U.S. large cap							38
Equities — International small cap							3
Equities — International emerging markets							5
Equities — International developed markets							16
Fixed income — U.S. long duration							9
Fixed income — Corporate bonds							9
Total assets at fair value at December 31, 2016							$	208

	2015
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(Millions)
Other postretirement benefit assets:
Cash management funds	$	11	$	—	$	—	$	11
Equity securities:
U.S. large cap	37		—		—		37
U.S. small cap	20		—		—		20
International developed markets large cap growth	1		9		—		10
Emerging markets growth	—		1		—		1
Fixed income securities (2):
U.S. Treasury securities	7		—		—		7
Government and municipal bonds	—		12		—		12
Mortgage and asset-backed securities	—		9		—		9
Corporate bonds	—		15		—		15
	$	76	$	46	$	—	122
Commingled investment funds measured at net asset value practical expedient (3):
Equities — U.S. large cap							37
Equities — International small cap							3
Equities — International emerging markets							5
Equities — International developed markets							16
Fixed income — U.S. long duration							10
Fixed income — Corporate bonds							8
Total assets at fair value at December 31, 2015							$	201

____________

(1) The weighted-average credit quality rating of the pension assets fixed income security portfolio is investment grade with a weighted-average duration of approximately 8 years for 2016 and 2015.

(2) The weighted-average credit quality rating of the other postretirement benefit assets fixed income security portfolio is investment grade with a weighted-average duration of approximately 8 years for 2016 and 7 years for 2015.

(3) The stated intents of the funds vary based on each commingled fund’s investment objective. These objectives generally include strategies to replicate or outperform various market indices. Certain standard withdrawal restrictions generally apply, which may include redemption notification period restrictions ranging from 10 to 30 days. Additionally, the fund managers retain the right to restrict withdrawals from and/or purchases into the funds so as not to disadvantage other investors in the funds. Generally, the funds also reserve the right to make all or a portion of the redemption in-kind rather than in cash or a combination of cash and in-kind.

The fair value measurement level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement of an asset.

Shares of the cash management funds and mutual funds are valued at fair value based on published market prices as of the close of business on the last business day of the year, which represents the net asset values of the shares held.

The fair values of equity securities traded on U.S. exchanges are derived from quoted market prices as of the close of business on the last business day of the year. The fair values of equity securities traded on foreign exchanges are also derived from quoted market prices as of the close of business on an active foreign exchange on the last business day of the year. However, the valuation requires translation of the foreign currency to U.S. dollars and this translation is considered an observable input to the valuation.

The fair values of all commingled investment funds are determined based on the net asset values per unit of each of the funds. The net asset values per unit represent the aggregate values of the funds’ assets at fair value less liabilities, divided by the number of units outstanding.

The fair values of fixed income securities, except U.S. Treasury securities, are determined using pricing models. These pricing models incorporate observable inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads for similar securities to determine fair value. The U.S. Treasury securities are valued at fair value based on closing prices on the last business day of the year reported in the active market in which the security is traded.

The investment contracts with insurance companies are valued at fair value by discounting the cash flow of a bond using a yield to maturity based on an investment grade index or comparable index with a similar maturity value, maturity period, and nominal coupon rate.

There have been no significant changes in the preceding valuation methodologies used at December 31, 2016 and 2015. Additionally, there were no transfers or reclassifications of investments between Level 1 and Level 2 from December 2015 to December 2016. If transfers between levels had occurred, the transfers would have been recognized as of the end of the period.

Plan Benefit Payments and Employer Contributions

Following are the expected benefits to be paid by the plans. These estimates are based on the same assumptions previously discussed and reflect future service as appropriate. The actuarial assumptions are based on long-term expectations and include, but are not limited to, assumptions as to average expected retirement age and form of benefit payment. Actual benefit payments could differ significantly from expected benefit payments if near-term participant behaviors differ significantly from the actuarial assumptions.

	Pension Benefits		Other Postretirement Benefits
	(Millions)
2017	$	99	$	13
2018	103		13
2019	103		13
2020	106		13
2021	111		13
2022-2026	562		62

In 2017, we expect to contribute approximately $60 million to our tax-qualified pension plans and approximately $2 million to our nonqualified pension plans, for a total of approximately $62 million, and approximately $7 million to our other postretirement benefit plans.

Defined Contribution Plans

We also maintain defined contribution plans for the benefit of substantially all of our employees. Generally, plan participants may contribute a portion of their compensation on a pre-tax and after-tax basis in accordance with the plans’ guidelines. We match employees’ contributions up to certain limits. Our matching contributions charged to expense were $36 million in 2016, $39 million in 2015, and $39 million in 2014.

XML

Property, Plant, and Equipment

12 Months Ended

Dec. 31, 2016

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment [Text Block]

Note 11 – Property, Plant, and Equipment

The following table presents nonregulated and regulated Property, plant, and equipment – net as presented on the Consolidated Balance Sheet for the years ended:

	Estimated Useful Life  (1) (Years)	Depreciation Rates (1) (%)	December 31,
			2016			2015
			(Millions)
Nonregulated:
Natural gas gathering and processing facilities	5 - 40		$	20,413		$	20,789
Construction in progress	Not applicable		412			1,366
Other	2 - 45		2,202			2,170
Regulated:
Natural gas transmission facilities		1.20 - 6.97	12,692			12,189
Construction in progress	Not applicable	Not applicable	1,603			941
Other	5 - 45	1.35 - 33.33	1,590			1,584
Total property, plant, and equipment, at cost			38,912			39,039
Accumulated depreciation and amortization			(10,484		)	(9,460		)
Property, plant, and equipment — net			$	28,428		$	29,579

__________

(1) Estimated useful life and depreciation rates are presented as of December 31, 2016. Depreciation rates and estimated useful lives for regulated assets are prescribed by the FERC.

Depreciation and amortization expense forProperty, plant, and equipment – net was $1,407 million, $1,382 million, and $967 million in 2016, 2015, and 2014, respectively.

Regulated Property, plant, and equipment – net includes approximately $665 million and $706 million at December 31, 2016 and 2015, respectively, related to amounts in excess of the original cost of the regulated facilities within our gas pipeline businesses as a result of our prior acquisitions. This amount is being amortized over 40 years using the straight-line amortization method. Current FERC policy does not permit recovery through rates for amounts in excess of original cost of construction.

Asset Retirement Obligations

Our accrued obligations relate to underground storage caverns, offshore platforms and pipelines, fractionation and compression facilities, gas gathering well connections and pipelines, and gas transmission pipelines and facilities. At the end of the useful life of each respective asset, we are legally obligated to plug storage caverns and remove any related surface equipment, to restore land and remove surface equipment at gas processing, fractionation, and compression facilities, to dismantle offshore platforms and appropriately abandon offshore pipelines, to cap certain gathering pipelines at the wellhead connection and remove any related surface equipment, and to remove certain components of gas transmission facilities from the ground.

The following table presents the significant changes to our ARO, of which $801 million and $858 million are included in Regulatory liabilities, deferred income, and other with the remaining current portion in Accrued liabilities at December 31, 2016 and 2015, respectively.

	December 31,
	2016			2015
	(Millions)
Beginning balance	$	915		$	831
Liabilities incurred	24			42
Liabilities settled	(8		)	(3		)
Accretion expense	69			60
Revisions (1)	(138		)	(15		)
Ending balance	$	862		$	915

___________

(1) Several factors are considered in the annual review process, including inflation rates, current estimates for removal cost, market risk premiums, discount rates, and the estimated remaining useful life of the assets. The 2016 revisions reflect changes in removal cost estimates, increases in the estimated remaining useful life of certain assets, and decreases in the inflation rate and discount rates used in the annual review process. The 2015 revisions reflect changes in removal cost estimates and the estimated remaining useful life of assets, a decrease in the inflation rate, and increases in the discount rates used in the annual review process.

The funds Transco collects through a portion of its rates to fund its ARO are deposited into an external trust account dedicated to funding its ARO (ARO Trust). (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk.) Under its current rate settlement, Transco’s annual funding obligation is approximately $36 million, with installments to be deposited monthly.

XML

Goodwill and Other Intangible Assets

12 Months Ended

Dec. 31, 2016

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill and Other Intangible Assets [Text Block]

Note 12 – Goodwill and Other Intangible Assets

Goodwill

Changes in the carrying amount of goodwill, included in Intangible assets – net of accumulated amortization, by reportable segment for the periods indicated are as follows:

	Williams Partners
	(Millions)
December 31, 2014	$	1,120
Purchase accounting adjustment	25
Impairment	(1,098		)
December 31, 2015	$	47
December 31, 2016	$	47

Our goodwill is not subject to amortization, but is evaluated at least annually for impairment or more frequently if impairment indicators are present. We did not identify or recognize any impairments to goodwill in connection with our annual evaluation of goodwill for impairment (performed as of October 1) during the years ended December 31, 2016 and 2014. During 2015, we performed an interim assessment and an annual assessment as of September 30, 2015 and October 1, 2015, respectively, of certain goodwill within the Williams Partners segment. The estimated fair value of the reporting units evaluated exceeded their carrying amounts, and thus no impairment was identified. We performed an additional goodwill impairment evaluation as of December 31, 2015, of the goodwill recorded within the Williams Partners segment. As a result of this evaluation, we recorded goodwill impairment charges totaling $1.098 billion. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk.)

Other Intangible Assets

The gross carrying amount and accumulated amortization of other intangible assets, included in Intangible assets – net of accumulated amortization, at December 31 are as follows:

	2016					2015
	Gross Carrying Amount		Accumulated Amortization			Gross Carrying Amount		Accumulated Amortization
	(Millions)
Contractual customer relationships	$	10,635	$	(1,019	)	$	10,633	$	(663	)

Other intangible assets primarily relate to gas gathering, processing, and fractionation contractual customer relationships recognized in the ACMP and Eagle Ford acquisitions (see Note 2 – Acquisitions) as well as previous acquisitions. Other intangible assets are being amortized on a straight-line basis over an initial period of 30 years which represents a portion of the term over which the contractual customer relationships are expected to contribute to our cash flows.

We expense costs incurred to renew or extend the terms of our gas gathering, processing, and fractionation contracts with customers. Based on the estimated future revenues during the contract periods (as estimated at the time of the respective acquisition), the weighted-average periods prior to the next renewal or extension of the contractual customer relationships associated with the ACMP and Eagle Ford acquisitions were approximately 17 years and 10 years, respectively. Although a significant portion of the expected future cash flows associated with these contractual customer relationships are dependent on our ability to renew or extend the arrangements beyond the initial contract periods, these expected future cash flows are significantly influenced by the scope and pace of our producer customers’ drilling programs. Once producer customers’ wells are connected to our gathering infrastructure, their likelihood of switching to another provider before the wells are abandoned is reduced due to the significant capital investment required.

The amortization expense related to other intangible assets was $356 million, $353 million, and $209 million in 2016, 2015, and 2014, respectively. The estimated amortization expense for each of the next five succeeding fiscal years is approximately $356 million.

XML

Accrued Liabilities

12 Months Ended

Dec. 31, 2016

Accrued Liabilities, Current [Abstract]

Accrued Liabilities [Text Block]

Note 13 – Accrued Liabilities

	December 31,
	2016		2015
	(Millions)
Deferred income	$	338	$	94
Interest on debt	310		284
Employee costs	223		215
Refundable deposits	160		—
Special distribution repayable to Gulfstream (See Note 6 - Investing Activities)	—		149
Asset retirement obligations	61		57
Other, including other loss contingencies	356		279
	$	1,448	$	1,078

Deferred income in 2016 includes cash proceeds associated with restructuring certain gas gathering contracts in the Barnett Shale and Mid-Continent regions. (See Note 1 – General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies.)

Refundable deposits in 2016 includes receipts related to an agreement to resolve several matters in relation to Transco’s Hillabee Expansion Project. In accordance with the agreement, the member–sponsors of Sabal Trail will pay WPZ an aggregate amount of $240 million in three equal installments as certain milestones of the project are met, of which $160 million was received in 2016. WPZ expects to recognize income associated with these receipts over the term of an underlying contract once the project is in service.

XML

Debt, Banking Arrangements, and Leases

12 Months Ended

Dec. 31, 2016

Debt Disclosure [Abstract]

Debt, Banking Arrangements, and Leases [Text Block]

Note 14 – Debt, Banking Arrangements, and Leases

Long-Term Debt

	December 31,
	2016		2015
	(Millions)
Unsecured:
Transco:
6.4% Notes due 2016 (1)	$	—	$	200
6.05% Notes due 2018	250		250
7.08% Debentures due 2026	8		8
7.25% Debentures due 2026	200		200
7.85% Notes due 2026	1,000		—
5.4% Notes due 2041	375		375
4.45% Notes due 2042	400		400
Northwest Pipeline:
7% Notes due 2016	—		175
5.95% Notes due 2017	185		185
6.05% Notes due 2018	250		250
7.125% Debentures due 2025	85		85
WPZ:
7.25% Notes due 2017	600		600
5.25% Notes due 2020	1,500		1,500
4.125% Notes due 2020	600		600
4% Notes due 2021	500		500
3.6% Notes due 2022	1,250		1,250
3.35% Notes due 2022	750		750
6.125% Notes due 2022	750		750
4.5% Notes due 2023	600		600
4.875% Notes due 2023	1,400		1,400
4.3% Notes due 2024	1,000		1,000
4.875% Notes due 2024	750		750
3.9% Notes due 2025	750		750
4% Notes due 2025	750		750
6.3% Notes due 2040	1,250		1,250
5.8% Notes due 2043	400		400
5.4% Notes due 2044	500		500
4.9% Notes due 2045	500		500
5.1% Notes due 2045	1,000		1,000
Term Loan, variable interest rate, due 2018	850		850
Credit facility loans	—		1,310
WMB:
7.875% Notes due 2021	371		371
3.7% Notes due 2023	850		850
4.55% Notes due 2024	1,250		1,250
7.5% Debentures due 2031	339		339

	December 31,
	2016			2015
	(Millions)
7.75% Notes due 2031	252			252
8.75% Notes due 2032	445			445
5.75% Notes due 2044	650			650
Various — 5.5% to 10.25% Notes and Debentures due 2019 to 2033	55			55
Credit facility loans	775			650
Capital lease obligations	—			1
Debt issuance costs	(119		)	(123		)
Net unamortized debt premium (discount)	88			110
Total long-term debt, including current portion	23,409			23,988
Long-term debt due within one year	(785		)	(176		)
Long-term debt	$	22,624		$	23,812

___________

(1) Presented as long-term debt at December 31, 2015, due to Transco’s intent and ability to refinance.

Certain of our debt agreements contain covenants that restrict or limit, among other things, our ability to create liens supporting indebtedness, sell assets, and incur additional debt. Default of these agreements could also restrict our ability to make certain distributions or repurchase equity.

The following table presents aggregate minimum maturities of long-term debt, excluding net unamortized debt premium (discount), debt issuance costs, and capital lease obligations, for each of the next five years:

	December 31, 2016
	(Millions)
2017	$	785
2018	1,350
2019	32
2020	2,896
2021	871

Issuances and retirements

WPZ retired $600 million of 7.25 percent senior unsecured notes that matured on February 1, 2017.

Northwest Pipeline retired $175 million of 7 percent senior unsecured notes that matured on June 15, 2016.

Transco retired $200 million of 6.4 percent senior unsecured notes that matured on April 15, 2016.

On January 22, 2016, Transco issued $1 billion of 7.85 percent senior unsecured notes due 2026 to investors in a private debt placement. In January 2017, Transco completed an exchange of these notes for substantially identical new notes that are registered under the Securities Act of 1933, as amended. Transco used the net proceeds to repay debt and to fund capital expenditures.

In December 2015, WPZ borrowed $850 million on a variable interest rate loan with certain lenders due 2018. At December 31, 2016, the interest rate was 2.50 percent. WPZ used the proceeds for working capital, capital expenditures, and for general partnership purposes.

On April 15, 2015, WPZ paid $783 million, including a redemption premium, to early retire $750 million of 5.875 percent senior notes due 2021 with a carrying value of $797 million.

On March 3, 2015, WPZ completed a public offering of $1.25 billion of 3.6 percent senior unsecured notes due 2022, $750 million of 4 percent senior unsecured notes due 2025, and $1 billion of 5.1 percent senior unsecured notes due 2045. WPZ used the net proceeds to repay amounts outstanding under its commercial paper program and credit facility, to fund capital expenditures, and for general partnership purposes.

WPZ retired $750 million of 3.8 percent senior unsecured notes that matured on February 15, 2015.

Credit Facilities

	December 31, 2016
	Available		Outstanding
	(Millions)
WMB
Long-term credit facility	$	1,500	$	775
Letters of credit under certain bilateral bank agreements			13
WPZ
Long-term credit facility (1)	3,500		—
Letters of credit under certain bilateral bank agreements			1

________________

(1) In managing our available liquidity, we do not expect a maximum outstanding amount in excess of the capacity of our credit facility inclusive of any outstanding amounts under our commercial paper program.

WMB long-term credit facility

On February 2, 2015, we entered into the Second Amended and Restated Credit Agreement. The aggregate commitments available remained at $1.5 billion, with up to an additional $500 million increase in aggregate commitments available under certain circumstances. The maturity date of the credit facility was extended to February 2, 2020. However, we may request up to two extensions of the maturity date each for an additional one year period to allow a maturity date as late as February 2, 2022, under certain circumstances. The agreement also allows for swing line loans up to an aggregate amount of $50 million, subject to available capacity under the credit facility, and the letters of credit up to $675 million.

The agreements governing the credit facilities contain the following terms and conditions:

• Various covenants may limit, among other things, a borrower’s and its material subsidiaries’ ability to grant certain liens supporting indebtedness, merge or consolidate, sell all or substantially all of its assets, enter into certain affiliate transactions, make certain distributions during an event of default, make investments, and allow any material change in the nature of its business.

• If an event of default with respect to a borrower occurs under its respective credit facility, the lenders will be able to terminate the commitments for the respective borrowers and accelerate the maturity of any loans of the defaulting borrower under the respective credit facility agreement and exercise other rights and remedies.

• Each time funds are borrowed under our credit facility, the borrower may choose from two methods of calculating interest: a fluctuating base rate equal to the bank’s alternate base rate plus an applicable margin or a periodic fixed rate equal to LIBOR plus an applicable margin. The borrower is required to pay a commitment fee based on the unused portion of its respective credit facility. The applicable margin and the commitment fee are determined for us by reference to a pricing schedule based on our senior unsecured long-term debt ratings.

Significant financial covenants under the agreement require the ratio of debt to EBITDA (each as defined in the credit agreement) be no greater than 5 to 1, except for the fiscal quarter and the two following fiscal quarters in which one or more acquisitions has been executed, in which case the ratio of debt to EBITDA is to be no greater than 5.5 to 1.

We are in compliance with these financial covenants as measured at December 31, 2016.

As of February 20, 2017, $235 million is outstanding under our long-term credit facility.

WPZ long-term credit facilities

Prior to their merger both WPZ and ACMP had separate credit facilities that terminated on February 2, 2015.

On February 2, 2015, WPZ along with Transco, Northwest Pipeline, the lenders named therein, and an administrative agent entered into the Second Amended & Restated Credit Agreement with aggregate commitments available of $3.5 billion, with up to an additional $500 million increase in aggregate commitments available under certain circumstances. The maturity date of the credit facility is February 2, 2020. However, the co-borrowers may request up to two extensions of the maturity date each for an additional one year period to allow a maturity date as late as February 2, 2022, under certain circumstances. The agreement allows for swing line loans up to an aggregate amount of $150 million, subject to available capacity under the credit facility, and letters of credit commitments of $1.125 billion. Transco and Northwest Pipeline are each able to borrow up to $500 million under this credit facility to the extent not otherwise utilized by the other co-borrowers. On December 18, 2015, WPZ along with Transco, Northwest Pipeline, the lenders named therein and an administrative agent entered into the Amendment No. 1 to Second Amended & Restated Credit Agreement modifying the thresholds specified in the covenant related to the maximum ratio of WPZ’s debt to EBITDA.

The agreement governing this credit facility contains the following terms and conditions:

• Various covenants may limit, among other things, a borrower’s and its material subsidiaries’ ability to grant certain liens supporting indebtedness, merge or consolidate, sell all or substantially all of its assets, enter into certain affiliate transactions, make certain distributions during an event of default, enter into certain restrictive agreements, and allow any material change in the nature of its business.

• If an event of default with respect to a borrower occurs under the credit facility, the lenders will be able to terminate the commitments for all borrowers and accelerate the maturity of any loans of the defaulting borrower under the credit facility agreement and exercise other rights and remedies.

• Other than swing line loans, each time funds are borrowed, the borrower must choose whether such borrowing will be an alternate base rate borrowing or a Eurodollar borrowing.  If such borrowing is an alternate base rate borrowing, interest is calculated on the basis of the greater of (a) the Prime Rate, (b) the Federal Funds Effective Rate plus one half of 1 percent and (c) a periodic fixed rate equal to the London Interbank Offered Rate (LIBOR) plus 1 percent, plus, in the case of each of (a), (b) and (c), an applicable margin. If the borrowing is a Eurodollar borrowing, interest is calculated on the basis of LIBOR for the relevant period plus an applicable margin.  Interest on swing line loans is calculated as the sum of the alternate base rate plus an applicable margin.  The borrower is required to pay a commitment fee based on the unused portion of the credit facility. The applicable margin and the commitment fee are determined for each borrower by reference to a pricing schedule based on such borrower’s senior unsecured long-term debt ratings.

Significant financial covenants under the agreement require the ratio of debt to EBITDA, each as defined in the credit facility, be no greater than:

• 5.75 to 1, for the quarters ending December 31, 2015, March 31, 2016 and June 30, 2016;

• 5.50 to 1, for the quarters ending September 30, 2016 and December 31, 2016;

• 5.00 to 1, for the quarter ending March 31, 2017 and each subsequent fiscal quarter, except for the the fiscal quarter and the two following fiscal quarters in which one or more acquisitions has been executed, in which case the ratio of debt to EBITDA is to be no greater than 5.5 to 1.00.

The ratio of debt to capitalization (defined as net worth plus debt) must be no greater than 65 percent for each Transco and Northwest Pipeline. WPZ is in compliance with these financial covenants as measured at December 31, 2016.

As of February 20, 2017, there are no amounts outstanding under the long-term credit facility.

WPZ short-term credit facilities

On August 26, 2015, WPZ entered into a $1.0 billion short-term credit facility. On December 23, 2015, WPZ’s short-term credit facility capacity decreased to $150 million in conjunction with entering into the $850 million term loan. The $150 million short-term credit facility is no longer available as it expired August 24, 2016.

Commercial Paper Program

On February 2, 2015, WPZ amended and restated the commercial paper program for the ACMP Merger and to allow a maximum outstanding amount of unsecured commercial paper notes of $3 billion. The maturities of the commercial paper notes vary but may not exceed 397 days from the date of issuance. The commercial paper notes are sold under customary terms in the commercial paper market and are issued at a discount from par, or, alternatively, are sold at par and bear varying interest rates on a fixed or floating basis. Proceeds from these notes are used for general partnership purposes, including funding capital expenditures, working capital, and partnership distributions. We classify WPZ’s commercial paper outstanding in Current liabilities in the Consolidated Balance Sheet, as the outstanding notes at December 31, 2016 and December 31, 2015, have maturity dates less than three months from the date of issuance. At December 31, 2016, WPZ had $93 million in Commercial paper outstanding at a weighted-average interest rate of 1.06 percent and at December 31, 2015, WPZ had $499 million in Commercial paper outstanding at a weighted-average interest rate of 0.92 percent.

Cash Payments for Interest (Net of Amounts Capitalized)

Cash payments for interest (net of amounts capitalized)were $1.152 billion in 2016, $1.023 billion in 2015, and $681 million in 2014.

Restricted Net Assets of Subsidiaries

We have considered the guidance in the Securities and Exchange Commission’s Regulation S-X related to restricted net assets of subsidiaries. In accordance with Rule 4-08(e) of Regulation S-X, we have determined that certain net assets of our subsidiaries are considered restricted under this guidance and exceed 25 percent of our consolidated net assets. As of December 31, 2016, substantially all of these restricted net assets relate to the net assets of WPZ, which are technically considered restricted under this accounting rule due to terms within WPZ’s partnership agreement that govern the partnerships’ assets. Our interest in WPZ’s net assets that are considered to be restricted at December 31, 2016, was $13 billion.

Leases-Lessee

The future minimum annual rentals under noncancelable operating leases, are payable as follows:

	December 31, 2016
	(Millions)
2017	$	62
2018	58
2019	51
2020	46
2021	35
Thereafter	90
Total	$	342

Total rent expense was $64 million in 2016, $69 million in 2015, and $62 million in 2014 and primarily included in Operating and maintenance expenses and Selling, general, and administrative expenses in the Consolidated Statement of Operations.

Other

On January 25, 2017, WPZ announced that it will redeem all of its $750 million6.125 percent senior notes due 2022 on February 23, 2017.

XML

Stockholders' Equity

12 Months Ended

Dec. 31, 2016

Stockholders' Equity Note [Abstract]

Stockholders' Equity [Text Block]

Note 15 – Stockholders' Equity

Cash dividends declared per common share were $1.68, $2.45, and $1.9575 for 2016, 2015, and 2014, respectively. On February 20, 2017, our board of directors approved a regular quarterly dividend of $0.30 per share payable on March 27, 2017.

In January 2017, we issued 65 million shares of common stock in a public offering at a price of $29.00 per share. In February 2017, we issued 9.75 million shares of common stock pursuant to the full exercise of the underwriter’s option to purchase additional shares. The net proceeds of approximately $2.1 billion were used to purchase newly issued common units in WPZ as part of our Financial Repositioning. (See Note 1 - General, Description of Business, Basis of Presentation and Summary of Significant Accounting Policies.)

On June 23, 2014, we issued 61 million shares of common stock in a public offering at a price of $57.00 per share. That amount includes 8 million shares purchased pursuant to the full exercise of the underwriter’s option to purchase additional shares. The net proceeds of $3.378 billion were used in July 2014 to finance a portion of the ACMP Acquisition. (See Note 2 - Acquisitions.)

AOCI

The following table presents the changes in AOCI by component, net of income taxes:

	Cash Flow Hedges			Foreign Currency Translation			Pension and Other Post Retirement Benefits			Total
	(Millions)
Balance at December 31, 2015	$	(1	)	$	(103	)	$	(338	)	$	(442	)
Other comprehensive income (loss) before reclassifications	2			25			(15		)	12
Amounts reclassified from accumulated othercomprehensive income (loss)	(1		)	76			16			91
Other comprehensive income (loss)	1			101			1			103
Balance at December 31, 2016	$	—		$	(2	)	$	(337	)	$	(339	)

Reclassifications out of AOCI are presented in the following table by component for the year ended December 31, 2016:

Component	Reclassifications			Classification
	(Millions)
Cash flow hedges:
Energy commodity contracts	$	(3	)	Product sales
Total cash flow hedges	(3		)
Pension and other postretirement benefits:
Amortization of prior service cost (credit) included in net periodic benefit cost	(6		)	Note 10 – Employee Benefit Plans
Amortization of actuarial (gain) loss included in net periodic benefit cost	32			Note 10 – Employee Benefit Plans
Total pension and other postretirement benefits	26
Foreign currency translation:
Reclassification of cumulative foreign currency translation adjustment upon sale of foreign entities	155			Other (income) expense - net
Total before tax	178
Income tax benefit	(45		)	Provision (benefit) for income taxes
Net of income tax	133
Noncontrolling interest	(42		)	Net income (loss) attributable to noncontrolling interests
Reclassifications during the period	$	91

XML

Equity-Based Compensation

12 Months Ended

Dec. 31, 2016

Share-based Compensation [Abstract]

Equity-Based Compensation [Text Block]

Note 16 – Equity-Based Compensation

Williams’ Plan Information

On May 17, 2007, our stockholders approved The Williams Companies, Inc. 2007 Incentive Plan (the Plan) that provides common-stock-based awards to both employees and nonmanagement directors and reserved 19 million new shares for issuance. On May 20, 2010 and May 22, 2014, our stockholders approved amendments and restatements of the Plan to increase by 11 million and 10 million, respectively, the number of new shares authorized for making awards under the Plan, among other changes. The Plan permits the granting of various types of awards including, but not limited to, restricted stock units and stock options. At December 31, 2016, 27 million shares of our common stock were reserved for issuance pursuant to existing and future stock awards, of which 17 million shares were available for future grants.

Additionally, on May 17, 2007, our stockholders approved an Employee Stock Purchase Plan (ESPP) which authorized up to 2 million new shares of our common stock to be available for sale under the ESPP. On May 22, 2014, our stockholders approved an amendment and restatement of the ESPP to increase by 1.6 million the number of new shares authorized for sale under the ESPP. The ESPP enables eligible participants to purchase our common stock through payroll deductions not exceeding an annual amount of $15,000 per participant. The ESPP provides for offering periods during which shares may be purchased and continues until the earliest of (1) the Board of Directors terminates the ESPP, (2) the sale of all shares available under the ESPP, or (3) the tenth anniversary of the date the amended and restated ESPP was approved by the stockholders. Offering periods are from January through June and from July through December. Generally, all employees are eligible to participate in the ESPP, with the exception of executives and international employees. The number of shares eligible for an employee to purchase during each offering period is limited to 750 shares. The purchase price of the stock is 85 percent of the lower closing price of either the first or the last day of the offering period. The ESPP requires a one-year holding period before the stock can be sold. The plan was suspended during the period from January 1, 2016 to August 31, 2016, and was reinstated effective September 1, 2016. Employees purchased111 thousand shares at an average price of $23.93 per share during the period from September 1, 2016 to December 31, 2016. Approximately 1.4 million shares were available for purchase under the ESPP at December 31, 2016.

Operating and maintenance expenses and Selling, general and administrative expenses include equity-based compensation expense for the years ended December 31, 2016, 2015, and 2014 of $53 million, $56 million, and $44 million, respectively. Income tax benefit recognized related to the stock-based compensation expense for the years ended December 31, 2016, 2015, and 2014 was $20 million, $21 million, and $17 million, respectively. Measured but unrecognized stock-based compensation expense at December 31, 2016, was $67 million, which does not include the effect of estimated forfeitures of $2 million. Unrecognized stock-based compensation expense is comprised of $5 million related to stock options and $62 million related to restricted stock units. These amounts are expected to be recognized over a weighted-average period of 1.9 years.

Stock Options

Stock options are valued at the date of award, which does not precede the approval date. The purchase price per share for stock options may not be less than the market price of the underlying stock on the date of grant. Stock options generally become exercisable over a three-year period from the date of grant. Stock options generally expire ten years after the grant.

The following summary reflects stock option activity and related information for the year ended December 31, 2016:

Stock Options	Options		Weighted- Average Exercise Price		Aggregate Intrinsic Value
	(Millions)				(Millions)
Outstanding at December 31, 2015	5.7		$	31.51
Granted	0.9		$	24.99
Exercised	(0.3	)	$	17.84
Cancelled	(0.1	)	$	24.04
Outstanding at December 31, 2016	6.2		$	31.32	$	28
Exercisable at December 31, 2016	5.0		$	29.75	$	23

The following table summarizes additional information related to stock option activity during each of the last three years:

	Years Ended December 31,
	2016		2015		2014
	(Millions)
Total intrinsic value of options exercised	$	2	$	37	$	48
Tax benefits realized on options exercised	$	1	$	13	$	18
Cash received from the exercise of options	$	4	$	20	$	31

The weighted-average remaining contractual life for stock options outstanding and exercisable at December 31, 2016, was 5.5 years and 4.2 years, respectively.

The estimated fair value at date of grant of options for our common stock granted in each respective year, using the Black-Scholes option pricing model, is as follows: 

	2016			2015			2014
Weighted-average grant date fair value of options for our common stock granted during the year, per share	$	7.90		$	7.61		$	7.50
Weighted-average assumptions:
Dividend yield	3.2		%	4.8		%	4.2		%
Volatility	44.7		%	27.8		%	28.0		%
Risk-free interest rate	1.2		%	1.8		%	2.2		%
Expected life (years)	6.0			6.0			6.5

The 2016 expected dividend yield is based on the 2016 dividend forecast and the grant-date market price of our stock. Expected volatility is based on the average of our peer group 10-year historical volatility adjusted by a ratio of our implied volatility to the adjusted average of our peer group’s implied volatility. The adjustment is made because the difference in implied volatility between our peer group and us may indicate that we are expected to be more volatile than our peer group average. The risk-free interest rate is based on the U.S. Treasury Constant Maturity rates as of the grant date. The expected life of the option is based on historical exercise behavior and expected future experience.

Nonvested Restricted Stock Units

The following summary reflects nonvested restricted stock unit activity and related information for the year ended December 31, 2016:

Restricted Stock Units Outstanding	Shares		Weighted- Average Fair Value (1)
	(Millions)
Nonvested at December 31, 2015	3.4		$	39.38
Granted	1.5		$	26.51
Forfeited	(0.1	)	$	38.18
Vested	(0.9	)	$	35.49
Nonvested at December 31, 2016	3.9		$	35.19

______________

(1) Performance-based restricted stock units are valued utilizing a Monte Carlo valuation method using measures of total shareholder return. Certain of the performance-based restricted stock units are subject to a holding period of up to two years after the vesting date. Discounts for the restrictions of liquidity were applied to the estimated fair value at the date of certain awards and ranged from 5.83 percent to 15.58 percent. The discounts were developed using the Chaffe model and the Finnerty model. All other restricted stock units are valued at the grant-date market price. Restricted stock units generally vest after three years.

Value of Restricted Stock Units	2016		2015		2014
Weighted-average grant date fair value of restricted stock units granted during the year, per share	$	26.51	$	40.15	$	42.79
Total fair value of restricted stock units vested during the year ($’s in millions)	$	32	$	42	$	27

Performance-based restricted stock units granted under the Plan represent40 percent of nonvested restricted stock units outstanding at December 31, 2016. These grants may be earned at the end of the vesting period based on actual performance against a performance target. Based on the extent to which certain financial targets are achieved, vested shares may range from zero percent to 500 percent of the original grant amount.

WPZ’s Plan Information

During 2014, certain employees of ACMP’s general partner received equity-based compensation through ACMP’s equity-based compensation program. The fair value of the awards issued was based on the fair market value of the common units on the date of grant. This value is being amortized over the vesting period, which is one to four years from the date of grant. These awards were converted to WPZ equity-based awards in accordance with the terms of the ACMP Merger. No additional grants of restricted common units were awarded through WPZ’s equity-based compensation programs in 2016 or 2015, and no additional grants are expected in the future. Equity-based compensation expense of $20 million, $29 million, and $11 million related to WPZ’s equity-based compensation program is included in Operating and maintenance expenses andSelling, general, and administrative expenses for the years ended December 31, 2016, 2015, and 2014, respectively. As of December 31, 2016, there was $11 million of unrecognized compensation expense attributable to the outstanding awards, which does not include the effect of estimated forfeitures of $1 million. These amounts are expected to be recognized over a weighted average period of 1.2 years.

The following summary reflects nonvested WPZ restricted common unit activity and related information for the year ended December 31, 2016:

Restricted Common Units Outstanding	Units		Weighted- Average Fair Value
	(Millions)
Nonvested at December 31, 2015	1.2		$	55.93
Forfeited	(0.1	)	$	52.85
Vested	(0.5	)	$	59.09
Nonvested at December 31, 2016	0.6		$	52.97

XML

Fair Value Measurements, Guarantees, and Concentration of Credit Risk

12 Months Ended

Dec. 31, 2016

Fair Value Disclosures [Abstract]

Fair Value Measurements, Guarantees, and Concentration of Credit Risk [Text Block]

Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk

The following table presents, by level within the fair value hierarchy, certain of our financial assets and liabilities. The carrying values of cash and cash equivalents, accounts receivable, commercial paper, and accounts payable approximate fair value because of the short-term nature of these instruments. Therefore, these assets and liabilities are not presented in the following table.

							Fair Value Measurements Using
	Carrying Amount			Fair Value			Quoted Prices In Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
	(Millions)
Assets (liabilities) at December 31, 2016:
Measured on a recurring basis:
ARO Trust investments	$	96		$	96		$	96	$	—		$	—
Energy derivatives assets designated as hedging instruments	2			2			—		2			—
Energy derivatives assets not designated as hedging instruments	1			1			—		—			1
Energy derivatives liabilities not designated as hedging instruments	(6		)	(6		)	—		—			(6		)
Additional disclosures:
Other receivables	15			15			15		—			—
Long-term debt, including current portion	(23,409		)	(24,090		)	—		(24,090		)	—
Guarantees	(44		)	(30		)	—		(14		)	(16		)
Assets (liabilities) at December 31, 2015:
Measured on a recurring basis:
ARO Trust investments	$	67		$	67		$	67	$	—		$	—
Energy derivatives assets not designated as hedging instruments	5			5			—		3			2
Energy derivatives liabilities not designated as hedging instruments	(2		)	(2		)	—		—			(2		)
Additional disclosures:
Other receivables	12			30			10		2			18
Long-term debt, including current portion (1)	(23,987		)	(19,606		)	—		(19,606		)	—
Guarantee	(29		)	(16		)	—		(16		)	—

___________

(1) Excludes capital leases.

Fair Value Methods

We use the following methods and assumptions in estimating the fair value of our financial instruments:

Assets and liabilities measured at fair value on a recurring basis

ARO Trust investments: Transco deposits a portion of its collected rates, pursuant to its rate case settlement, into an external trust that is specifically designated to fund future asset retirement obligations. The ARO Trust invests in a portfolio of actively traded mutual funds that are measured at fair value on a recurring basis based on quoted prices in an active market, is classified as available-for-sale, and is reported in Regulatory assets, deferred charges, and other in the Consolidated Balance Sheet. Both realized and unrealized gains and losses are ultimately recorded as regulatory assets or liabilities.

Energy derivatives: Energy derivatives include commodity based exchange-traded contracts and over-the-counter contracts, which consist of physical forwards, futures, and swaps that are measured at fair value on a recurring basis. The fair value amounts are presented on a gross basis and do not reflect the netting of asset and liability positions permitted under the terms of our master netting arrangements. Further, the amounts do not include cash held on deposit in margin accounts that we have received or remitted to collateralize certain derivative positions. Energy derivatives assets are reported in Other current assets and deferred charges and Regulatory assets, deferred charges, and other in the Consolidated Balance Sheet. Energy derivatives liabilities are reported in Accrued liabilities and Regulatory liabilities, deferred income, and other in the Consolidated Balance Sheet.

Reclassifications of fair value between Level 1, Level 2, and Level 3 of the fair value hierarchy, if applicable, are made at the end of each quarter. No transfers between Level 1 and Level 2 occurred during the years ended December 31, 2016 or 2015.

Additional fair value disclosures

Other receivables: Other receivables primarily consist of margin deposits, which are reported in Other current assets and deferred charges in the Consolidated Balance Sheet. The disclosed fair value of our margin deposits is considered to approximate the carrying value generally due to the short-term nature of these items.

Other receivables also include a receivable related to the sale of certain former Venezuela assets. The disclosed fair value of this receivable is determined by an income approach. We calculated the net present value of a probability-weighted set of cash flows utilizing assumptions based on contractual terms, historical payment patterns by the counterparty, future probabilities of default, our likelihood of using arbitration if the counterparty does not perform, and discount rates. We determined the fair value of the receivable to be $18 million at December 31, 2015. We received two payments in 2016. The carrying value of this receivable iszero at December 31, 2016 and December 31, 2015.

Long-term debt: The disclosed fair value of our long-term debt is determined by a market approach using broker quoted indicative period-end bond prices. The quoted prices are based on observable transactions in less active markets for our debt or similar instruments.

Guarantees: Guarantees primarily consist of a guarantee we have provided in the event of nonpayment by our previously owned communications subsidiary, Williams Communications Group (WilTel), on a lease performance obligation that extends through 2042. Guarantees also include an indemnification related to a disposed operation.

To estimate the disclosed fair value of the WilTel guarantee, an estimated default rate is applied to the sum of the future contractual lease payments using an income approach. The estimated default rate is determined by obtaining the average cumulative issuer-weighted corporate default rate based on the credit rating of WilTel’s current owner and the term of the underlying obligation. The default rate is published by Moody’s Investors Service. The carrying value of the WilTel guarantee is reported in Accrued liabilities in the Consolidated Balance Sheet. The maximum potential undiscounted exposure is approximately $32 million at December 31, 2016. Our exposure declines systematically through the remaining term of WilTel’s obligation.

The fair value of the guarantee associated with the indemnification related to a disposed operation was estimated using an income approach that considered probability-weighted scenarios of potential levels of future performance. The terms of the indemnification do not limit the maximum potential future payments associated with the guarantee. The carrying value of this guarantee is reported in Regulatory liabilities, deferred income, and other in the Consolidated Balance Sheet.

We are required by our revolving credit agreements to indemnify lenders for certain taxes required to be withheld from payments due to the lenders and for certain tax payments made by the lenders. The maximum potential amount of future payments under these indemnifications is based on the related borrowings and such future payments cannot currently be determined. These indemnifications generally continue indefinitely unless limited by the underlying tax regulations and have no carrying value. We have never been called upon to perform under these indemnifications and have no current expectation of a future claim.

Nonrecurring fair value measurements

We performed an interim assessment of the goodwill associated with our Central and Northeast G&P reporting units as of September 30, 2015, and the annual assessment of goodwill associated with our Northeast G&P and West reporting units as of October 1, 2015. No impairment charges were required following these evaluations.

During the fourth quarter of 2015, we observed a significant decline in the market values of WPZ and comparable midstream companies within the industry. This served to reduce our estimate of enterprise value and increased our estimates of discount rates. As a result, we performed an impairment assessment as of December 31, 2015, of the goodwill associated with these reporting units, all within the Williams Partners segment.

We estimated the fair value of each reporting unit based on an income approach utilizing discount rates specific to the underlying businesses of each reporting unit. These discount rates considered variables unique to each business area, including equity yields of comparable midstream businesses, expectations for future growth, and customer performance considerations. Weighted-average discount rates utilized ranged from approximately 10 percent to 13 percent across the three reporting units.

As a result of the increases in discount rates during the fourth quarter of 2015, coupled with certain reductions in estimated future cash flows determined during the same period, the fair values of the Central and Northeast G&P reporting units were determined to be below their respective carrying values. For these measurements, the book basis of each reporting unit was reduced by the associated deferred tax liabilities. We then calculated the implied fair value of goodwill by performing a hypothetical application of the acquisition method wherein the estimated fair value was allocated to the underlying assets and liabilities of each reporting unit. As a result of these Level 3 measurements, we determined that the previously recorded goodwill associated with each reporting unit was fully impaired, resulting in a fourth-quarter 2015 noncash charge of $1,098 million, reflected in Impairment of goodwill in the Consolidated Statement of Operations. For the West reporting unit, the estimated fair value exceeded the carrying value and no impairment was recorded.

The following table presents impairments of assets and investments associated with certain nonrecurring fair value measurements within Level 3 of the fair value hierarchy.

						Impairments
						Years Ended December 31,
	Classification	Segment	Date of Measurement	Fair Value		2016		2015		2014
				(Millions)
Surplus equipment (1)	Property, plant, and equipment – net	Williams Partners	June 30, 2014	$	46					$	17
Surplus equipment (1)	Property, plant, and equipment – net	Williams Partners	December 31, 2014	32						13
Surplus equipment (1)	Property, plant, and equipment – net	Williams Partners	June 30, 2015	17				$	20
Surplus equipment (1)	Assets held for sale	Williams Partners	December 31, 2014	1						12
Previously capitalized project development costs (2)	Property, plant, and equipment – net	Williams Partners	December 31, 2015	13				94
Previously capitalized project development costs (3)	Property, plant, and equipment – net	Williams NGL & Petchem Services	December 31, 2015	40				64
Canadian operations (4)	Assets held for sale	Williams Partners	June 30, 2016	924		$	341
Canadian operations (4)	Assets held for sale	Williams NGL & Petchem Services	June 30, 2016	206		406
Certain gathering operations (5)	Property, plant, and equipment – net	Williams Partners	June 30, 2016	18		48
Certain idle assets	Property, plant, and equipment – net	Williams NGL & Petchem Services	December 31, 2016	73		8
Level 3 fair value measurements of certain assets						803		178		42
Other impairments and write-downs (6)						70		31		10
Impairment of certain assets						$	873	$	209	$	52
Equity-method investments (7)	Investments	Williams Partners	September 30, 2015	$	1,203			$	461
Equity-method investments (8)	Investments	Williams Partners	December 31, 2015	4,017				890
Equity-method investments (9)	Investments	Williams Partners	March 31, 2016	1,294		$	109
Equity-method investments (10)	Investments	Williams Partners	December 31, 2016	1,295		318
Other equity-method investment	Investments	Williams Partners	December 31, 2015	58				8
Other equity-method investment	Investments	Williams Partners	March 31, 2016	—		3
Impairment of equity-method investments						$	430	$	1,359

______________

(1) Relates to certain surplus equipment. The estimated fair value was determined by a market approach based on our analysis of observable inputs in the principal market.

(2) Relates to a gas processing plant, the completion of which is considered remote due to unfavorable impact of low natural gas prices on customer drilling activities. The assessed fair value primarily represents the estimated salvage value of certain equipment measured using a market approach based on our analysis of observable inputs in the principal market.

(3) Relates to an olefins pipeline project, the completion of which is considered remote due to lack of customer interest. The assessed fair value primarily represents the estimated fair value of unused pipeline measured using a market approach based on our analysis of observable inputs in the principal market.

(4) Relates to our Canadian operations. We designated these operations as held for sale as of June 30, 2016. As a result, we measured the fair value of the disposal group, resulting in an impairment charge. The estimated fair value was determined by a market approach based primarily on inputs received in the marketing process and reflected our estimate of the potential assumed proceeds. We disposed of our Canadian operations through a sale during the third quarter of 2016. See Note 3 – Divestiture.

(5) Relates to certain gathering assets within the Mid-Continent region. The estimated fair value was determined by a market approach based on our analysis of observable inputs in the principal market.

(6) Reflects multiple individually insignificant impairments and write-downs of other certain assets that may no longer be in use or are surplus in nature for which the fair value was determined to be zero or an insignificant salvage value.

(7) Relates to equity-method investments in DBJV and certain of the Appalachia Midstream Investments. The historical carrying value of these investments was initially recorded based on estimated fair value during the third quarter of 2014 in conjunction with the acquisition of ACMP. We estimated the fair value of these investments using an income approach based on expected future cash flows and appropriate discount rates. The determination of estimated future cash flows involved significant assumptions regarding gathering volumes and related capital spending. Discount rates utilized were 11.8 percent and 8.8 percent for DBJV and certain of the Appalachia Midstream Investments, respectively, and reflected our cost of capital as impacted by market conditions, and risks associated with the underlying businesses.

(8) Relates to equity-method investments in DBJV, certain of the Appalachia Midstream Investments, UEOM, and Laurel Mountain. We estimated the fair value of these investments using an income approach based on expected future cash flows and appropriate discount rates. The determination of estimated future cash flows involved significant assumptions regarding gathering volumes and related capital spending. Discount rates utilized ranged from 10.8 percent to 14.4 percent and reflected further fourth-quarter 2015 increases in our cost of capital, revised estimates of expected future cash flows, and risks associated with the underlying businesses.

(9) Relates to equity-method investments in DBJV and Laurel Mountain. Our carrying values in these equity-method investments had been written down to fair value at December 31, 2015. Our first-quarter 2016 analysis reflected higher discount rates for both of these investments, along with lower natural gas prices for Laurel Mountain. We estimated the fair value of these investments using an income approach based on expected future cash flows and appropriate discount rates. The determination of estimated future cash flows involved significant assumptions regarding gathering volumes and related capital spending. Discount rates utilized ranged from 13.0 percent to 13.3 percent and reflected increases in our cost of capital, revised estimates of expected future cash flows, and risks associated with the underlying businesses.

(10) Relates to equity-method investments in Ranch Westex and multiple Appalachia Midstream Investments. The historical carrying value of these investments was initially recorded based on estimated fair value during the third quarter of 2014 in conjunction with the acquisition of ACMP. We estimated the fair value of these Appalachia Midstream Investments using an income approach based on expected future cash flows and appropriate discount rates. The determination of estimated future cash flows involved significant assumptions regarding gathering volumes, rates, and related capital spending. The discount rate utilized for the Appalachia Midstream Investments evaluation was 10.2 percent and reflected our cost of capital as impacted by market conditions and risks associated with the underlying businesses. In addition to utilizing an income approach, we also considered a market approach for certain Appalachia Midstream Investments and Ranch Westex based on an agreement reached in February 2017 to exchange our interests in DBJV and Ranch Westex for additional interests in certain Appalachia Midstream Investments and cash.

Concentration of Credit Risk

Cash equivalents

Our cash equivalents are primarily invested in funds with high-quality, short-term securities and instruments that are issued or guaranteed by the U.S. government.

Trade accounts and other receivables

The following table summarizes concentration of receivables, net of allowances:

	December 31,
	2016		2015
	(Millions)
NGLs, natural gas, and related products and services	$	736	$	823
Transportation of natural gas and related products	187		202
Other	15		16
Total	$	938	$	1,041

Customers include producers, distribution companies, industrial users, gas marketers, and pipelines primarily located in the continental United States. As a general policy, collateral is not required for receivables, but customers’ financial condition and credit worthiness are evaluated regularly. Based upon this evaluation, we may obtain collateral to support receivables. As of December 31, 2016 and 2015, Chesapeake Energy Corporation, and its affiliates (Chesapeake), a customer within our Williams Partners segment, accounted for$133 million and $364 million, respectively, of the consolidated Trade accounts and other receivables balances.

Revenues

In 2016 and 2015, Chesapeake accounted for 14 percent and 18 percent, respectively, of our consolidated revenues.

XML

Contingent Liabilities and Commitments

12 Months Ended

Dec. 31, 2016

Commitments and Contingencies Disclosure [Abstract]

Contingent Liabilities and Commitments [Text Block]

Note 18 – Contingent Liabilities and Commitments

Reporting of Natural Gas-Related Information to Trade Publications

Direct and indirect purchasers of natural gas in various states filed an individual and class actions against us, our former affiliate WPX and its subsidiaries, and others alleging the manipulation of published gas price indices and seeking unspecified amounts of damages. Such actions were transferred to the Nevada federal district court for consolidation of discovery and pre-trial issues. We have agreed to indemnify WPX and its subsidiaries related to this matter.

In the individual action, filed by Farmland Industries Inc. (Farmland), the court issued an order on May 24, 2016, granting one of our co-defendant’s motion for summary judgment as to Farmland’s claims. On January 5, 2017, the court extended such ruling to us, entering final judgment in our favor. Farmland has appealed.

Because of the uncertainty around the remaining pending unresolved issues, including an insufficient description of the purported classes and other related matters, we cannot reasonably estimate a range of potential exposure at this time. However, it is reasonably possible that the ultimate resolution of these actions and our related indemnification obligation could result in a potential loss that may be material to our results of operations. In connection with this indemnification, we have an accrued liability balance associated with this matter, and as a result, have exposure to future developments in this matter.

Geismar Incident

On June 13, 2013, an explosion and fire occurred at our Geismar olefins plant and rendered the facility temporarily inoperable (Geismar Incident). As a result, there were two fatalities and numerous individuals (including employees and contractors) reported injuries. We are addressing the following contingent liabilities in connection with the Geismar Incident.

On October 21, 2013, the U.S. Environmental Protection Agency (EPA) issued an Inspection Report pursuant to the Clean Air Act’s Risk Management Program following its inspection of the facility on June 24 through June 28, 2013. The report notes the EPA’s preliminary determinations about the facility’s documentation regarding process safety, process hazard analysis, as well as operating procedures, employee training, and other matters. On June 16, 2014, we received a request for information related to the Geismar Incident from the EPA under Section 114 of the Clean Air Act to which we responded on August 13, 2014. The EPA could issue penalties pertaining to final determinations.

Multiple lawsuits, including class actions for alleged offsite impacts, property damage, customer claims, and personal injury, have been filed against us. To date, we have settled certain of the personal injury claims for an aggregate immaterial amount that we have recovered from our insurers. The first two trials, for nine plaintiffs claiming personal injury, were held in Louisiana state court in Iberville Parish, Louisiana in September and November 2016. The juries returned adverse verdicts against us, our subsidiary Williams Olefins, LLC, and other defendants. The defendants, including us, intend to appeal the verdicts. Trial dates for additional plaintiffs are scheduled in April 2017 and August 2017. We believe it is probable that additional losses will be incurred on some lawsuits, while for others we believe it is only reasonably possible that losses will be incurred. However, due to ongoing litigation involving defenses to liability, the number of individual plaintiffs, limited information as to the nature and extent of all plaintiffs’ damages, and the ultimate outcome of all appeals, we are unable to reliably estimate any such losses at this time. We believe that it is probable that any ultimate losses incurred will be covered by our general liability insurance policy, which has an aggregate limit of $610 million applicable to this event and retention (deductible) of $2 million per occurrence.

Alaska Refinery Contamination Litigation

In 2010, James West filed a class action lawsuit in state court in Fairbanks, Alaska on behalf of individual property owners whose water contained sulfolane contamination allegedly emanating from the Flint Hills Oil Refinery in North Pole, Alaska. The suit named our subsidiary, Williams Alaska Petroleum Inc. (WAPI), and Flint Hills Resources Alaska, LLC (FHRA), a subsidiary of Koch Industries, Inc., as defendants. We owned and operated the refinery until 2004 when we sold it to FHRA. We and FHRA made claims under the pollution liability insurance policy issued in connection with the sale of the North Pole refinery to FHRA. We and FHRA also filed claims against each other seeking, among other things, contractual indemnification alleging that the other party caused the sulfolane contamination.

In 2011, we and FHRA settled the James West claim. We and FHRA subsequently filed motions for summary judgment on the other’s claims. On July 8, 2014, the court dismissed all FHRA’s claims and entered judgment for us. On August 6, 2014, FHRA appealed the court’s decision to the Alaska Supreme Court, which heard oral arguments in October of 2015, and issued a decision on August 26, 2016. The Alaska Supreme Court affirmed dismissal of FHRA’s equitable claims and statutory claims for damages related to sulfolane located on the refinery property. The Alaska Supreme Court remanded FHRA’s claims against us for contractual indemnification and statutory claims for damages related to off-site sulfolane for further resolution by the trial court. We currently estimate that our reasonably possible loss exposure in this matter could range from an insignificant amount up to $32 million, although uncertainties inherent in the litigation process, expert evaluations, and jury dynamics might cause our exposure to exceed that amount.

On March 6, 2014, the State of Alaska filed suit against FHRA, WAPI, and us in state court in Fairbanks seeking injunctive relief and damages in connection with sulfolane contamination of the water supply near the Flint Hills Oil Refinery in North Pole, Alaska. On May 5, 2014, FHRA filed cross-claims against us in the State of Alaska suit. FHRA also seeks injunctive relief and damages.

On November 26, 2014, the City of North Pole (North Pole) filed suit in Alaska state court in Fairbanks against FHRA, WAPI, and us alleging nuisance and violations of municipal and state statutes based upon the same alleged sulfolane contamination of the water supply. North Pole claims an unspecified amount of past and future damages as well as punitive damages against WAPI. FHRA filed cross-claims against us.

In October of 2015, the court consolidated the State of Alaska and North Pole cases. On February 29, 2016, we and WAPI filed Amended Answers in the consolidated cases. Both we and WAPI asserted counter claims against both the State of Alaska and North Pole, and cross claims against FHRA. A trial is scheduled to commence May 30, 2017. All or a portion of the exposure in this consolidated State of Alaska and North Pole action may duplicate exposure in the James West case. As such, on February 9, 2017, the remanded claims in the James West case were consolidated into the State of Alaska and North Pole action. Due to the ongoing assessment of the level and extent of sulfolane contamination, the lack of an articulated cleanup level for sulfolane, and the lack of a concrete remedial proposal and cost estimate, we are unable to estimate a range of exposure for the consolidated action at this time.

Independent of the litigation matter described in the preceding paragraphs, in 2013, the Alaska Department of Environmental Conservation indicated that it views FHRA and us as responsible parties, and that it intended to enter a compliance order to address the environmental remediation of sulfolane and other possible contaminants including cleanup work outside the refinery’s boundaries. Due to the ongoing assessment of the level and extent of sulfolane contamination and the ultimate cost of remediation and division of costs among the potentially responsible parties, we are unable to estimate a range of exposure at this time.

Royalty Matters

Certain of our customers, including one major customer, have been named in various lawsuits alleging underpayment of royalties and claiming, among other things, violations of anti-trust laws and the Racketeer Influenced and Corrupt Organizations Act. We have also been named as a defendant in certain of these cases in Texas, Pennsylvania, and Ohio based on allegations that we improperly participated with that major customer in causing the alleged royalty underpayments. We have also received subpoenas from the United States Department of Justice and the Pennsylvania Attorney General requesting documents relating to the agreements between us and our major customer and calculations of the major customer’s royalty payments. On December 9, 2015, the Pennsylvania Attorney General filed a civil suit against one of our major customers and us alleging breaches of the Pennsylvania Unfair Trade Practices and Consumer Protection Law, and on February 8, 2016, the Pennsylvania Attorney General filed an amended complaint in such civil suit, which omitted us as a party. We believe that the claims asserted are subject to indemnity obligations owed to us by that major customer. Our customer and plaintiffs in the Texas cases reached a settlement, and therefore all claims asserted (or possibly asserted) by any such plaintiffs against us in the Texas cases have been fully dismissed with prejudice. On February 7, 2017, the plaintiffs in the Ohio case voluntarily dismissed the case without prejudice. Due to the preliminary status of the remaining cases, we are unable to estimate a range of potential loss at this time.

Shareholder Litigation

Between October 2015 and December 2015, purported shareholders of us filed six putative class action lawsuits in the Delaware Court of Chancery that were consolidated into a single suit on January 13, 2016. This consolidated putative class action lawsuit relates to our terminated merger with Energy Transfer Equity, L.P. (Energy Transfer). The complaint asserts various claims against the individual members of our Board of Directors, including that they breached their fiduciary duties by agreeing to sell us through an allegedly unfair process and for an allegedly unfair price and by allegedly failing to disclose allegedly material information about the merger. The complaint seeks, among other things, an injunction against the merger and an award of costs and attorneys’ fees. On March 22, 2016, the court granted the parties’ proposed order in the consolidated action to stay the proceedings pending the close of the transaction with Energy Transfer. The plaintiffs have not filed an amended complaint.

A purported shareholder filed a separate class action lawsuit in the Delaware Court of Chancery on January 15, 2016. The putative class action complaint alleged that the individual members of our Board of Directors breached their fiduciary duties by, among other things, agreeing to the WPZ Merger Agreement, which purportedly reduced the merger consideration to have been received in the subsequently proposed but now terminated merger with Energy Transfer. The plaintiff filed a motion to voluntarily dismiss, which the court granted on January 13, 2017. On September 2, 2016, the same purported shareholder filed a derivative action claiming that the members of our Board of Directors breached their fiduciary duties by executing the WPZ Merger Agreement as a defensive measure against Energy Transfer. On September 28, 2016, we requested the court dismiss this action also.

On March 7, 2016, a purported unitholder of WPZ filed a putative class action on behalf of certain purchasers of WPZ units in U.S. District Court in Oklahoma. The action names as defendants us, WPZ, Williams Partners GP LLC, Alan S. Armstrong, and Donald R. Chappel and alleges violations of certain federal securities laws for failure to disclose Energy Transfer’s intention to pursue a purchase of us conditioned on us not closing the WPZ Merger Agreement when announcing the WPZ Merger Agreement. The complaint seeks, among other things, damages and an award of costs and attorneys’ fees. The plaintiff filed an amended complaint on August 31, 2016. On October 17, 2016, we requested the court dismiss the action. We cannot reasonably estimate a range of potential loss at this time.

Litigation against Energy Transfer and related parties

On April 6, 2016, we filed suit in Delaware Chancery Court against Energy Transfer and LE GP, LLC (the general partner for Energy Transfer) alleging willful and material breaches of the Agreement and Plan of Merger (Merger Agreement) with Energy Transfer resulting from the private offering by Energy Transfer on March 8, 2016, of Series A Convertible Preferred Units (Special Offering) to certain Energy Transfer insiders and other accredited investors. The suit seeks, among other things, an injunction ordering the defendants to unwind the Special Offering and to specifically perform their obligations under the Merger Agreement. On April 19, 2016, we filed an amended complaint seeking the same relief. On May 3, 2016, Energy Transfer and LE GP, LLC filed an answer and counterclaims.

On May 13, 2016, we filed a separate complaint in Delaware Chancery Court against Energy Transfer, LE GP, LLC, and the other Energy Transfer affiliates that are parties to the Merger Agreement, alleging material breaches of the Merger Agreement for failing to cooperate and use necessary efforts to obtain a tax opinion required under the Merger Agreement (Tax Opinion) and for otherwise failing to use necessary efforts to consummate the merger under the Merger Agreement wherein we would be merged with and into the newly formed Energy Transfer Corp LP (ETC) (ETC Merger). The suit sought, among other things, a declaratory judgment and injunction preventing Energy Transfer from terminating or otherwise avoiding its obligations under the Merger Agreement due to any failure to obtain the Tax Opinion.

The Court of Chancery coordinated the Special Offering and Tax Opinion suits. On May 20, 2016, the Energy Transfer defendants filed amended affirmative defenses and verified counterclaims in the Special Offering and Tax Opinion suits, alleging certain breaches of the Merger Agreement by us and seeking, among other things, a declaration that we were not entitled to specific performance, that Energy Transfer could terminate the ETC Merger, and that Energy Transfer is entitled to a $1.48 billion termination fee. On June 24, 2016, following a two-day trial, the court issued a Memorandum Opinion and Order denying our requested relief in the Tax Opinion suit. The court did not rule on the substance of our claims related to the Special Offering or on the substance of Energy Transfer’s counterclaims. On June 27, 2016, we filed an appeal of the court’s decision with the Supreme Court of Delaware, seeking reversal and remand to pursue damages. The appeal has been fully briefed for consideration by the Supreme Court of Delaware, and oral argument occurred on January 11, 2017.

On September 16, 2016, we filed an amended complaint with the Court of Chancery seeking damages for breaches of the Merger Agreement by defendants.  On September 23, 2016, Energy Transfer filed a second amended and supplemental affirmative defenses and verified counterclaim with the Court of Chancery seeking, among other things, payment of the $1.48 billion termination fee due to our alleged breaches of the Merger Agreement. We filed a motion to dismiss Energy Transfer’s counterclaims, which was fully briefed on November 14, 2016, and oral argument occurred on November 30, 2016.

Environmental Matters

We are a participant in certain environmental activities in various stages including assessment studies, cleanup operations, and remedial processes at certain sites, some of which we currently do not own. We are monitoring these sites in a coordinated effort with other potentially responsible parties, the EPA, and other governmental authorities. We are jointly and severally liable along with unrelated third parties in some of these activities and solely responsible in others. Certain of our subsidiaries have been identified as potentially responsible parties at various Superfund and state waste disposal sites. In addition, these subsidiaries have incurred, or are alleged to have incurred, various other hazardous materials removal or remediation obligations under environmental laws. As of December 31, 2016, we have accrued liabilities totaling $38 million for these matters, as discussed below. Our accrual reflects the most likely costs of cleanup, which are generally based on completed assessment studies, preliminary results of studies, or our experience with other similar cleanup operations. Certain assessment studies are still in process for which the ultimate outcome may yield significantly different estimates of most likely costs. Any incremental amount in excess of amounts currently accrued cannot be reasonably estimated at this time due to uncertainty about the actual number of contaminated sites ultimately identified, the actual amount and extent of contamination discovered, and the final cleanup standards mandated by the EPA and other governmental authorities.

The EPA and various state regulatory agencies routinely promulgate and propose new rules, and issue updated guidance to existing rules. More recent rules and rulemakings include, but are not limited to, rules for reciprocating internal combustion engine maximum achievable control technology, new air quality standards for one hour nitrogen dioxide emissions, and volatile organic compound and methane new source performance standards impacting design and operation of storage vessels, pressure valves, and compressors. On October 1, 2015, the EPA issued its new rule regarding National Ambient Air Quality Standards for ground-level ozone, setting a new standard of 70 parts per billion. We are monitoring the rule’s implementation and evaluating potential impacts to our operations. For these and other new regulations, we are unable to estimate the costs of asset additions or modifications necessary to comply due to uncertainty created by the various legal challenges to these regulations and the need for further specific regulatory guidance.

Continuing operations

Our interstate gas pipelines are involved in remediation activities related to certain facilities and locations for polychlorinated biphenyls, mercury, and other hazardous substances. These activities have involved the EPA and various state environmental authorities, resulting in our identification as a potentially responsible party at various Superfund waste sites. At December 31, 2016, we have accrued liabilities of $9 million for these costs. We expect that these costs will be recoverable through rates.

We also accrue environmental remediation costs for natural gas underground storage facilities, primarily related to soil and groundwater contamination. At December 31, 2016, we have accrued liabilities totaling $7 million for these costs.

Former operations, including operations classified as discontinued

We have potential obligations in connection with assets and businesses we no longer operate. These potential obligations include remediation activities at the direction of federal and state environmental authorities and the indemnification of the purchasers of certain of these assets and businesses for environmental and other liabilities existing at the time the sale was consummated. Our responsibilities relate to the operations of the assets and businesses described below.

• Former agricultural fertilizer and chemical operations and former retail petroleum and refining operations;

• Former petroleum products and natural gas pipelines;

• Former petroleum refining facilities;

• Former exploration and production and mining operations;

• Former electricity and natural gas marketing and trading operations.

At December 31, 2016, we have accrued environmental liabilities of $22 million related to these matters.

Other Divestiture Indemnifications

Pursuant to various purchase and sale agreements relating to divested businesses and assets, we have indemnified certain purchasers against liabilities that they may incur with respect to the businesses and assets acquired from us. The indemnities provided to the purchasers are customary in sale transactions and are contingent upon the purchasers incurring liabilities that are not otherwise recoverable from third parties. The indemnities generally relate to breach of warranties, tax, historic litigation, personal injury, property damage, environmental matters, right of way, and other representations that we have provided.

At December 31, 2016, other than as previously disclosed, we are not aware of any material claims against us involving the indemnities; thus, we do not expect any of the indemnities provided pursuant to the sales agreements to have a material impact on our future financial position. Any claim for indemnity brought against us in the future may have a material adverse effect on our results of operations in the period in which the claim is made.

In addition to the foregoing, various other proceedings are pending against us which are incidental to our operations.

Summary

We have disclosed our estimated range of reasonably possible losses for certain matters above, as well as all significant matters for which we are unable to reasonably estimate a range of possible loss. We estimate that for all other matters for which we are able to reasonably estimate a range of loss, our aggregate reasonably possible losses beyond amounts accrued are immaterial to our expected future annual results of operations, liquidity, and financial position. These calculations have been made without consideration of any potential recovery from third parties.

Commitments

Commitments for construction and acquisition of property, plant, and equipment are approximately $244 million at December 31, 2016.

XML

Segment Disclosures

12 Months Ended

Dec. 31, 2016

Segment Reporting [Abstract]

Segment Disclosures [Text Block]

Note 19 – Segment Disclosures

Our reportable segments are Williams Partners and Williams NGL & Petchem Services. All remaining business activities are included in Other. (See Note 1 – General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies.)

Our segment presentation of Williams Partners, which includes our consolidated master limited partnership, is reflective of the parent-level focus by our chief operating decision-maker, considering the resource allocation and governance provisions associated with the master limited partnership structure. This partnership maintains capital and cash management structures that are separate from ours. It is self-funding and maintains its own lines of bank credit and cash management accounts. These factors, coupled with different costs of capital from our other businesses, serve to differentiate the management of this entity as a whole.

Performance Measurement

We evaluate segment operating performance based upon Modified EBITDA (earnings before interest, taxes, depreciation, and amortization). This measure represents the basis of our internal financial reporting and is the primary performance measure used by our chief operating decision maker in measuring performance and allocating resources among our reportable segments.

We define Modified EBITDA as follows:

•Net income (loss) before:

◦Income (loss) from discontinued operations;

◦Provision (benefit) for income taxes;

◦Interest incurred, net of interest capitalized;

◦Equity earnings (losses);

◦Gain on remeasurement of equity-method investment;

◦Impairment of equity-method investments;

◦Other investing income (loss) – net;

◦Impairment of goodwill;

◦Depreciation and amortization expenses;

◦Accretion expense associated with asset retirement obligations for nonregulated operations.

• This measure is further adjusted to include our proportionate share (based on ownership interest) of Modified EBITDA from our equity-method investments calculated consistently with the definition described above.

The following geographic area data includes Revenues from external customers based on product shipment origin and Long-lived assets based upon physical location:

		United States		Canada		Total
		(Millions)
Revenues from external customers:
	2016	$	7,425	$	74	$	7,499
	2015	7,247		113		7,360
	2014	7,229		408		7,637
Long-lived assets:
	2016	$	38,091	$	—	$	38,091
	2015	38,016		1,580		39,596
	2014	38,290		1,364		39,654

Long-lived assets are comprised of property, plant, and equipment, goodwill, and other intangible assets.

The following table reflects the reconciliation of Segment revenues to Total revenues as reported in the Consolidated Statement of Operations and Other financial information:

	Williams Partners		Williams NGL & Petchem Services			Other		Eliminations			Total
	(Millions)
2016
Segment revenues:
Service revenues
External	$	5,140	$	2		$	29	$	—		$	5,171
Internal	33		—			19		(52		)	—
Total service revenues	5,173		2			48		(52		)	5,171
Product sales
External	2,318		10			—		—			2,328
Internal	—		16			—		(16		)	—
Total product sales	2,318		26			—		(16		)	2,328
Total revenues	$	7,491	$	28		$	48	$	(68	)	$	7,499
Other financial information:
Additions to long-lived assets	$	2,102	$	33		$	11	$	(1	)	$	2,145
Proportional Modified EBITDA of equity-method investments	754		—			—		—			754
2015
Segment revenues:
Service revenues
External	$	5,134	$	2		$	28	$	—		$	5,164
Internal	1		—			158		(159		)	—
Total service revenues	5,135		2			186		(159		)	5,164
Product sales
External	2,196		—			—		—			2,196
Internal	—		—			—		—			—
Total product sales	2,196		—			—		—			2,196
Total revenues	$	7,331	$	2		$	186	$	(159	)	$	7,360
Other financial information:
Additions to long-lived assets	$	2,960	$	360		$	28	$	(12	)	$	3,336
Proportional Modified EBITDA of equity-method investments	699		—			—		—			699
2014
Segment revenues:
Service revenues
External	$	3,887	$	—		$	229	$	—		$	4,116
Internal	1		—			30		(31		)	—
Total service revenues	3,888		—			259		(31		)	4,116
Product sales
External	3,521		—			—		—			3,521
Internal	—		—			—		—			—
Total product sales	3,521		—			—		—			3,521
Total revenues	$	7,409	$	—		$	259	$	(31	)	$	7,637
Other financial information:
Additions to long-lived assets (1)	$	20,413	$	291		$	54	$	(2	)	$	20,756
Proportional Modified EBITDA of equity-method investments	431		(78		)	85		—			438

_______________

(1) 2014 Additions to long-lived assets within our Williams Partners segment primarily includes the acquisition-date fair value of long-lived assets from the ACMP Acquisition. (See Note 2 - Acquisitions.)

The following table reflects the reconciliation of Modified EBITDA to Net income (loss) as reported in the Consolidated Statement of Operations:

	Years Ended December 31,
	2016			2015			2014
	(Millions)
Modified EBITDA by segment:
Williams Partners	$	3,864		$	4,003		$	3,244
Williams NGL & Petchem Services	(540		)	(83		)	(115		)
Other	(2		)	(29		)	103
	3,322			3,891			3,232
Accretion expense associated with asset retirement obligations for nonregulated operations	(31		)	(28		)	(18		)
Depreciation and amortization expenses	(1,763		)	(1,738		)	(1,176		)
Impairment of goodwill	—			(1,098		)	—
Equity earnings (losses)	397			335			144
Gain on remeasurement of equity-method investment	—			—			2,544
Impairment of equity-method investments	(430		)	(1,359		)	—
Other investing income (loss) – net	63			27			43
Proportional Modified EBITDA of equity-method investments	(754		)	(699		)	(438		)
Interest expense	(1,179		)	(1,044		)	(747		)
(Provision) benefit for income taxes	25			399			(1,249		)
Income (loss) from discontinued operations, net of tax	—			—			4
Net income (loss)	$	(350	)	$	(1,314	)	$	2,339

The following table reflects Total assets and Equity-method investments by reportable segments:

	Total Assets						Equity-Method Investments
	December 31, 2016			December 31, 2015			December 31, 2016		December 31, 2015
	(Millions)
Williams Partners	$	46,265		$	47,870		$	6,701	$	7,336
Williams NGL & Petchem Services	249			835			—		—
Other	674			850			—		—
Eliminations	(353		)	(535		)	—		—
Total	$	46,835		$	49,020		$	6,701	$	7,336

XML

Schedule I Condensed Financial Information Of Registrant

12 Months Ended

Dec. 31, 2016

Condensed Financial Information of Parent Company Only Disclosure [Abstract]

Condensed Financial Information of Parent Company Only Disclosure [Text Block]

The Williams Companies, Inc.

Schedule I — Condensed Financial Information of Registrant

Statement of Comprehensive Income (Loss) (Parent)

	Years Ended December 31,
	2016			2015			2014
	(Millions, except per-share amounts)
Equity in earnings of consolidated subsidiaries	$	522		$	232		$	1,799
Equity earnings (losses) from investment in Access Midstream Partners	—			—			(7		)
Interest incurred — external	(268		)	(255		)	(206		)
Interest incurred — affiliate	(568		)	(828		)	(797		)
Interest income — affiliate	—			6			10
Gain on remeasurement of equity-method investment	—			—			2,544
Other income (expense) — net	(53		)	(75		)	(13		)
Income (loss) from continuing operations before income taxes	(367		)	(920		)	3,330
Provision (benefit) for income taxes	57			(349		)	1,220
Income (loss) from continuing operations	(424		)	(571		)	2,110
Income (loss) from discontinued operations	—			—			4
Net income (loss)	$	(424	)	$	(571	)	$	2,114
Basic earnings (loss) per common share:
Income (loss) from continuing operations	$	(.57	)	$	(.76	)	$	2.93
Income (loss) from discontinued operations	—			—			.01
Net income (loss)	$	(.57	)	$	(.76	)	$	2.94
Weighted-average shares (thousands)	750,673			749,271			719,325
Diluted earnings (loss) per common share:
Income (loss) from continuing operations	$	(.57	)	$	(.76	)	$	2.91
Income (loss) from discontinued operations	—			—			.01
Net income (loss)	$	(.57	)	$	(.76	)	$	2.92
Weighted-average shares (thousands)	750,673			749,271			723,641
Other comprehensive income (loss):
Equity in other comprehensive income (loss) of consolidated subsidiaries	$	171		$	(204	)	$	(96	)
Other comprehensive income (loss) attributable to The Williams Companies, Inc.	1			33			(80		)
Other comprehensive income (loss)	172			(171		)	(176		)
Less: Other comprehensive income (loss) attributable to noncontrolling interests	69			(70		)	(19		)
Comprehensive income (loss) attributable to The Williams Companies, Inc.	$	(321	)	$	(672	)	$	1,957

See accompanying notes.

The Williams Companies, Inc.

Schedule I — Condensed Financial Information of Registrant – (Continued)

Balance Sheet (Parent)

	December 31,
	2016		2015
	(Millions)
ASSETS
Current assets:
Cash and cash equivalents	$	14	$	12
Other current assets and deferred charges	16		62
Total current assets	30		74
Investments in and advances to consolidated subsidiaries	22,359		30,927
Property, plant, and equipment — net	77		99
Other noncurrent assets	8		12
Total assets	$	22,474	$	31,112
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	27	$	27
Other current liabilities	169		163
Total current liabilities	196		190
Long-term debt	4,939		4,811
Notes payable — affiliates	8,171		15,506
Pension, other postretirement, and other noncurrent liabilities	287		336
Deferred income tax liabilities	4,238		4,121
Contingent liabilities and commitments
Equity:
Common stock	785		784
Other stockholders’ equity	3,858		5,364
Total stockholders’ equity	4,643		6,148
Total liabilities and stockholders’ equity	$	22,474	$	31,112

See accompanying notes.

The Williams Companies, Inc.

Schedule I — Condensed Financial Information of Registrant – (Continued)

Statement of Cash Flows (Parent)

	Years Ended December 31,
	2016			2015			2014
	(Millions)
NET CASH FLOWS PROVIDED (USED) BY OPERATING ACTIVITIES	$	(833	)	$	(1,209	)	$	(500	)
FINANCING ACTIVITIES:
Proceeds from long-term debt	2,280			2,097			2,935
Payments of long-term debt	(2,155		)	(1,817		)	(671		)
Changes in notes payable to affiliates	9			2,211			2,465
Tax benefit of stock-based awards	—			—			25
Proceeds from issuance of common stock	9			27			3,416
Dividends paid	(1,261		)	(1,836		)	(1,412		)
Other — net	—			(2		)	(17		)
Net cash provided (used) by financing activities	(1,118		)	680			6,741
INVESTING ACTIVITIES:
Capital expenditures	(13		)	(29		)	(54		)
Purchase of Access Midstream Partners	—			—			(5,995		)
Changes in investments in and advances to consolidated subsidiaries	1,966			521			(450		)
Other — net	—			—			25
Net cash provided (used) by investing activities	1,953			492			(6,474		)
Increase (decrease) in cash and cash equivalents	2			(37		)	(233		)
Cash and cash equivalents at beginning of year	12			49			282
Cash and cash equivalents at end of year	$	14		$	12		$	49

See accompanying notes.

Note 1. Guarantees

In addition to the guarantees disclosed in the accompanying consolidated financial statements in Item 8, we have financially guaranteed the performance of certain consolidated subsidiaries. The duration of these guarantees varies, and we estimate the maximum undiscounted potential future payment obligation related to these guarantees as of December 31, 2016, is approximately $305 million.

Note 2. Cash Dividends Received

We receive dividends and distributions either directly from our subsidiaries or indirectly through dividends received by subsidiaries and subsequent transfers of cash to us through our corporate cash management system. The total of such receipts ultimately related to dividends and distributions for the years ended December 31, 2016, 2015, and 2014 was approximately $1.7 billion, $1.8 billion, and $1.9 billion, respectively.

XML

Schedule II Valuation and Qualifying Accounts

12 Months Ended

Dec. 31, 2016

Valuation and Qualifying Accounts [Abstract]

Schedule II Valuation and Qualifying Accounts [Text Block]

The Williams Companies, Inc.

Schedule II — Valuation and Qualifying Accounts

			Additions
	Beginning Balance		Charged (Credited) To Costs and Expenses			Other		Deductions		Ending Balance
	(Millions)
2016
Allowance for doubtful accounts — accounts and notes receivable (1)	$	3	$	6		$	—	$	3	$	6
Deferred tax asset valuation allowance (1)	190		144			—		—		334
2015
Allowance for doubtful accounts — accounts and notes receivable (1)	—		3			—		—		3
Deferred tax asset valuation allowance (1)	206		(16		)	—		—		190
2014
Allowance for doubtful accounts — accounts and notes receivable (1)	—		—			—		—		—
Deferred tax asset valuation allowance (1)	181		25			—		—		206

__________

(1)    Deducted from related assets.

XML

General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2016

Accounting Policies [Abstract]

Principles of consolidation [Policy Text Block]

Principles of consolidation

The consolidated financial statements include the accounts of all entities that we control and our proportionate interest in the accounts of certain ventures in which we own an undivided interest. Management’s judgment is required to evaluate whether we control an entity. Key areas of that evaluation include:

• Determining whether an entity is a VIE;

• Determining whether we are the primary beneficiary of a VIE, including evaluating which activities of the VIE most significantly impact its economic performance and the degree of power that we and our related parties have over those activities through our variable interests;

• Identifying events that require reconsideration of whether an entity is a VIE and continuously evaluating whether we are a VIE’s primary beneficiary;

• Evaluating whether other owners in entities that are not VIEs are able to effectively participate in significant decisions that would be expected to be made in the ordinary course of business such that we do not have the power to control such entities.

We apply the equity method of accounting to investments over which we exercise significant influence but do not control.

Equity-method investment basis differences [Policy Text Block]

Equity-method investment basis differences

Differences between the cost of our equity-method investments and our underlying equity in the net assets of investees are accounted for as if the investees were consolidated subsidiaries. Equity earnings (losses) in the Consolidated Statement of Operations includes our allocable share of net income (loss) of investees adjusted for any depreciation and amortization, as applicable, associated with basis differences.

Use of estimates [Policy Text Block]

Use of estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual results could differ from those estimates.

Significant estimates and assumptions include:

• Impairment assessments of investments, property, plant, and equipment, goodwill, and other identifiable intangible assets;

• Litigation-related contingencies;

• Environmental remediation obligations;

• Realization of deferred income tax assets;

• Depreciation and/or amortization of equity-method investment basis differences;

• Asset retirement obligations;

• Pension and postretirement valuation variables;

• Acquisition related purchase price allocations.

These estimates are discussed further throughout these notes.

Regulatory Accounting [Policy Text Block]

Regulatory accounting

Transco and Northwest Pipeline are regulated by the Federal Energy Regulatory Commission (FERC). Their rates, which are established by the FERC, are designed to recover the costs of providing the regulated services, and their competitive environment makes it probable that such rates can be charged and collected. Therefore, our management has determined that it is appropriate under Accounting Standards Codification (ASC) Topic 980, “Regulated Operations,” to account for and report regulatory assets and liabilities related to these operations consistent with the economic effect of the way in which their rates are established. Accounting for these operations that are regulated can differ from the accounting requirements for nonregulated operations. For example, for regulated operations, allowance for funds used during construction (AFUDC) represents the estimated cost of debt and equity funds applicable to utility plant in process of construction and is capitalized as a cost of property, plant, and equipment because it constitutes an actual cost of construction under established regulatory practices; nonregulated operations are only allowed to capitalize the cost of debt funds related to construction activities, while a component for equity is prohibited. The components of our regulatory assets and liabilities relate to the effects of deferred taxes on equity funds used during construction, asset retirement obligations, fuel cost differentials, levelized incremental depreciation, negative salvage, and pension and other postretirement benefits. Our current and noncurrent regulatory asset and liability balances for the years ended December 31, 2016 and 2015 are as follows:

	December 31,
	2016		2015
	(Millions)
Current assets reported within Other current assets and deferred charges	$	91	$	84
Noncurrent assets reported within Regulatory assets, deferred charges, and other	387		370
Total regulated assets	$	478	$	454
Current liabilities reported within Accrued liabilities	$	11	$	4
Noncurrent liabilities reported within Regulatory liabilities, deferred income, and other	498		434
Total regulated liabilities	$	509	$	438

Cash and cash equivalents [Policy Text Block]

Cash and cash equivalents

Cash and cash equivalents in the Consolidated Balance Sheet includes amounts primarily invested in funds with high-quality, short-term securities and instruments that are issued or guaranteed by the U.S. government. These have maturity dates of three months or less when acquired.

Accounts receivable [Policy Text Block]

Accounts receivable

Accounts receivable are carried on a gross basis, with no discounting, less an allowance for doubtful accounts. We estimate the allowance for doubtful accounts based on existing economic conditions, the financial condition of our customers, and the amount and age of past due accounts. We consider receivables past due if full payment is not received by the contractual due date. Interest income related to past due accounts receivable is generally recognized at the time full payment is received or collectability is assured. Past due accounts are generally written off against the allowance for doubtful accounts only after all collection attempts have been exhausted.

Inventories [Policy Text Block]

Inventories

Inventories in the Consolidated Balance Sheet primarily consist of natural gas liquids, olefins, natural gas in underground storage, and materials and supplies and are stated at the lower of cost or market. The cost of inventories is primarily determined using the average-cost method.

Property, plant, and equipment [Policy Text Block]

Property, plant, and equipment

Property, plant, and equipment is recorded at cost. We base the carrying value of these assets on estimates, assumptions, and judgments relative to capitalized costs, useful lives, and salvage values.

As regulated entities, Northwest Pipeline and Transco provide for depreciation using the straight-line method at FERC-prescribed rates. Depreciation for nonregulated entities is provided primarily on the straight-line method over estimated useful lives, except for certain offshore facilities that apply an accelerated depreciation method.

Gains or losses from the ordinary sale or retirement of property, plant, and equipment for regulated pipelines are credited or charged to accumulated depreciation. Other gains or losses are recorded in Other (income) expense – net included in Operating income (loss) in the Consolidated Statement of Operations.

Ordinary maintenance and repair costs are generally expensed as incurred. Costs of major renewals and replacements are capitalized as property, plant, and equipment.

We record a liability and increase the basis in the underlying asset for the present value of each expected future asset retirement obligation (ARO) at the time the liability is initially incurred, typically when the asset is acquired or constructed. As regulated entities, Northwest Pipeline and Transco offset the depreciation of the underlying asset that is attributable to capitalized ARO cost to a regulatory asset as management expects to recover these amounts in future rates. We measure changes in the liability due to passage of time by applying an interest rate to the liability balance. This amount is recognized as an increase in the carrying amount of the liability and as a corresponding accretion expense included in Operating and maintenance expenses in the Consolidated Statement of Operations, except for regulated entities, for which the liability is offset by a regulatory asset. The regulatory asset is amortized commensurate with our collection of those costs in rates.

Measurements of AROs include, as a component of future expected costs, an estimate of the price that a third party would demand, and could expect to receive, for bearing the uncertainties inherent in the obligations, sometimes referred to as a market-risk premium.

Goodwill [Policy Text Block]

Goodwill

Goodwill included within Intangible assets – net of accumulated amortization in the Consolidated Balance Sheet represents the excess of the consideration, plus the fair value of any noncontrolling interest or any previously held equity interest, over the fair value of the net assets acquired. It is not subject to amortization but is evaluated annually as of October 1 for impairment or more frequently if impairment indicators are present that would indicate it is more likely than not that the fair value of the reporting unit is less than its carrying amount. As part of the evaluation, we compare our estimate of the fair value of the reporting unit with its carrying value, including goodwill. If the carrying value of the reporting unit exceeds its fair value, a computation of the implied fair value of the goodwill is compared with its related carrying value. If the carrying value of the reporting unit goodwill exceeds the implied fair value of that goodwill, an impairment loss is recognized in the amount of the excess. Judgments and assumptions are inherent in our management’s estimates of fair value.

Other intangibles assets [Policy Text Block]

Other intangible assets

Our identifiable intangible assets included within Intangible assets – net of accumulated amortization in the Consolidated Balance Sheet are primarily related to gas gathering, processing, and fractionation contractual customer relationships. Our intangible assets are amortized on a straight-line basis over the period in which these assets contribute to our cash flows. We evaluate these assets for changes in the expected remaining useful lives and would reflect any changes prospectively through amortization over the revised remaining useful life.

Impairment of property, plant, and equipment, other identifiable intangible assets, and investments [Policy Text Block]

Impairment of property, plant, and equipment, other identifiable intangible assets, and investments

We evaluate our property, plant, and equipment and other identifiable intangible assets for impairment when events or changes in circumstances indicate, in our management’s judgment, that the carrying value of such assets may not be recoverable. When an indicator of impairment has occurred, we compare our management’s estimate of undiscounted future cash flows attributable to the assets to the carrying value of the assets to determine whether an impairment has occurred and we may apply a probability-weighted approach to consider the likelihood of different cash flow assumptions and possible outcomes including selling in the near term or holding for the remaining estimated useful life. If an impairment of the carrying value has occurred, we determine the amount of the impairment recognized in the financial statements by estimating the fair value of the assets and recording a loss for the amount that the carrying value exceeds the estimated fair value. This evaluation is performed at the lowest level for which separately identifiable cash flows exist.

For assets identified to be disposed of in the future and considered held for sale, we compare the carrying value to the estimated fair value less the cost to sell to determine if recognition of an impairment is required. Until the assets are disposed of, the estimated fair value, which includes estimated cash flows from operations until the assumed date of sale, is recalculated when related events or circumstances change.

We evaluate our investments for impairment when events or changes in circumstances indicate, in our management’s judgment, that the carrying value of such investments may have experienced an other-than-temporary decline in value. When evidence of loss in value has occurred, we compare our estimate of fair value of the investment to the carrying value of the investment to determine whether an impairment has occurred. If the estimated fair value is less than the carrying value and we consider the decline in value to be other-than-temporary, the excess of the carrying value over the fair value is recognized in the consolidated financial statements as an impairment charge.

Judgments and assumptions are inherent in our management’s estimate of undiscounted future cash flows and an asset’s or investment’s fair value. Additionally, judgment is used to determine the probability of sale with respect to assets considered for disposal.

Deferred income [Policy Text Block]

Deferred income

We record a liability for deferred income related to cash received from customers in advance of providing our services.  Such amounts are generally recognized in revenue upon satisfying our performance obligations, primarily providing services based on units of production or over remaining contractual service periods ranging from 1 to 25 years.  Deferred incomeis reflected within Accrued liabilitiesand Regulatory liabilities, deferred income, and otheron the Consolidated Balance Sheet.  (See Note 13 – Accrued Liabilities.) 

During 2016, we received cash proceeds totaling $820 million associated with restructuring certain gas gathering contracts in the Barnett Shale and Mid-Continent regions. The proceeds were recorded as deferred incomeand are being amortized into income in 2016 and future periods.

In October 2016, we received $104 million of newly constructed assets as part of a noncash investing transaction with a customer for which we provide production handling and other services. The transaction was recorded in Property, plant, and equipment – net and deferred income in the Consolidated Balance Sheet and is being amortized based on units of production through 2024. Due to the noncash nature of this transaction, it is not presented within the Consolidated Statement of Cash Flows.

Contingent liabilities [Policy Text Block]

Contingent liabilities

We record liabilities for estimated loss contingencies, including environmental matters, when we assess that a loss is probable and the amount of the loss can be reasonably estimated. These liabilities are calculated based upon our assumptions and estimates with respect to the likelihood or amount of loss and upon advice of legal counsel, engineers, or other third parties regarding the probable outcomes of the matters. These calculations are made without consideration of any potential recovery from third parties. We recognize insurance recoveries or reimbursements from others when realizable. Revisions to these liabilities are generally reflected in income when new or different facts or information become known or circumstances change that affect the previous assumptions or estimates.

Cash flows from revolving credit facilities and commercial paper program [Policy Text Block]

Cash flows from revolving credit facilities and commercial paper program

Proceeds and payments related to borrowings under our credit facilities are reflected in the financing activities in the Consolidated Statement of Cash Flows on a gross basis. Proceeds and payments related to borrowings under our commercial paper program are reflected in the financing activities in the Consolidated Statement of Cash Flows on a net basis, as the outstanding notes generally have maturity dates less than three months from the date of issuance. (See Note 14 – Debt, Banking Arrangements, and Leases.)

Treasury stock [Policy Text Block]

Treasury stock

Treasury stock purchases are accounted for under the cost method whereby the entire cost of the acquired stock is recorded as Treasury stock in the Consolidated Balance Sheet. Gains and losses on the subsequent reissuance of shares are credited or charged to Capital in excess of par value in the Consolidated Balance Sheet using the average-cost method.

Derivative instruments and hedging activities [Policy Text Block]

Derivative instruments and hedging activities

We may utilize derivatives to manage a portion of our commodity price risk. These instruments consist primarily of swaps, futures, and forward contracts involving short- and long-term purchases and sales of energy commodities. We report the fair value of derivatives, except those for which the normal purchases and normal sales exception has been elected, in Other current assets and deferred charges; Regulatory assets, deferred charges, and other;Accrued liabilities; or Regulatory liabilities, deferred income, and other in the Consolidated Balance Sheet. We determine the current and noncurrent classification based on the timing of expected future cash flows of individual trades. We report these amounts on a gross basis. Additionally, we report cash collateral receivables and payables with our counterparties on a gross basis. (See Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk.)

The accounting for the changes in fair value of a commodity derivative can be summarized as follows:

Derivative Treatment	Accounting Method
Normal purchases and normal sales exception	Accrual accounting
Designated in a qualifying hedging relationship	Hedge accounting
All other derivatives	Mark-to-market accounting

We may elect the normal purchases and normal sales exception for certain short- and long-term purchases and sales of physical energy commodities. Under accrual accounting, any change in the fair value of these derivatives is not reflected on the balance sheet after the initial election of the exception.

We may also designate a hedging relationship for certain commodity derivatives. For a derivative to qualify for designation in a hedging relationship, it must meet specific criteria and we must maintain appropriate documentation. We establish hedging relationships pursuant to our risk management policies. We evaluate the hedging relationships at the inception of the hedge and on an ongoing basis to determine whether the hedging relationship is, and is expected to remain, highly effective in achieving offsetting changes in fair value or cash flows attributable to the underlying risk being hedged. We also regularly assess whether the hedged forecasted transaction is probable of occurring. If a derivative ceases to be or is no longer expected to be highly effective, or if we believe the likelihood of occurrence of the hedged forecasted transaction is no longer probable, hedge accounting is discontinued prospectively, and future changes in the fair value of the derivative are recognized currently in Product sales or Product costsin the Consolidated Statement of Operations.

For commodity derivatives designated as a cash flow hedge, the effective portion of the change in fair value of the derivative is reported in Accumulated other comprehensive income (loss) (AOCI) in the Consolidated Balance Sheet and reclassified into earnings in the period in which the hedged item affects earnings. Any ineffective portion of the derivative’s change in fair value is recognized currently in Product sales or Product costs in the Consolidated Statement of Operations. Gains or losses deferred in AOCI associated with terminated derivatives, derivatives that cease to be highly effective hedges, derivatives for which the forecasted transaction is reasonably possible but no longer probable of occurring, and cash flow hedges that have been otherwise discontinued remain in AOCI until the hedged item affects earnings. If it becomes probable that the forecasted transaction designated as the hedged item in a cash flow hedge will not occur, any gain or loss deferred in AOCI is recognized in Product sales or Product costs in the Consolidated Statement of Operations at that time. The change in likelihood of a forecasted transaction is a judgmental decision that includes qualitative assessments made by management.

For commodity derivatives that are not designated in a hedging relationship, and for which we have not elected the normal purchases and normal sales exception, we report changes in fair value currently in Product salesorProduct costsin the Consolidated Statement of Operations.

Certain gains and losses on derivative instruments included in the Consolidated Statement of Operations are netted together to a single net gain or loss, while other gains and losses are reported on a gross basis. Gains and losses recorded on a net basis include unrealized gains and losses on all derivatives that are not designated as hedges and for which we have not elected the normal purchases and normal sales exception.

Realized gains and losses on derivatives that require physical delivery, as well as natural gas derivatives for NGL processing activities and which are not held for trading purposes nor were entered into as a pre-contemplated buy/sell arrangement, are recorded on a gross basis.

Revenue recognition [Policy Text Block]

Revenue recognition

Revenues

As a result of the ratemaking process, certain revenues collected by us may be subject to refunds upon the issuance of final orders by the FERC in pending rate proceedings. We record estimates of rate refund liabilities considering our and other third-party regulatory proceedings, advice of counsel, and other risks.

Service revenues

Revenues from our interstate natural gas pipeline businesses include services pursuant to long-term firm transportation and storage agreements. These agreements provide for a reservation charge based on the volume of contracted capacity and a commodity charge based on the volume of gas delivered, both at rates specified in our FERC tariffs. We recognize revenues for reservation charges ratably over the contract period regardless of the volume of natural gas that is transported or stored. Revenues for commodity charges, from both firm and interruptible transportation services and storage injection and withdrawal services, are recognized when natural gas is delivered at the agreed upon delivery point or when natural gas is injected or withdrawn from the storage facility.

Certain revenues from our midstream operations include those derived from natural gas gathering, processing, treating, and compression services and are performed under volumetric-based fee contracts. These revenues are recorded when services have been performed.

Certain of our gas gathering and processing agreements have minimum volume commitments. If a customer under such an agreement fails to meet its minimum volume commitment for a specified period, generally measured on an annual basis, it is obligated to pay a contractually determined fee based upon the shortfall between actual production volumes and the minimum volume commitment for that period. The revenue associated with minimum volume commitments is recognized in the period that the actual shortfall is determined and is no longer subject to future reduction or offset, which is generally at the end of the annual period or fourth quarter.

Crude oil gathering and transportation revenues and offshore production handling fees are recognized when the services have been performed. Certain offshore production handling contracts contain fixed payment terms that result in the deferral of revenues until such services have been performed or such capacity has been made available.

Storage revenues from our midstream operations associated with prepaid contracted storage capacity contracts are recognized on a straight-line basis over the life of the contract as services are provided.

Product sales

In the course of providing transportation services to customers of our interstate natural gas pipeline businesses, we may receive different quantities of gas from shippers than the quantities delivered on behalf of those shippers. The resulting imbalances are primarily settled through the purchase and sale of gas with our customers under terms provided for in our FERC tariffs. Revenue is recognized from the sale of gas upon settlement of the transportation and exchange imbalances.

We market NGLs, crude oil, natural gas, and olefins that we purchase from our producer customers as part of the overall service provided to producers. Revenues from marketing NGLs are recognized when the products have been sold and delivered.

Under our keep-whole and percent-of-liquids processing contracts, we retain the rights to all or a portion of the NGLs extracted from the producers’ natural gas stream and recognize revenues when the extracted NGLs are sold and delivered.

Our domestic olefins business produces olefins from purchased or produced feedstock and we recognize revenues when the olefins are sold and delivered.

Our Canadian businesses that were sold in September 2016 had processing and fractionation operations where we retained certain NGLs and olefins from an upgrader’s offgas stream and we recognized revenues when the fractionated products were sold and delivered.

Interest capitalized [Policy Text Block]

Interest capitalized

We capitalize interest during construction on major projects with construction periods of at least 3 months and a total project cost in excess of $1 million. Interest is capitalized on borrowed funds and, where regulation by the FERC exists, on internally generated funds (equity AFUDC). The latter is included in Other income (expense) – net below Operating income (loss) in the Consolidated Statement of Operations. The rates used by regulated companies are calculated in accordance with FERC rules. Rates used by nonregulated companies are based on our average interest rate on debt.

Employee stock-based awards [Policy Text Block]

Employee stock-based awards

We recognize compensation expense on employee stock-based awards, net of estimated forfeitures, on a straight-line basis. (See Note 16 – Equity-Based Compensation.)

Pension and other postretirement benefits [Policy Text Block]

Pension and other postretirement benefits

The funded status of each of the pension and other postretirement benefit plans is recognized separately in the Consolidated Balance Sheet as either an asset or liability. The funded status is the difference between the fair value of plan assets and the plan’s benefit obligation. The plans’ benefit obligations and net periodic benefit costs are actuarially determined and impacted by various assumptions and estimates. (See Note 10 – Employee Benefit Plans.)

The discount rates are determined separately for each of our pension and other postretirement benefit plans based on an approach specific to our plans. The year-end discount rates are determined considering a yield curve comprised of high-quality corporate bonds and the timing of the expected benefit cash flows of each plan.

The expected long-term rates of return on plan assets are determined by combining a review of the historical returns within the portfolio, the investment strategy included in the plans’ investment policy statement, and capital market projections for the asset classes in which the portfolio is invested, as well as the weighting of each asset class.

Unrecognized actuarial gains and losses and unrecognized prior service costs and credits are deferred and recorded in AOCI or, for Transco and Northwest Pipeline, as a regulatory asset or liability, until amortized as a component of net periodic benefit cost. Unrecognized actuarial gains and losses in excess of 10 percent of the greater of the benefit obligation or the market-related value of plan assets are amortized over the participants’ average remaining future years of service, which is approximately 13 years for our pension plans and approximately 7 years for our other postretirement benefit plans. Unrecognized prior service costs and credits for the other postretirement benefit plans are amortized on a straight line basis over the average remaining years of service to eligibility for eligible plan participants, which is approximately 4 years.

The expected return on plan assets component of net periodic benefit cost is calculated using the market-related value of plan assets. For our pension plans, the market-related value of plan assets is equal to the fair value of plan assets adjusted to reflect the amortization of gains or losses associated with the difference between the expected and actual return on plan assets over a 5-year period. Additionally, the market-related value of assets may be no more than 110 percent or less than 90 percent of the fair value of plan assets at the beginning of the year. The market-related value of plan assets for our other postretirement benefit plans is equal to the unadjusted fair value of plan assets at the beginning of the year.

Income taxes [Policy Text Block]

Income taxes

We include the operations of our domestic corporate subsidiaries and income from our subsidiary partnerships in our consolidated federal income tax return and also file tax returns in various foreign and state jurisdictions as required. Deferred income taxes are computed using the liability method and are provided on all temporary differences between the financial basis and the tax basis of our assets and liabilities. Our management’s judgment and income tax assumptions are used to determine the levels, if any, of valuation allowances associated with deferred tax assets.

Earnings (loss) per common share [Policy Text Block]

Earnings (loss) per common share

Basic earnings (loss) per common share in the Consolidated Statement of Operations is based on the sum of the weighted-average number of common shares outstanding and vested restricted stock units. Diluted earnings (loss) per common share in the Consolidated Statement of Operations includes any dilutive effect of stock options, nonvested restricted stock units, and convertible debt, unless otherwise noted. Diluted earnings (loss) per common share are calculated using the treasury-stock method.

Foreign currency translation [Policy Text Block]

Foreign currency translation

Certain of our foreign subsidiaries that used the Canadian dollar as their functional currency were sold in 2016. The assets and liabilities of such foreign subsidiaries were translated at the spot rate in effect at the applicable reporting date, and the combined statements of operations were translated into the U.S. dollar at the average exchange rates in effect during the applicable period. The resulting cumulative translation adjustment was recorded as a separate component of AOCI in the Consolidated Balance Sheet.

Transactions denominated in currencies other than the functional currency were recorded based on exchange rates at the time such transactions arose. Subsequent changes in exchange rates when the transactions were settled resulted in transaction gains and losses which were reflected in Other (income) expense – net within Costs and expenses in the Consolidated Statement of Operations. Substantially all of our Canadian operations were sold in September 2016.

XML

General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Regulatory Assets and Liabilities [Table Text Block]

Our current and noncurrent regulatory asset and liability balances for the years ended December 31, 2016 and 2015 are as follows:

	December 31,
	2016		2015
	(Millions)
Current assets reported within Other current assets and deferred charges	$	91	$	84
Noncurrent assets reported within Regulatory assets, deferred charges, and other	387		370
Total regulated assets	$	478	$	454
Current liabilities reported within Accrued liabilities	$	11	$	4
Noncurrent liabilities reported within Regulatory liabilities, deferred income, and other	498		434
Total regulated liabilities	$	509	$	438

XML

Acquisitions (Tables)

12 Months Ended

Dec. 31, 2016

Business Acquisition [Line Items]

Schedule of Business Acquisitions, by Acquisition [Table Text Block]

The following table presents the allocation of the acquisition-date fair value of the major classes of the assets acquired, which are presented in the Williams Partners segment, liabilities assumed, and noncontrolling interest at July 1, 2014. The fair value of accounts receivable acquired equaled contractual amounts receivable. Changes to the preliminary allocation disclosed in Exhibit 99.1 of our Form 8-K dated May 6, 2015, which were recorded in the first quarter of 2015, reflect an increase of $150 million in Property, plant, and equipment and $25 million in Goodwill, and a decrease of $168 million in Other intangible assets and $7 million in Investments. These adjustments during the measurement period were not considered significant to require retrospective revisions of our financial statements.

	(Millions)
Accounts receivable	$	168
Other current assets	63
Investments	5,865
Property, plant, and equipment	7,165
Goodwill	499
Other intangible assets	8,841
Current liabilities	(408		)
Debt	(4,052		)
Other noncurrent liabilities	(9		)
Noncontrolling interest in ACMP’s subsidiaries	(958		)
Noncontrolling interest in ACMP	(6,544		)

Business Acquisition, Pro Forma Information [Table Text Block]

The following unaudited pro forma Total revenues and Net income (loss) attributable to The Williams Companies, Inc. for the year ended December 31, 2014, are presented as if the ACMP Acquisition had been completed on January 1, 2014. These pro forma amounts are not necessarily indicative of what the actual results would have been if the acquisition had in fact occurred on the date or for the period indicated, nor do they purport to project Total revenues or Net income (loss) attributable to The Williams Companies, Inc. for any future periods or as of any date. These amounts do not give effect to any potential cost savings, operating synergies, or revenue enhancements to result from the transactions or the potential costs to achieve these cost savings, operating synergies, and revenue enhancements.

	December 31,
	2014
	(Millions)
Total revenues	$	8,181
Net income (loss) attributable to The Williams Companies, Inc.	$	622

XML

Divestiture (Tables)

12 Months Ended

Dec. 31, 2016

Discontinued Operations and Disposal Groups [Abstract]

Schedule of Disposal Group's Income Statement Disclosures [Table Text Block]

The following table presents the results of operations for the disposal group, excluding the impairment and loss noted above:

	Years Ended December 31,
	2016			2015
	(Millions)
Income (loss) before income taxes of disposal group	$	(98	)	$	17
Income (loss) before income taxes of disposal group attributable to The Williams Companies, Inc.	(95		)	15

XML

Variable Interest Entities (Tables)

12 Months Ended

Dec. 31, 2016

Variable Interest Entity Disclosures [Abstract]

Schedule of Variable Interest Entities [Table Text Block]

The following table presents amounts included in our Consolidated Balance Sheet that are for the use or obligation of WPZ and/or its subsidiaries, and which comprise a significant portion of our consolidated assets and liabilities:

	December 31,
	2016			2015			Classification
	(Millions)
Assets (liabilities):
Cash and cash equivalents	$	145		$	73		Cash and cash equivalents
Trade accounts and other receivables – net	925			1,026			Trade accounts and other receivables
Inventories	138			127			Inventories
Other current assets	205			190			Other current assets and deferred charges
Investments	6,701			7,336			Investments
Property, plant, and equipment – net	28,021			28,593			Property, plant, and equipment – net
Intangible assets – net	9,662			10,016			Intangible assets – net of accumulated amortization
Regulatory assets, deferred charges, and other noncurrent assets	467			479			Regulatory assets, deferred charges, and other
Accounts payable	(589		)	(625		)	Accounts payable
Accrued liabilities including current asset retirement obligations	(1,122		)	(757		)	Accrued liabilities
Commercial paper	(93		)	(499		)	Commercial paper
Long-term debt due within one year	(785		)	(176		)	Long-term debt due within one year
Long-term debt	(17,685		)	(19,001		)	Long-term debt
Deferred income tax liabilities	(20		)	(119		)	Deferred income tax liabilities
Noncurrent asset retirement obligations	(798		)	(857		)	Regulatory liabilities, deferred income, and other
Regulatory liabilities, deferred income, and other noncurrent liabilities	(1,860		)	(1,066		)	Regulatory liabilities, deferred income, and other

XML

Investing Activities (Tables)

12 Months Ended

Dec. 31, 2016

Investments [Abstract]

Impairments [Table Text Block]

Impairment of equity-method investments

The following table presents other-than-temporary impairment charges related to certain equity-method investments (see Note 17 – Fair Value Measurements, Guarantees, and Concentration of Credit Risk):

	Years Ended December 31,
	2016		2015
	(Millions)
Williams Partners
Appalachia Midstream Investments	$	294	$	562
DBJV	59		503
Laurel Mountain	50		45
UEOM	—		241
Ranch Westex	24		—
Other	3		8
	$	430	$	1,359

Investments [Table Text Block]

Investments

	Ownership Interest at December 31, 2016	December 31,
		2016		2015
		(Millions)
Equity-method investments:
Appalachia Midstream Investments	(1)	$	2,062	$	2,464
UEOM	62%	1,448		1,525
DBJV	50%	988		977
Discovery	60%	572		602
OPPL	50%	430		445
Caiman II	58%	426		418
Laurel Mountain	69%	324		391
Gulfstream	50%	261		293
Other	Various	190		221
		$	6,701	$	7,336

___________

(1) Includes equity-method investments in multiple gathering systems in the Marcellus Shale with an approximate average 41 percent interest.

Contributions [Table Text Block]

Purchases of and contributions to equity-method investments

We generally fund our portion of significant expansion or development projects of these investees through additional capital contributions. These transactions increased the carrying value of our investments and included:

	Years Ended December 31,
	2016		2015		2014
	(Millions)
DBJV	$	105	$	57	$	20
Appalachia Midstream Investments	28		93		84
Caiman II	22		—		175
UEOM	—		357		57
Discovery	—		35		106
Other	22		53		40
	$	177	$	595	$	482

Dividends and distributions [Table Text Block]

Dividends and distributions

The organizational documents of entities in which we have an equity-method interest generally require distribution of available cash to members on at least a quarterly basis. These transactions reduced the carrying value of our investments and included:

	Years Ended December 31,
	2016		2015		2014
	(Millions)
Appalachia Midstream Investments	$	211	$	219	$	130
Discovery	141		116		36
Gulfstream	100		88		81
UEOM	92		42		—
OPPL	69		45		27
Caiman II	40		33		13
DBJV	39		33		—
Laurel Mountain	28		31		39
ACMP	—		—		64
Other	22		26		50
	$	742	$	633	$	440

Summarized Financial Position and Results of Operations of Equity Method Investments [Table Text Block]

Summarized Financial Position and Results of Operations of All Equity-Method Investments

	December 31,
	2016			2015
	(Millions)
Assets (liabilities):
Current assets	$	508		$	773
Noncurrent assets	9,695			9,549
Current liabilities	(412		)	(633		)
Noncurrent liabilities	(1,484		)	(1,450		)

	Years Ended December 31,
	2016		2015		2014
	(Millions)
Gross revenue	$	1,883	$	1,707	$	1,623
Operating income	799		690		534
Net income	726		611		460

XML

Other Income and Expenses (Tables)

12 Months Ended

Dec. 31, 2016

Other Income and Expenses [Abstract]

Other Income and Expenses [Table Text Block]

The following table presents certain gains or losses reflected in Other (income) expense – net within Costs and expenses in the Consolidated Statement of Operations:

	Years Ended December 31,
	2016			2015			2014
	(Millions)
Williams Partners
Loss on sale of Canadian operations (Note 3)	$	34		$	—		$	—
Amortization of regulatory assets associated with asset retirement obligations	33			33			33
Accrual of regulatory liability related to overcollection of certain employee expenses	25			20			14
Project development costs related to Constitution (Note 4)	28			—			—
Net foreign currency exchange (gains) losses (1)	10			(10		)	(3		)
Contingency gain settlement (2)	—			—			(154		)
Net gain related to partial acreage dedication release	—			—			(12		)
Gain on asset retirement	(11		)	—			—
Loss related to sale of certain assets	—			—			10
Williams NGL & Petchem Services
Loss on sale of Canadian operations (Note 3)	32			—			—
Gain on sale of unused pipe	(10		)	—			—

________________

(1) Primarily relates to gains and losses incurred on foreign currency transactions and the remeasurement of U.S. dollar-denominated current assets and liabilities within our former Canadian operations (see Note 3 – Divestiture).

(2) In November 2014, we settled a claim arising from the resolution of a contingent gain related to claims associated with the purchase of a business in a prior period. Pursuant to the settlement, we received $154 million in cash, all of which was recognized as a gain in the fourth quarter of 2014.

XML

Provision (Benefit) for Income Taxes (Tables)

12 Months Ended

Dec. 31, 2016

Income Tax Expense (Benefit), Continuing Operations [Abstract]

Schedule of Components of Provision (benefit) for income taxes [Table Text Block]

The Provision (benefit) for income taxes includes:

	Years Ended December 31,
	2016			2015			2014
	(Millions)
Current:
Federal	$	—		$	—		$	(9	)
State	2			(7		)	2
Foreign	(1		)	(55		)	10
	1			(62		)	3
Deferred:
Federal	(6		)	(317		)	1,108
State	61			(25		)	119
Foreign	(81		)	5			19
	(26		)	(337		)	1,246
Provision (benefit) for income taxes	$	(25	)	$	(399	)	$	1,249

Provision for income taxes at federal statutory rate [Table Text Block]

Reconciliations from the Provision (benefit) at statutory rate to recorded Provision (benefit) for income taxes are as follows:

	Years Ended December 31,
	2016			2015			2014
	(Millions)
Provision (benefit) at statutory rate	$	(131	)	$	(600	)	$	1,255
Increases (decreases) in taxes resulting from:
Impact of nontaxable noncontrolling interests	(22		)	263			(75		)
State income taxes (net of federal benefit)	3			(21		)	82
State deferred income tax rate change	43			—			—
Foreign operations – net (Including tax effect of Canadian Sale)	78			8			(11		)
Taxes on undistributed earnings of foreign subsidiaries – net	—			—			(37		)
Translation adjustment of certain unrecognized tax benefits	(1		)	(71		)	—
Other – net	5			22			35
Provision (benefit) for income taxes	$	(25	)	$	(399	)	$	1,249

Deferred tax liabilities and Deferred tax assets [Table Text Block]

Significant components of Deferred income tax liabilities and Deferred income tax assets are as follows:

	December 31,
	2016		2015
	(Millions)
Deferred income tax liabilities:
Property, plant, and equipment	$	—	$	4
Investments	5,300		5,272
Other	29		15
Total deferred income tax liabilities	5,329		5,291
Deferred income tax assets:
Accrued liabilities	145		150
Minimum tax credits	139		139
Foreign tax credit	140		193
Federal loss carryovers	651		485
State losses and credits	313		296
Other	37		42
Total deferred income tax assets	1,425		1,305
Less valuation allowance	334		190
Net deferred income tax assets	1,091		1,115
Overall net deferred income tax liabilities	$	4,238	$	4,176

Reconciliation of unrecognized tax benefits [Table Bext Block]

A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows:

	2016			2015
	(Millions)
Balance at beginning of period	$	55		$	89
Additions for tax positions of prior years	—			2
Reductions for tax positions of prior years	(4		)	—
Changes due to currency translation	(1		)	(36		)
Balance at end of period	$	50		$	55

XML

Earnings (Loss) Per Common Share from Continuing Operations (Tables)

12 Months Ended

Dec. 31, 2016

Earnings Per Share [Abstract]

Earnings (loss) per common share from continuing operations [Table Text Block]

	Years Ended December 31,
	2016			2015			2014
	(Dollars in millions, except per-share amounts; shares in thousands)
Income (loss) from continuing operations attributable to The Williams Companies, Inc. available to common stockholders for basic and diluted earnings (loss) per common share	$	(424	)	$	(571	)	$	2,110
Basic weighted-average shares	750,673			749,271			719,325
Effect of dilutive securities:
Nonvested restricted stock units	—			—			2,234
Stock options	—			—			2,064
Convertible debentures	—			—			18
Diluted weighted-average shares (1)	750,673			749,271			723,641
Earnings (loss) per common share from continuing operations:
Basic	$	(.57	)	$	(.76	)	$	2.93
Diluted	$	(.57	)	$	(.76	)	$	2.91

(1) For the years ended December 31, 2016 and December 31, 2015, 0.6 million and 1.7 million weighted-average nonvested restricted stock units, and 0.5 million and 1.5 million weighted-average stock options have been excluded from the computation of diluted earnings (loss) per common share as their inclusion would be antidilutive due to our loss from continuing operations attributable to The Williams Companies, Inc.

XML

Employee Benefit Plans (Tables)

12 Months Ended

Dec. 31, 2016

Compensation and Retirement Disclosure [Abstract]

Changes in benefit obligations and plan assets [Table Text Block]

The following table presents the changes in benefit obligations and plan assets for pension benefits and other postretirement benefits for the years indicated:

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
	(Millions)
Change in benefit obligation:
Benefit obligation at beginning of year	$	1,464		$	1,544		$	202		$	233
Service cost	54			59			1			2
Interest cost	62			58			8			9
Plan participants’ contributions	—			—			2			2
Benefits paid	(130		)	(101		)	(15		)	(13		)
Actuarial loss (gain)	20			(91		)	(1		)	(31		)
Settlements	(4		)	(5		)	—			—
Net increase (decrease) in benefit obligation	2			(80		)	(5		)	(31		)
Benefit obligation at end of year	1,466			1,464			197			202
Change in plan assets:
Fair value of plan assets at beginning of year	1,241			1,293			201			208
Actual return on plan assets	82			(11		)	13			(1		)
Employer contributions	65			65			7			5
Plan participants’ contributions	—			—			2			2
Benefits paid	(130		)	(101		)	(15		)	(13		)
Settlements	(4		)	(5		)	—			—
Net increase (decrease) in fair value of plan assets	13			(52		)	7			(7		)
Fair value of plan assets at end of year	1,254			1,241			208			201
Funded status — overfunded (underfunded)	$	(212	)	$	(223	)	$	11		$	(1	)
Accumulated benefit obligation	$	1,440		$	1,432

Overfunded (underfunded) status of our pension plans and other postretirement benefit plans [Table Text Block]

The overfunded (underfunded) status of our pension plans and other postretirement benefit plans presented in the previous table are recognized in the Consolidated Balance Sheet within the following accounts:

	December 31,
	2016			2015
	(Millions)
Underfunded pension plans:
Current liabilities	$	(2	)	$	(2	)
Noncurrent liabilities	(210		)	(221		)
Overfunded (underfunded) other postretirement benefit plans:
Current liabilities	(7		)	(7		)
Noncurrent assets (liabilities)	18			6

Pre-tax amounts not yet recognized in net periodic benefit cost [Table Text Block]

Pre-tax amounts not yet recognized in Net periodic benefit cost at December 31 are as follows:

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
	(Millions)
Amounts included in Accumulated other comprehensive income (loss):
Prior service credit	$	—		$	—		$	5		$	11
Net actuarial loss	(535		)	(544		)	(18		)	(18		)
Amounts included in regulatory liabilities associated with Transco and Northwest Pipeline:
Prior service credit	N/A			N/A			$	10		$	19
Net actuarial gain	N/A			N/A			8			6

Schedule of Net Benefit Costs [Table Text Block]

Net periodic benefit cost for the years ended December 31 consist of the following:

	Pension Benefits									Other Postretirement  Benefits
	2016			2015			2014			2016			2015			2014
	(Millions)
Components of net periodic benefit cost:
Service cost	$	54		$	59		$	40		$	1		$	2		$	2
Interest cost	62			58			62			8			9			10
Expected return on plan assets	(85		)	(75		)	(76		)	(12		)	(12		)	(12		)
Amortization of prior service credit	—			—			—			(15		)	(17		)	(20		)
Amortization of net actuarial loss	30			42			39			—			2			—
Net actuarial (gain) loss from settlements and curtailments	2			2			1			—			—			(1		)
Reclassification to regulatory liability	—			—			—			4			3			4
Net periodic benefit cost	$	63		$	86		$	66		$	(14	)	$	(13	)	$	(17	)

Other changes in plan assets and benefit obligations recognized in other comprehensive income (loss) [Table Text Block]

Other changes in plan assets and benefit obligations recognized in Other comprehensive income (loss) before taxes for the years ended December 31 consist of the following:

	Pension Benefits								Other Postretirement  Benefits
	2016			2015		2014			2016			2015			2014
	(Millions)
Other changes in plan assets and benefit obligations recognized in Other comprehensive income (loss):
Net actuarial gain (loss)	$	(23	)	$	5	$	(142	)	$	—		$	8		$	(18	)
Prior service (cost) credit	—			—		—			—			—			(1		)
Amortization of prior service credit	—			—		—			(6		)	(6		)	(8		)
Amortization of net actuarial loss	30			42		39			—			2			—
Loss from settlements and curtailments	2			2		1			—			—			1
Other changes in plan assets and benefit obligations recognized in Other comprehensive income (loss)	$	9		$	49	$	(102	)	$	(6	)	$	4		$	(26	)

Schedule of Regulatory Assets / Liabilities [Table Text Block]

Other changes in plan assets and benefit obligations for our other postretirement benefit plans associated with Transco and Northwest Pipeline are recognized in regulatory assets/liabilities.Amounts recognized in regulatory assets/ liabilities for the years ended December 31 consist of the following:

	2016			2015			2014
	(Millions)
Other changes in plan assets and benefit obligations recognized in regulatory (assets) liabilities:
Net actuarial gain (loss)	$	2		$	10		$	(2	)
Amortization of prior service credit	(9		)	(11		)	(12		)

Pre-tax amounts expected to be amortized in net periodic benefit cost [Table Text Block]

Pre-tax amounts expected to be amortized in Net periodic benefit cost in 2017 are as follows:

	Pension Benefits		Other Postretirement Benefits
	(Millions)
Amounts included in Accumulated other comprehensive income (loss):
Prior service credit	$	—	$	(5	)
Net actuarial loss	28		—
Amounts included in regulatory liabilities associated with Transco and Northwest Pipeline:
Prior service credit	N/A		$	(8	)
Net actuarial loss	N/A		—

Schedule of Assumptions Used [Table Text Block]

The weighted-average assumptions utilized to determine benefit obligations as of December 31 are as follows:

	Pension Benefits				Other Postretirement Benefits
	2016		2015		2016		2015
Discount rate	4.17	%	4.38	%	4.27	%	4.50	%
Rate of compensation increase	4.87		4.88		N/A		N/A

The weighted-average assumptions utilized to determine Net periodic benefit cost for the years ended December 31 are as follows:

	Pension Benefits						Other Postretirement  Benefits
	2016		2015		2014		2016		2015		2014
Discount rate	4.37	%	3.96	%	4.68	%	4.50	%	4.12	%	4.80	%
Expected long-term rate of return on plan assets	6.85		6.38		6.85		6.11		5.70		6.11
Rate of compensation increase	4.88		4.62		4.56		N/A		N/A		N/A

One percentage point change in assumed health care cost trend rates effects [Table Text Block]

A one-percentage-point change in assumed health care cost trend rates would have the following effects:

	Point increase		Point decrease
	(Millions)
Effect on total of service and interest cost components	$	—	$	—
Effect on other postretirement benefit obligation	6		(5		)

Fair values of plan assets [Table Text Block]

The fair values of our pension plan assets at December 31, 2016 and 2015 by asset class are as follows:

	2016
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(Millions)
Pension assets:
Cash management fund	$	14	$	—	$	—	$	14
Equity securities:
U.S. large cap	87		—		—		87
U.S. small cap	77		—		—		77
Fixed income securities (1):
U.S. Treasury securities	68		—		—		68
Government and municipal bonds	—		10		—		10
Mortgage and asset-backed securities	—		80		—		80
Corporate bonds	—		148		—		148
Insurance company investment contracts and other	—		5		—		5
	$	246	$	243	$	—	489
Commingled investment funds measured at net asset value practical expedient (3):
Equities — U.S. large cap							369
Equities — International small cap							27
Equities — International emerging markets							50
Equities — International developed markets							149
Fixed income — U.S. long duration							88
Fixed income — Corporate bonds							82
Total assets at fair value at December 31, 2016							$	1,254

	2015
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(Millions)
Pension assets:
Cash management fund	$	8	$	—	$	—	$	8
Equity securities:
U.S. large cap	83		—		—		83
U.S. small cap	64		—		—		64
Fixed income securities (1):
U.S. Treasury securities	65		—		—		65
Government and municipal bonds	—		8		—		8
Mortgage and asset-backed securities	—		87		—		87
Corporate bonds	—		145		—		145
Insurance company investment contracts and other	—		5		—		5
	$	220	$	245	$	—	465
Commingled investment funds measured at net asset value practical expedient (3):
Equities — U.S. large cap							367
Equities — International small cap							27
Equities — International emerging markets							50
Equities — International developed markets							153
Fixed income — U.S. long duration							95
Fixed income — Corporate bonds							84
Total assets at fair value at December 31, 2015							$	1,241

The fair values of our other postretirement benefits plan assets at December 31, 2016 and 2015 by asset class are as follows:

	2016
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(Millions)
Other postretirement benefit assets:
Cash management funds	$	11	$	—	$	—	$	11
Equity securities:
U.S. large cap	24		—		—		24
U.S. small cap	15		—		—		15
International developed markets large cap growth	—		5		—		5
Fixed income securities (2):
U.S. Treasury securities	7		—		—		7
Government and municipal bonds	—		1		—		1
Mortgage and asset-backed securities	—		8		—		8
Corporate bonds	—		15		—		15
Mutual fund — Municipal bonds	42		—		—		42
	$	99	$	29	$	—	128
Commingled investment funds measured at net asset value practical expedient (3):
Equities — U.S. large cap							38
Equities — International small cap							3
Equities — International emerging markets							5
Equities — International developed markets							16
Fixed income — U.S. long duration							9
Fixed income — Corporate bonds							9
Total assets at fair value at December 31, 2016							$	208

	2015
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(Millions)
Other postretirement benefit assets:
Cash management funds	$	11	$	—	$	—	$	11
Equity securities:
U.S. large cap	37		—		—		37
U.S. small cap	20		—		—		20
International developed markets large cap growth	1		9		—		10
Emerging markets growth	—		1		—		1
Fixed income securities (2):
U.S. Treasury securities	7		—		—		7
Government and municipal bonds	—		12		—		12
Mortgage and asset-backed securities	—		9		—		9
Corporate bonds	—		15		—		15
	$	76	$	46	$	—	122
Commingled investment funds measured at net asset value practical expedient (3):
Equities — U.S. large cap							37
Equities — International small cap							3
Equities — International emerging markets							5
Equities — International developed markets							16
Fixed income — U.S. long duration							10
Fixed income — Corporate bonds							8
Total assets at fair value at December 31, 2015							$	201

____________

(1) The weighted-average credit quality rating of the pension assets fixed income security portfolio is investment grade with a weighted-average duration of approximately 8 years for 2016 and 2015.

(2) The weighted-average credit quality rating of the other postretirement benefit assets fixed income security portfolio is investment grade with a weighted-average duration of approximately 8 years for 2016 and 7 years for 2015.

(3) The stated intents of the funds vary based on each commingled fund’s investment objective. These objectives generally include strategies to replicate or outperform various market indices. Certain standard withdrawal restrictions generally apply, which may include redemption notification period restrictions ranging from 10 to 30 days. Additionally, the fund managers retain the right to restrict withdrawals from and/or purchases into the funds so as not to disadvantage other investors in the funds. Generally, the funds also reserve the right to make all or a portion of the redemption in-kind rather than in cash or a combination of cash and in-kind.

Expected benefit payments [Table Text Block]

Following are the expected benefits to be paid by the plans. These estimates are based on the same assumptions previously discussed and reflect future service as appropriate. The actuarial assumptions are based on long-term expectations and include, but are not limited to, assumptions as to average expected retirement age and form of benefit payment. Actual benefit payments could differ significantly from expected benefit payments if near-term participant behaviors differ significantly from the actuarial assumptions.

	Pension Benefits		Other Postretirement Benefits
	(Millions)
2017	$	99	$	13
2018	103		13
2019	103		13
2020	106		13
2021	111		13
2022-2026	562		62

XML

Property, Plant, and Equipment (Tables)

12 Months Ended

Dec. 31, 2016

Property, Plant and Equipment [Abstract]

Property, Plant, and Equipment [Table Text Block]

The following table presents nonregulated and regulated Property, plant, and equipment – net as presented on the Consolidated Balance Sheet for the years ended:

	Estimated Useful Life  (1) (Years)	Depreciation Rates (1) (%)	December 31,
			2016			2015
			(Millions)
Nonregulated:
Natural gas gathering and processing facilities	5 - 40		$	20,413		$	20,789
Construction in progress	Not applicable		412			1,366
Other	2 - 45		2,202			2,170
Regulated:
Natural gas transmission facilities		1.20 - 6.97	12,692			12,189
Construction in progress	Not applicable	Not applicable	1,603			941
Other	5 - 45	1.35 - 33.33	1,590			1,584
Total property, plant, and equipment, at cost			38,912			39,039
Accumulated depreciation and amortization			(10,484		)	(9,460		)
Property, plant, and equipment — net			$	28,428		$	29,579

__________

(1) Estimated useful life and depreciation rates are presented as of December 31, 2016. Depreciation rates and estimated useful lives for regulated assets are prescribed by the FERC.

Asset Retirement Obligation [Table Text Block]

The following table presents the significant changes to our ARO, of which $801 million and $858 million are included in Regulatory liabilities, deferred income, and other with the remaining current portion in Accrued liabilities at December 31, 2016 and 2015, respectively.

	December 31,
	2016			2015
	(Millions)
Beginning balance	$	915		$	831
Liabilities incurred	24			42
Liabilities settled	(8		)	(3		)
Accretion expense	69			60
Revisions (1)	(138		)	(15		)
Ending balance	$	862		$	915

___________

(1) Several factors are considered in the annual review process, including inflation rates, current estimates for removal cost, market risk premiums, discount rates, and the estimated remaining useful life of the assets. The 2016 revisions reflect changes in removal cost estimates, increases in the estimated remaining useful life of certain assets, and decreases in the inflation rate and discount rates used in the annual review process. The 2015 revisions reflect changes in removal cost estimates and the estimated remaining useful life of assets, a decrease in the inflation rate, and increases in the discount rates used in the annual review process.

XML

Goodwill and Other Intangible Assets (Tables)

12 Months Ended

Dec. 31, 2016

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of Goodwill [Table Text Block]

Goodwill

Changes in the carrying amount of goodwill, included in Intangible assets – net of accumulated amortization, by reportable segment for the periods indicated are as follows:

	Williams Partners
	(Millions)
December 31, 2014	$	1,120
Purchase accounting adjustment	25
Impairment	(1,098		)
December 31, 2015	$	47
December 31, 2016	$	47

Schedule of Finite-Lived Intangible Assets [Table Text Block]

Other Intangible Assets

The gross carrying amount and accumulated amortization of other intangible assets, included in Intangible assets – net of accumulated amortization, at December 31 are as follows:

	2016					2015
	Gross Carrying Amount		Accumulated Amortization			Gross Carrying Amount		Accumulated Amortization
	(Millions)
Contractual customer relationships	$	10,635	$	(1,019	)	$	10,633	$	(663	)

XML

Accrued Liabilities (Tables)

12 Months Ended

Dec. 31, 2016

Accrued Liabilities, Current [Abstract]

Accrued Liabilities [Table Text Block]

	December 31,
	2016		2015
	(Millions)
Deferred income	$	338	$	94
Interest on debt	310		284
Employee costs	223		215
Refundable deposits	160		—
Special distribution repayable to Gulfstream (See Note 6 - Investing Activities)	—		149
Asset retirement obligations	61		57
Other, including other loss contingencies	356		279
	$	1,448	$	1,078

XML

Debt, Banking Arrangements, and Leases (Tables)

12 Months Ended

Dec. 31, 2016

Debt Disclosure [Abstract]

Schedule of Long-term Debt Instruments [Table Text Block]

Long-Term Debt

	December 31,
	2016		2015
	(Millions)
Unsecured:
Transco:
6.4% Notes due 2016 (1)	$	—	$	200
6.05% Notes due 2018	250		250
7.08% Debentures due 2026	8		8
7.25% Debentures due 2026	200		200
7.85% Notes due 2026	1,000		—
5.4% Notes due 2041	375		375
4.45% Notes due 2042	400		400
Northwest Pipeline:
7% Notes due 2016	—		175
5.95% Notes due 2017	185		185
6.05% Notes due 2018	250		250
7.125% Debentures due 2025	85		85
WPZ:
7.25% Notes due 2017	600		600
5.25% Notes due 2020	1,500		1,500
4.125% Notes due 2020	600		600
4% Notes due 2021	500		500
3.6% Notes due 2022	1,250		1,250
3.35% Notes due 2022	750		750
6.125% Notes due 2022	750		750
4.5% Notes due 2023	600		600
4.875% Notes due 2023	1,400		1,400
4.3% Notes due 2024	1,000		1,000
4.875% Notes due 2024	750		750
3.9% Notes due 2025	750		750
4% Notes due 2025	750		750
6.3% Notes due 2040	1,250		1,250
5.8% Notes due 2043	400		400
5.4% Notes due 2044	500		500
4.9% Notes due 2045	500		500
5.1% Notes due 2045	1,000		1,000
Term Loan, variable interest rate, due 2018	850		850
Credit facility loans	—		1,310
WMB:
7.875% Notes due 2021	371		371
3.7% Notes due 2023	850		850
4.55% Notes due 2024	1,250		1,250
7.5% Debentures due 2031	339		339

	December 31,
	2016			2015
	(Millions)
7.75% Notes due 2031	252			252
8.75% Notes due 2032	445			445
5.75% Notes due 2044	650			650
Various — 5.5% to 10.25% Notes and Debentures due 2019 to 2033	55			55
Credit facility loans	775			650
Capital lease obligations	—			1
Debt issuance costs	(119		)	(123		)
Net unamortized debt premium (discount)	88			110
Total long-term debt, including current portion	23,409			23,988
Long-term debt due within one year	(785		)	(176		)
Long-term debt	$	22,624		$	23,812

___________

(1) Presented as long-term debt at December 31, 2015, due to Transco’s intent and ability to refinance.

Schedule of Maturities of Long-term Debt [Table Text Block]

The following table presents aggregate minimum maturities of long-term debt, excluding net unamortized debt premium (discount), debt issuance costs, and capital lease obligations, for each of the next five years:

	December 31, 2016
	(Millions)
2017	$	785
2018	1,350
2019	32
2020	2,896
2021	871

Schedule of Line of Credit Facilities [Table Text Block]

Credit Facilities

	December 31, 2016
	Available		Outstanding
	(Millions)
WMB
Long-term credit facility	$	1,500	$	775
Letters of credit under certain bilateral bank agreements			13
WPZ
Long-term credit facility (1)	3,500		—
Letters of credit under certain bilateral bank agreements			1

________________

(1) In managing our available liquidity, we do not expect a maximum outstanding amount in excess of the capacity of our credit facility inclusive of any outstanding amounts under our commercial paper program.

Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]

The future minimum annual rentals under noncancelable operating leases, are payable as follows:

	December 31, 2016
	(Millions)
2017	$	62
2018	58
2019	51
2020	46
2021	35
Thereafter	90
Total	$	342

XML

Stockholders' Equity (Tables)

12 Months Ended

Dec. 31, 2016

Stockholders' Equity Note [Abstract]

Accumulated Other Comprehensive Income (Loss) [Table Text Block]

The following table presents the changes in AOCI by component, net of income taxes:

	Cash Flow Hedges			Foreign Currency Translation			Pension and Other Post Retirement Benefits			Total
	(Millions)
Balance at December 31, 2015	$	(1	)	$	(103	)	$	(338	)	$	(442	)
Other comprehensive income (loss) before reclassifications	2			25			(15		)	12
Amounts reclassified from accumulated othercomprehensive income (loss)	(1		)	76			16			91
Other comprehensive income (loss)	1			101			1			103
Balance at December 31, 2016	$	—		$	(2	)	$	(337	)	$	(339	)

Reclassifications Out Of Accumulated Other Comprehensive Income [Table Text Block]

Reclassifications out of AOCI are presented in the following table by component for the year ended December 31, 2016:

Component	Reclassifications			Classification
	(Millions)
Cash flow hedges:
Energy commodity contracts	$	(3	)	Product sales
Total cash flow hedges	(3		)
Pension and other postretirement benefits:
Amortization of prior service cost (credit) included in net periodic benefit cost	(6		)	Note 10 – Employee Benefit Plans
Amortization of actuarial (gain) loss included in net periodic benefit cost	32			Note 10 – Employee Benefit Plans
Total pension and other postretirement benefits	26
Foreign currency translation:
Reclassification of cumulative foreign currency translation adjustment upon sale of foreign entities	155			Other (income) expense - net
Total before tax	178
Income tax benefit	(45		)	Provision (benefit) for income taxes
Net of income tax	133
Noncontrolling interest	(42		)	Net income (loss) attributable to noncontrolling interests
Reclassifications during the period	$	91

XML

Equity-Based Compensation (Tables)

12 Months Ended

Dec. 31, 2016

Williams Companies Incentive Plan [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Stock Option Rollfoward and related information [Table Text Block]

The following summary reflects stock option activity and related information for the year ended December 31, 2016:

Stock Options	Options		Weighted- Average Exercise Price		Aggregate Intrinsic Value
	(Millions)				(Millions)
Outstanding at December 31, 2015	5.7		$	31.51
Granted	0.9		$	24.99
Exercised	(0.3	)	$	17.84
Cancelled	(0.1	)	$	24.04
Outstanding at December 31, 2016	6.2		$	31.32	$	28
Exercisable at December 31, 2016	5.0		$	29.75	$	23

Schedule of Cash Proceeds Received from Share-based Payment Awards [Table Text Block]

The following table summarizes additional information related to stock option activity during each of the last three years:

	Years Ended December 31,
	2016		2015		2014
	(Millions)
Total intrinsic value of options exercised	$	2	$	37	$	48
Tax benefits realized on options exercised	$	1	$	13	$	18
Cash received from the exercise of options	$	4	$	20	$	31

Stock Options Schedule of Valuation Assumptions [Table Text Block]

The estimated fair value at date of grant of options for our common stock granted in each respective year, using the Black-Scholes option pricing model, is as follows: 

	2016			2015			2014
Weighted-average grant date fair value of options for our common stock granted during the year, per share	$	7.90		$	7.61		$	7.50
Weighted-average assumptions:
Dividend yield	3.2		%	4.8		%	4.2		%
Volatility	44.7		%	27.8		%	28.0		%
Risk-free interest rate	1.2		%	1.8		%	2.2		%
Expected life (years)	6.0			6.0			6.5

Nonvested Restricted Stock Unit Rollforward and related information [Table Text Block]

The following summary reflects nonvested restricted stock unit activity and related information for the year ended December 31, 2016:

Restricted Stock Units Outstanding	Shares		Weighted- Average Fair Value (1)
	(Millions)
Nonvested at December 31, 2015	3.4		$	39.38
Granted	1.5		$	26.51
Forfeited	(0.1	)	$	38.18
Vested	(0.9	)	$	35.49
Nonvested at December 31, 2016	3.9		$	35.19

______________

(1) Performance-based restricted stock units are valued utilizing a Monte Carlo valuation method using measures of total shareholder return. Certain of the performance-based restricted stock units are subject to a holding period of up to two years after the vesting date. Discounts for the restrictions of liquidity were applied to the estimated fair value at the date of certain awards and ranged from 5.83 percent to 15.58 percent. The discounts were developed using the Chaffe model and the Finnerty model. All other restricted stock units are valued at the grant-date market price. Restricted stock units generally vest after three years.

Other restricted stock unit information [Table Text Block]

Value of Restricted Stock Units	2016		2015		2014
Weighted-average grant date fair value of restricted stock units granted during the year, per share	$	26.51	$	40.15	$	42.79
Total fair value of restricted stock units vested during the year ($’s in millions)	$	32	$	42	$	27

Williams Partners Long Term Incentive Plan [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Nonvested Restricted Stock Unit Rollforward and related information [Table Text Block]

The following summary reflects nonvested WPZ restricted common unit activity and related information for the year ended December 31, 2016:

Restricted Common Units Outstanding	Units		Weighted- Average Fair Value
	(Millions)
Nonvested at December 31, 2015	1.2		$	55.93
Forfeited	(0.1	)	$	52.85
Vested	(0.5	)	$	59.09
Nonvested at December 31, 2016	0.6		$	52.97

XML

Fair Value Measurements, Guarantees, and Concentration of Credit Risk (Tables)

12 Months Ended

Dec. 31, 2016

Fair Value Disclosures [Abstract]

Fair Value Assets and Liabilities Measured On Recurring Basis [Table Text Block]

The following table presents, by level within the fair value hierarchy, certain of our financial assets and liabilities. The carrying values of cash and cash equivalents, accounts receivable, commercial paper, and accounts payable approximate fair value because of the short-term nature of these instruments. Therefore, these assets and liabilities are not presented in the following table.

							Fair Value Measurements Using
	Carrying Amount			Fair Value			Quoted Prices In Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
	(Millions)
Assets (liabilities) at December 31, 2016:
Measured on a recurring basis:
ARO Trust investments	$	96		$	96		$	96	$	—		$	—
Energy derivatives assets designated as hedging instruments	2			2			—		2			—
Energy derivatives assets not designated as hedging instruments	1			1			—		—			1
Energy derivatives liabilities not designated as hedging instruments	(6		)	(6		)	—		—			(6		)
Additional disclosures:
Other receivables	15			15			15		—			—
Long-term debt, including current portion	(23,409		)	(24,090		)	—		(24,090		)	—
Guarantees	(44		)	(30		)	—		(14		)	(16		)
Assets (liabilities) at December 31, 2015:
Measured on a recurring basis:
ARO Trust investments	$	67		$	67		$	67	$	—		$	—
Energy derivatives assets not designated as hedging instruments	5			5			—		3			2
Energy derivatives liabilities not designated as hedging instruments	(2		)	(2		)	—		—			(2		)
Additional disclosures:
Other receivables	12			30			10		2			18
Long-term debt, including current portion (1)	(23,987		)	(19,606		)	—		(19,606		)	—
Guarantee	(29		)	(16		)	—		(16		)	—

___________

(1) Excludes capital leases.

Fair Value Measurements, Nonrecurring [Table Text Block]

The following table presents impairments of assets and investments associated with certain nonrecurring fair value measurements within Level 3 of the fair value hierarchy.

						Impairments
						Years Ended December 31,
	Classification	Segment	Date of Measurement	Fair Value		2016		2015		2014
				(Millions)
Surplus equipment (1)	Property, plant, and equipment – net	Williams Partners	June 30, 2014	$	46					$	17
Surplus equipment (1)	Property, plant, and equipment – net	Williams Partners	December 31, 2014	32						13
Surplus equipment (1)	Property, plant, and equipment – net	Williams Partners	June 30, 2015	17				$	20
Surplus equipment (1)	Assets held for sale	Williams Partners	December 31, 2014	1						12
Previously capitalized project development costs (2)	Property, plant, and equipment – net	Williams Partners	December 31, 2015	13				94
Previously capitalized project development costs (3)	Property, plant, and equipment – net	Williams NGL & Petchem Services	December 31, 2015	40				64
Canadian operations (4)	Assets held for sale	Williams Partners	June 30, 2016	924		$	341
Canadian operations (4)	Assets held for sale	Williams NGL & Petchem Services	June 30, 2016	206		406
Certain gathering operations (5)	Property, plant, and equipment – net	Williams Partners	June 30, 2016	18		48
Certain idle assets	Property, plant, and equipment – net	Williams NGL & Petchem Services	December 31, 2016	73		8
Level 3 fair value measurements of certain assets						803		178		42
Other impairments and write-downs (6)						70		31		10
Impairment of certain assets						$	873	$	209	$	52
Equity-method investments (7)	Investments	Williams Partners	September 30, 2015	$	1,203			$	461
Equity-method investments (8)	Investments	Williams Partners	December 31, 2015	4,017				890
Equity-method investments (9)	Investments	Williams Partners	March 31, 2016	1,294		$	109
Equity-method investments (10)	Investments	Williams Partners	December 31, 2016	1,295		318
Other equity-method investment	Investments	Williams Partners	December 31, 2015	58				8
Other equity-method investment	Investments	Williams Partners	March 31, 2016	—		3
Impairment of equity-method investments						$	430	$	1,359

______________

(1) Relates to certain surplus equipment. The estimated fair value was determined by a market approach based on our analysis of observable inputs in the principal market.

(2) Relates to a gas processing plant, the completion of which is considered remote due to unfavorable impact of low natural gas prices on customer drilling activities. The assessed fair value primarily represents the estimated salvage value of certain equipment measured using a market approach based on our analysis of observable inputs in the principal market.

(3) Relates to an olefins pipeline project, the completion of which is considered remote due to lack of customer interest. The assessed fair value primarily represents the estimated fair value of unused pipeline measured using a market approach based on our analysis of observable inputs in the principal market.

(4) Relates to our Canadian operations. We designated these operations as held for sale as of June 30, 2016. As a result, we measured the fair value of the disposal group, resulting in an impairment charge. The estimated fair value was determined by a market approach based primarily on inputs received in the marketing process and reflected our estimate of the potential assumed proceeds. We disposed of our Canadian operations through a sale during the third quarter of 2016. See Note 3 – Divestiture.

(5) Relates to certain gathering assets within the Mid-Continent region. The estimated fair value was determined by a market approach based on our analysis of observable inputs in the principal market.

(6) Reflects multiple individually insignificant impairments and write-downs of other certain assets that may no longer be in use or are surplus in nature for which the fair value was determined to be zero or an insignificant salvage value.

(7) Relates to equity-method investments in DBJV and certain of the Appalachia Midstream Investments. The historical carrying value of these investments was initially recorded based on estimated fair value during the third quarter of 2014 in conjunction with the acquisition of ACMP. We estimated the fair value of these investments using an income approach based on expected future cash flows and appropriate discount rates. The determination of estimated future cash flows involved significant assumptions regarding gathering volumes and related capital spending. Discount rates utilized were 11.8 percent and 8.8 percent for DBJV and certain of the Appalachia Midstream Investments, respectively, and reflected our cost of capital as impacted by market conditions, and risks associated with the underlying businesses.

(8) Relates to equity-method investments in DBJV, certain of the Appalachia Midstream Investments, UEOM, and Laurel Mountain. We estimated the fair value of these investments using an income approach based on expected future cash flows and appropriate discount rates. The determination of estimated future cash flows involved significant assumptions regarding gathering volumes and related capital spending. Discount rates utilized ranged from 10.8 percent to 14.4 percent and reflected further fourth-quarter 2015 increases in our cost of capital, revised estimates of expected future cash flows, and risks associated with the underlying businesses.

(9) Relates to equity-method investments in DBJV and Laurel Mountain. Our carrying values in these equity-method investments had been written down to fair value at December 31, 2015. Our first-quarter 2016 analysis reflected higher discount rates for both of these investments, along with lower natural gas prices for Laurel Mountain. We estimated the fair value of these investments using an income approach based on expected future cash flows and appropriate discount rates. The determination of estimated future cash flows involved significant assumptions regarding gathering volumes and related capital spending. Discount rates utilized ranged from 13.0 percent to 13.3 percent and reflected increases in our cost of capital, revised estimates of expected future cash flows, and risks associated with the underlying businesses.

(10) Relates to equity-method investments in Ranch Westex and multiple Appalachia Midstream Investments. The historical carrying value of these investments was initially recorded based on estimated fair value during the third quarter of 2014 in conjunction with the acquisition of ACMP. We estimated the fair value of these Appalachia Midstream Investments using an income approach based on expected future cash flows and appropriate discount rates. The determination of estimated future cash flows involved significant assumptions regarding gathering volumes, rates, and related capital spending. The discount rate utilized for the Appalachia Midstream Investments evaluation was 10.2 percent and reflected our cost of capital as impacted by market conditions and risks associated with the underlying businesses. In addition to utilizing an income approach, we also considered a market approach for certain Appalachia Midstream Investments and Ranch Westex based on an agreement reached in February 2017 to exchange our interests in DBJV and Ranch Westex for additional interests in certain Appalachia Midstream Investments and cash.

Concentration of receivables, net of allowances, by product or service [Table Text Block]

Trade accounts and other receivables

The following table summarizes concentration of receivables, net of allowances:

	December 31,
	2016		2015
	(Millions)
NGLs, natural gas, and related products and services	$	736	$	823
Transportation of natural gas and related products	187		202
Other	15		16
Total	$	938	$	1,041

XML

Segment Disclosures (Tables)

12 Months Ended

Dec. 31, 2016

Segment Reporting [Abstract]

Schedule of Revenue from External Customers and Long-Lived Assets, by Geographical Areas [Table Text Block]

The following geographic area data includes Revenues from external customers based on product shipment origin and Long-lived assets based upon physical location:

		United States		Canada		Total
		(Millions)
Revenues from external customers:
	2016	$	7,425	$	74	$	7,499
	2015	7,247		113		7,360
	2014	7,229		408		7,637
Long-lived assets:
	2016	$	38,091	$	—	$	38,091
	2015	38,016		1,580		39,596
	2014	38,290		1,364		39,654

Long-lived assets are comprised of property, plant, and equipment, goodwill, and other intangible assets.

Reconciliation of revenue from segment to consolidated [Table Text Block]

The following table reflects the reconciliation of Segment revenues to Total revenues as reported in the Consolidated Statement of Operations and Other financial information:

	Williams Partners		Williams NGL & Petchem Services			Other		Eliminations			Total
	(Millions)
2016
Segment revenues:
Service revenues
External	$	5,140	$	2		$	29	$	—		$	5,171
Internal	33		—			19		(52		)	—
Total service revenues	5,173		2			48		(52		)	5,171
Product sales
External	2,318		10			—		—			2,328
Internal	—		16			—		(16		)	—
Total product sales	2,318		26			—		(16		)	2,328
Total revenues	$	7,491	$	28		$	48	$	(68	)	$	7,499
Other financial information:
Additions to long-lived assets	$	2,102	$	33		$	11	$	(1	)	$	2,145
Proportional Modified EBITDA of equity-method investments	754		—			—		—			754
2015
Segment revenues:
Service revenues
External	$	5,134	$	2		$	28	$	—		$	5,164
Internal	1		—			158		(159		)	—
Total service revenues	5,135		2			186		(159		)	5,164
Product sales
External	2,196		—			—		—			2,196
Internal	—		—			—		—			—
Total product sales	2,196		—			—		—			2,196
Total revenues	$	7,331	$	2		$	186	$	(159	)	$	7,360
Other financial information:
Additions to long-lived assets	$	2,960	$	360		$	28	$	(12	)	$	3,336
Proportional Modified EBITDA of equity-method investments	699		—			—		—			699
2014
Segment revenues:
Service revenues
External	$	3,887	$	—		$	229	$	—		$	4,116
Internal	1		—			30		(31		)	—
Total service revenues	3,888		—			259		(31		)	4,116
Product sales
External	3,521		—			—		—			3,521
Internal	—		—			—		—			—
Total product sales	3,521		—			—		—			3,521
Total revenues	$	7,409	$	—		$	259	$	(31	)	$	7,637
Other financial information:
Additions to long-lived assets (1)	$	20,413	$	291		$	54	$	(2	)	$	20,756
Proportional Modified EBITDA of equity-method investments	431		(78		)	85		—			438

_______________

(1) 2014 Additions to long-lived assets within our Williams Partners segment primarily includes the acquisition-date fair value of long-lived assets from the ACMP Acquisition. (See Note 2 - Acquisitions.)

Reconciliation of Modified EBITDA to Net income (loss) [Table Text Block]

The following table reflects the reconciliation of Modified EBITDA to Net income (loss) as reported in the Consolidated Statement of Operations:

	Years Ended December 31,
	2016			2015			2014
	(Millions)
Modified EBITDA by segment:
Williams Partners	$	3,864		$	4,003		$	3,244
Williams NGL & Petchem Services	(540		)	(83		)	(115		)
Other	(2		)	(29		)	103
	3,322			3,891			3,232
Accretion expense associated with asset retirement obligations for nonregulated operations	(31		)	(28		)	(18		)
Depreciation and amortization expenses	(1,763		)	(1,738		)	(1,176		)
Impairment of goodwill	—			(1,098		)	—
Equity earnings (losses)	397			335			144
Gain on remeasurement of equity-method investment	—			—			2,544
Impairment of equity-method investments	(430		)	(1,359		)	—
Other investing income (loss) – net	63			27			43
Proportional Modified EBITDA of equity-method investments	(754		)	(699		)	(438		)
Interest expense	(1,179		)	(1,044		)	(747		)
(Provision) benefit for income taxes	25			399			(1,249		)
Income (loss) from discontinued operations, net of tax	—			—			4
Net income (loss)	$	(350	)	$	(1,314	)	$	2,339

Total assets and equity method investments by reporting segment [Table Text Block]

The following table reflects Total assets and Equity-method investments by reportable segments:

	Total Assets						Equity-Method Investments
	December 31, 2016			December 31, 2015			December 31, 2016		December 31, 2015
	(Millions)
Williams Partners	$	46,265		$	47,870		$	6,701	$	7,336
Williams NGL & Petchem Services	249			835			—		—
Other	674			850			—		—
Eliminations	(353		)	(535		)	—		—
Total	$	46,835		$	49,020		$	6,701	$	7,336

XML

Schedule I Condensed Financial Information of Registrant (Tables)

12 Months Ended

Dec. 31, 2016

Condensed Financial Information of Parent Company Only Disclosure [Abstract]

Condensed Income Statement [Table Text Block]

The Williams Companies, Inc.

Schedule I — Condensed Financial Information of Registrant

Statement of Comprehensive Income (Loss) (Parent)

	Years Ended December 31,
	2016			2015			2014
	(Millions, except per-share amounts)
Equity in earnings of consolidated subsidiaries	$	522		$	232		$	1,799
Equity earnings (losses) from investment in Access Midstream Partners	—			—			(7		)
Interest incurred — external	(268		)	(255		)	(206		)
Interest incurred — affiliate	(568		)	(828		)	(797		)
Interest income — affiliate	—			6			10
Gain on remeasurement of equity-method investment	—			—			2,544
Other income (expense) — net	(53		)	(75		)	(13		)
Income (loss) from continuing operations before income taxes	(367		)	(920		)	3,330
Provision (benefit) for income taxes	57			(349		)	1,220
Income (loss) from continuing operations	(424		)	(571		)	2,110
Income (loss) from discontinued operations	—			—			4
Net income (loss)	$	(424	)	$	(571	)	$	2,114
Basic earnings (loss) per common share:
Income (loss) from continuing operations	$	(.57	)	$	(.76	)	$	2.93
Income (loss) from discontinued operations	—			—			.01
Net income (loss)	$	(.57	)	$	(.76	)	$	2.94
Weighted-average shares (thousands)	750,673			749,271			719,325
Diluted earnings (loss) per common share:
Income (loss) from continuing operations	$	(.57	)	$	(.76	)	$	2.91
Income (loss) from discontinued operations	—			—			.01
Net income (loss)	$	(.57	)	$	(.76	)	$	2.92
Weighted-average shares (thousands)	750,673			749,271			723,641
Other comprehensive income (loss):
Equity in other comprehensive income (loss) of consolidated subsidiaries	$	171		$	(204	)	$	(96	)
Other comprehensive income (loss) attributable to The Williams Companies, Inc.	1			33			(80		)
Other comprehensive income (loss)	172			(171		)	(176		)
Less: Other comprehensive income (loss) attributable to noncontrolling interests	69			(70		)	(19		)
Comprehensive income (loss) attributable to The Williams Companies, Inc.	$	(321	)	$	(672	)	$	1,957

See accompanying notes.

Condensed Balance Sheet [Table Text Block]

The Williams Companies, Inc.

Schedule I — Condensed Financial Information of Registrant – (Continued)

Balance Sheet (Parent)

	December 31,
	2016		2015
	(Millions)
ASSETS
Current assets:
Cash and cash equivalents	$	14	$	12
Other current assets and deferred charges	16		62
Total current assets	30		74
Investments in and advances to consolidated subsidiaries	22,359		30,927
Property, plant, and equipment — net	77		99
Other noncurrent assets	8		12
Total assets	$	22,474	$	31,112
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	27	$	27
Other current liabilities	169		163
Total current liabilities	196		190
Long-term debt	4,939		4,811
Notes payable — affiliates	8,171		15,506
Pension, other postretirement, and other noncurrent liabilities	287		336
Deferred income tax liabilities	4,238		4,121
Contingent liabilities and commitments
Equity:
Common stock	785		784
Other stockholders’ equity	3,858		5,364
Total stockholders’ equity	4,643		6,148
Total liabilities and stockholders’ equity	$	22,474	$	31,112

See accompanying notes.

Condensed Cash Flow Statement [Table Text Block]

The Williams Companies, Inc.

Schedule I — Condensed Financial Information of Registrant – (Continued)

Statement of Cash Flows (Parent)

	Years Ended December 31,
	2016			2015			2014
	(Millions)
NET CASH FLOWS PROVIDED (USED) BY OPERATING ACTIVITIES	$	(833	)	$	(1,209	)	$	(500	)
FINANCING ACTIVITIES:
Proceeds from long-term debt	2,280			2,097			2,935
Payments of long-term debt	(2,155		)	(1,817		)	(671		)
Changes in notes payable to affiliates	9			2,211			2,465
Tax benefit of stock-based awards	—			—			25
Proceeds from issuance of common stock	9			27			3,416
Dividends paid	(1,261		)	(1,836		)	(1,412		)
Other — net	—			(2		)	(17		)
Net cash provided (used) by financing activities	(1,118		)	680			6,741
INVESTING ACTIVITIES:
Capital expenditures	(13		)	(29		)	(54		)
Purchase of Access Midstream Partners	—			—			(5,995		)
Changes in investments in and advances to consolidated subsidiaries	1,966			521			(450		)
Other — net	—			—			25
Net cash provided (used) by investing activities	1,953			492			(6,474		)
Increase (decrease) in cash and cash equivalents	2			(37		)	(233		)
Cash and cash equivalents at beginning of year	12			49			282
Cash and cash equivalents at end of year	$	14		$	12		$	49

See accompanying notes.

XML

General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies (Details) - USD ($) $ / shares in Units, $ in Millions				1 Months Ended											3 Months Ended	12 Months Ended
	Feb. 10, 2017	Jan. 09, 2017	Sep. 28, 2015	Feb. 10, 2017	Feb. 03, 2017	Jan. 31, 2017	Nov. 30, 2016	Aug. 31, 2016	May 31, 2016	Feb. 29, 2016	Nov. 30, 2015	Jun. 30, 2015	Oct. 31, 2014	Feb. 28, 2014	Jun. 30, 2014	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 20, 2012
Basis Of Presentation [Abstract]
Master limited partnership, general partner ownership percentage																			2.00%
Changes in ownership of consolidated subsidiaries, net																$ (6)	$ 94	$ 44
Income Tax Effects Allocated Directly to Equity, Other																6
WPZ Merger Agreement [Member]
General and Description Of Business [Abstract]
Termination Fee			$ 428
Maximum Reduction Of Quarterly Incentive Distributions			$ 209
Basis Of Presentation [Abstract]
Reduction in incentive distribution rights payment									$ 10	$ 209	$ 209
Canada Dropdown [Member]
Basis Of Presentation [Abstract]
Proceeds from Divestiture of Businesses														$ 56	$ 31
Number Of Limited Partner Units Received1														25,577,521
Payments for Previous Acquisition													$ 56
Reduction in incentive distribution rights payment													$ 2
Financial Repositioning [Member] | Subsequent Event [Member]
Basis Of Presentation [Abstract]
Sale Of Stock Number Of Shares Issued In Transaction		277,000			59,000,000	289,000,000
Payments to Acquire Limited Partnership Interests	$ 50					$ 10
Sale of Stock, Price Per Share					$ 36.08586
Noncontrolling Interest [Member]
Basis Of Presentation [Abstract]
Changes in ownership of consolidated subsidiaries, net																(18)	254	137
Capital in excess of par value [Member]
Basis Of Presentation [Abstract]
Changes in ownership of consolidated subsidiaries, net																$ 12	(160)	(73)
Gulfstream Natural Gas System, L.L.C.[Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage																50.00%
Utica East Ohio Midstream, LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage																62.00%
Delaware Basin Gas Gathering System [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage																50.00%
Laurel Mountain Midstream, LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage																69.00%
Caiman Energy II [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage																58.00%
Discovery Producer Services LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage																60.00%
Overland Pass Pipeline Company LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage																50.00%
Williams Partners L.P. [Member]
Basis Of Presentation [Abstract]
Master limited partnership, general partner ownership percentage														2.00%
Williams Partners L.P. [Member] | Financial Repositioning [Member] | Subsequent Event [Member]
General and Description Of Business [Abstract]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest				74.00%
Basis Of Presentation [Abstract]
Master limited partnership, general partner ownership percentage						2.00%
Williams Partners L.P. [Member] | General and Limited Partner [Member]
General and Description Of Business [Abstract]
Master limited partnership ownership percentage																60.00%
Williams Partners [Member]
General and Description Of Business [Abstract]
Number Of Interstate Natural Gas Pipelines																2
Basis Of Presentation [Abstract]
Goodwill																$ 47	$ 47	$ 1,120
Williams Partners [Member] | Private Placement [Member]
Basis Of Presentation [Abstract]
Sale Of Stock Number Of Shares Issued In Transaction								6,975,446
Payments to Acquire Limited Partnership Interests								$ 250
Williams Partners [Member] | Dividend Reinvestment Program [Member]
Basis Of Presentation [Abstract]
Sale Of Stock Number Of Shares Issued In Transaction							7,891,414
Payments to Acquire Limited Partnership Interests							$ 250
Sale of Stock, Consideration Received on Transaction							$ 260
Williams Partners [Member] | Equity Distribution Agreement [Member]
Basis Of Presentation [Abstract]
Sale Of Stock Number Of Shares Issued In Transaction																3,273,601
Sale of Stock, Consideration Received on Transaction																$ 115
Williams Partners [Member] | Gulfstream Natural Gas System, L.L.C.[Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage																50.00%
Williams Partners [Member] | Utica East Ohio Midstream, LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage																62.00%
Basis Of Presentation [Abstract]
Reduction in incentive distribution rights payment												$ 2
Williams Partners [Member] | Delaware Basin Gas Gathering System [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage																50.00%
Williams Partners [Member] | Laurel Mountain Midstream, LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage																69.00%
Williams Partners [Member] | Caiman Energy II [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage																58.00%
Williams Partners [Member] | Discovery Producer Services LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage																60.00%
Williams Partners [Member] | Overland Pass Pipeline Company LLC [Member]
General and Description Of Business [Abstract]
Equity Method Investment, Ownership Percentage																50.00%
Williams Partners [Member] | Appalachia Midstream Services, LLC [Member]
General and Description Of Business [Abstract]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest																41.00%
Williams Partners [Member] | Constitution Pipeline Company LLC [Member]
General and Description Of Business [Abstract]
Variable Interest Entity Ownership Percentage																41.00%

XML

Summary of Significant Accounting Policies (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Regulatory Assets and Liabilities Disclosure [Abstract]
Regulatory Assets, Current	$ 91	$ 84
Regulatory Assets, Noncurrent	387	370
Total regulatory assets	478	454
Regulatory Liabilities, Current	11	4
Regulatory Liabilities, Noncurrent	498	434
Total regulatory liabilities	$ 509	$ 438
Interest Capitalized [Abstract]
Minimum period of construction for capitalization of interest	3 months
Minimum total project cost for capitalization of interest	$ 1
General Discussion of Pension and Other Postretirement Benefits [Abstract]
Threshold For Amortization Of Unrecognized Actuarial Gains Losses	10.00%
Pension Benefits [Member]
General Discussion of Pension and Other Postretirement Benefits [Abstract]
Approximate Amortization Period Of Net Actuarial Gain Loss	13 years
Amortization Period Of Difference Between Expected And Actual Return On Plan Assets	5 years
Other Postretirement Benefits [Member]
General Discussion of Pension and Other Postretirement Benefits [Abstract]
Approximate Amortization Period Of Net Actuarial Gain Loss	7 years
Amortization Period Of Unrecognized Prior Service Costs Credits	4 years
Maximum [Member] | Pension Benefits [Member]
General Discussion of Pension and Other Postretirement Benefits [Abstract]
Threshold For Market Related Value	110.00%
Minimum [Member] | Pension Benefits [Member]
General Discussion of Pension and Other Postretirement Benefits [Abstract]
Threshold For Market Related Value	90.00%

XML

General, Description of Business, Basis of Presentation, and Summary of Significant Accounting Policies Deferred Revenue Arrangement, by Type [Table] (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Oct. 31, 2016	Dec. 31, 2016
Newly constructed assets [Member]
Deferred Revenue Arrangement [Line Items]
Deferred Revenue, Additions	$ 104
Contracts in Barnett Shale and Mid-Continent regions [Member]
Deferred Revenue Arrangement [Line Items]
Deferred Revenue, Additions		$ 820
Maximum [Member]
Deferred Revenue Arrangement [Line Items]
Duration Of Period For Deferred Revenue Recognition		25 years
Minimum [Member]
Deferred Revenue Arrangement [Line Items]
Duration Of Period For Deferred Revenue Recognition		1 year

XML

Acquisitions (Details) $ in Millions	1 Months Ended		3 Months Ended		6 Months Ended	12 Months Ended
	Jun. 30, 2015 USD ($)	May 31, 2015 USD ($)	Sep. 30, 2015 USD ($)	Mar. 31, 2015 USD ($)	Jul. 02, 2014 USD ($)	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)	Dec. 20, 2012 USD ($)	Jul. 01, 2014 USD ($)
Equity Method Investments and Joint Ventures [Abstract]
Payments to Acquire Equity Method Investments						$ 177	$ 595	$ 482
Business Combination, Consideration Transferred [Abstract]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest									2.00%
Business Combination, Step Acquisition, Equity Interest in Acquiree, Remeasurement Gain						0	0	2,544
Business Acquisition, Pro Forma Information [Abstract]
Gain on remeasurement of equity-method investment (Note 2)						0	0	2,544
Williams Partners [Member]
Business Acquisition [Line Items]
Goodwill, Purchase Accounting Adjustments							25
Business Acquisition, Purchase Price Allocation [Abstract]
Goodwill						$ 47	47	1,120
Access Midstream [Member]
Equity Method Investments and Joint Ventures [Abstract]
Payments to Acquire Equity Method Investments									$ 2,190
Business Combination, Consideration Transferred [Abstract]
Business Combination, Step Acquisition, Equity Interest in Acquiree, Fair Value					$ 4,600
Utica East Ohio Midstream, LLC [Member]
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investment, Ownership Percentage						62.00%
Payments to Acquire Equity Method Investments						$ 0	$ 357	57
Utica East Ohio Midstream, LLC [Member] | Williams Partners [Member]
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investment, Ownership Percentage						62.00%
Payments to Acquire Equity Method Investments	$ 357
Reduction in incentive distribution rights payment	$ 2
Access Midstream Partners Acquisition [Member]
Business Acquisition [Line Items]
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Property, Plant, and Equipment				$ 150
Goodwill, Purchase Accounting Adjustments				25
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Intangibles				(168)
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Investments				$ (7)
Business Combination, Consideration Transferred [Abstract]
Payments to Acquire Businesses, Gross					$ 5,995
Business Combination, Step Acquisition, Equity Interest in Acquiree, Remeasurement Gain								2,544
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life					30 years
Percentage Of Finite Lived Intangible Assets Impacted By Our Intent Or Ability To Renew Or Extend Arrangement										56.00%
Acquired Finite-lived Intangible Asset, Weighted-Average Period before Renewal or Extension					17 years
Business Acquisition, Pro Forma Information [Abstract]
Business Acquisition, Pro Forma Revenue								8,181
Business Acquisition, Pro Forma Net Income (Loss)								622
Gain on remeasurement of equity-method investment (Note 2)								2,544
Business Combination, Pro Forma Information, Revenue of Acquiree since Acquisition Date, Actual								781
Business Combination, Pro Forma Information, Earnings or Loss of Acquiree since Acquisition Date, Actual								165
Access Midstream Partners Acquisition [Member] | Selling, General and Administrative Expenses [Member]
Business Combination, Consideration Transferred [Abstract]
Business Combination, Acquisition Related Costs								16
Access Midstream Partners Acquisition [Member] | Interest Incurred [Member]
Business Combination, Consideration Transferred [Abstract]
Business Combination, Acquisition Related Costs								9
Access Midstream Partners Acquisition [Member] | Income Loss From Equity Method Investment [Member]
Business Combination, Consideration Transferred [Abstract]
Business Combination, Integration Related Costs								$ 19
Access Midstream Partners Acquisition [Member] | Pro Forma [Member]
Business Combination, Consideration Transferred [Abstract]
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life								30 years
Access Midstream Partners Acquisition [Member] | Williams Partners [Member]
Business Acquisition, Purchase Price Allocation [Abstract]
Accounts receivable										$ 168
Other current assets										63
Investments										5,865
Property, plant, and equipment										7,165
Goodwill										499
Other intangible assets										8,841
Current liabilities										(408)
Debt										(4,052)
Other noncurrent liabilities										$ (9)
Access Midstream Partners Acquisition [Member] | Access Midstream Partners L.P. [Member]
Business Combination, Consideration Transferred [Abstract]
Business Combination, Step Acquisition, Equity Interest in Acquiree, Including Subsequent Acquisition, Percentage										26.00%
Access Midstream Partners Acquisition [Member] | Access Midstream Partners L.P. [Member] | Williams Partners [Member]
Business Acquisition, Purchase Price Allocation [Abstract]
Noncontrolling interest										$ (6,544)
Access Midstream Partners Acquisition [Member] | ACMP's subsidiaries [Member] | Williams Partners [Member]
Business Acquisition, Purchase Price Allocation [Abstract]
Noncontrolling interest										$ (958)
Eagle Ford Gathering System [Member]
Business Combination, Consideration Transferred [Abstract]
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life		30 years
Acquired Finite-lived Intangible Asset, Weighted-Average Period before Renewal or Extension		10 years
Business Acquisition, Purchase Price Allocation [Abstract]
Other intangible assets		$ 32
Eagle Ford Gathering System [Member] | Williams Partners [Member]
Business Acquisition [Line Items]
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Property, Plant, and Equipment			$ 20
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Intangibles			$ (20)
Number Of Miles Of Pipeline Acquired		140
Business Combination, Consideration Transferred [Abstract]
Payments to Acquire Businesses, Gross		$ 112
Business Acquisition, Purchase Price Allocation [Abstract]
Property, plant, and equipment		$ 80
Limited Partner [Member] | Access Midstream Partners L.P. [Member]
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investment, Ownership Percentage									24.00%
General Partner [Member] | Access Midstream [Member]
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investment, Ownership Percentage									50.00%
General Partner [Member] | Access Midstream Partners Acquisition [Member]
Business Combination, Consideration Transferred [Abstract]
Business Acquisition, Percentage of Voting Interests Acquired										50.00%
Additional Investment [Member] | Utica East Ohio Midstream, LLC [Member]
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investment, Ownership Percentage	13.00%

XML

Divestiture (Details) - Canadian Operations [Member] - USD ($) $ in Millions		3 Months Ended	12 Months Ended
		Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Impairment Of Certain Assets [Member] | Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Williams Partners [Member]
Income Statement and Additional Disclosures by Disposal Groups [Line Items]
Disposal Group, Not Discontinued Operation, Loss (Gain) on Write-down	[1]	$ 341
Impairment Of Certain Assets [Member] | Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Williams Ngl And Petchem Services [Member]
Income Statement and Additional Disclosures by Disposal Groups [Line Items]
Disposal Group, Not Discontinued Operation, Loss (Gain) on Write-down	[1]	406
Disposal Group, Not Discontinued Operations [Member]
Income Statement and Additional Disclosures by Disposal Groups [Line Items]
Disposal Group, Consideration			$ 1,020
Divested cash of disposal group			31
Reduction in incentive distribution rights payment			150
Income (Loss) from Individually Significant Component Disposed of, Attributable to Parent, before Income Tax [Abstract]
Income (Loss) before Income Taxes of Disposal Group			(98)	$ 17
Income (Loss) before Income Taxes of Disposal Group Attributable to the Williams Companies, Inc.			(95)	15
Disposal Group, Not Discontinued Operations [Member] | Other income (expense) - net [Member]
Income Statement and Additional Disclosures by Disposal Groups [Line Items]
Loss on sale of Canadian operations (Note 3)			66
Gain (Loss) on Foreign Currency Derivative Instruments Not Designated as Hedging Instruments			15
Disposal Group, Not Discontinued Operations [Member] | Other income (expense) - net [Member] | Williams Partners [Member]
Income Statement and Additional Disclosures by Disposal Groups [Line Items]
Loss on sale of Canadian operations (Note 3)			34	0	$ 0
Disposal Group, Not Discontinued Operations [Member] | Other income (expense) - net [Member] | Williams Ngl And Petchem Services [Member]
Income Statement and Additional Disclosures by Disposal Groups [Line Items]
Loss on sale of Canadian operations (Note 3)			$ 32	$ 0	$ 0
Disposal Group, Not Discontinued Operations [Member] | Impairment Of Certain Assets [Member] | Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member]
Income Statement and Additional Disclosures by Disposal Groups [Line Items]
Disposal Group, Not Discontinued Operation, Loss (Gain) on Write-down		$ 747

[1] Relates to our Canadian operations. We designated these operations as held for sale as of June 30, 2016. As a result, we measured the fair value of the disposal group, resulting in an impairment charge. The estimated fair value was determined by a market approach based primarily on inputs received in the marketing process and reflected our estimate of the potential assumed proceeds. We disposed of our Canadian operations through a sale during the third quarter of 2016. See Note 3 – Divestiture.

XML

Variable Interest Entities (Details) - Variable Interest Entity, Primary Beneficiary [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Cash and cash equivalents [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Variable Interest Entity, Consolidated, Carrying Amount, Assets	$ 145	$ 73
Accounts receivable [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Variable Interest Entity, Consolidated, Carrying Amount, Assets	925	1,026
Inventories [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Variable Interest Entity, Consolidated, Carrying Amount, Assets	138	127
Other current assets [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Variable Interest Entity, Consolidated, Carrying Amount, Assets	205	190
Investments [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Variable Interest Entity, Consolidated, Carrying Amount, Assets	6,701	7,336
Property, plant, and equipment, net [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Variable Interest Entity, Consolidated, Carrying Amount, Assets	28,021	28,593
Intangible Assets [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Variable Interest Entity, Consolidated, Carrying Amount, Assets	9,662	10,016
Regulatory assets, deferred charges, and other noncurrent assets [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Variable Interest Entity, Consolidated, Carrying Amount, Assets	467	479
Accounts payable [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Variable Interest Entity, Consolidated, Carrying Amount, Liabilities	(589)	(625)
Accrued liabilities [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Variable Interest Entity, Consolidated, Carrying Amount, Liabilities	(1,122)	(757)
Commercial Paper [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Variable Interest Entity, Consolidated, Carrying Amount, Liabilities	(93)	(499)
Long-term debt due within one year [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Variable Interest Entity, Consolidated, Carrying Amount, Liabilities	(785)	(176)
Long-term Debt [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Variable Interest Entity, Consolidated, Carrying Amount, Liabilities	(17,685)	(19,001)
Deferred Income Tax Liabilities [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Variable Interest Entity, Consolidated, Carrying Amount, Liabilities	(20)	(119)
Noncurrent asset retirement obligations [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Variable Interest Entity, Consolidated, Carrying Amount, Liabilities	(798)	(857)
Regulatory liabilities, deferred income, and other noncurrent liabilities [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Variable Interest Entity, Consolidated, Carrying Amount, Liabilities	$ (1,860)	$ (1,066)
Gulfstar One [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	51.00%
Constitution Pipeline Company Llc [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	41.00%
Constitution Pipeline Company Llc [Member] | Property, plant, and equipment, net [Member]
Variable Interest Entity [Line Items]
Capitalized project development costs, Cumulative	$ 381
Constitution Pipeline Company Llc [Member] | Estimated Remaining Construction Costs For Variable Interest Entity [Member]
Variable Interest Entity [Line Items]
Estimated remaining construction costs	$ 687
Cardinal Gas Services LLC [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	66.00%
Jackalope Gas Gathering Services LLC [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	50.00%

XML

Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Related Party Transaction [Line Items]
Product costs	$ 180	$ 187	$ 197
Equity Method Investee [Member]
Related Party Transaction [Line Items]
Accounts payable	19	12
Management Fees Revenue	66	64	65
Common Management Transaction [Member]
Related Party Transaction [Line Items]
Service revenues	$ 144	$ 111	$ 115

XML

Investing Activities (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 20, 2012
Schedule of Investments [Line Items]
Impairment of equity-method investments		$ 430	$ 1,359	$ 0
Equity earnings (losses)		397	335	144
Investment income, nonoperating		63	27	43
Equity-method investments		6,701	7,336
Equity-method investment, difference between carrying amount and underlying equity		1,900	2,400
Equity-method investment, payments to purchase or contributions		177	595	482
Equity-method investment, dividends or distributions		742	633	440
Special distribution from equity-method investment		0	396	0
Summarized Financial Position of Equity Method Investments
Current assets		508	773
Noncurrent assets		9,695	9,549
Current liabilities		(412)	(633)
Noncurrent liabilities		(1,484)	(1,450)
Summarized Results of Operations of Equity Method Investments
Gross revenue		1,883	1,707	1,623
Operating income		799	690	534
Net income		726	611	460
Caiman Energy II [Member]
Schedule of Investments [Line Items]
Equity-method investments		$ 426	418
Equity-method investment, ownership percentage		58.00%
Equity-method investment, payments to purchase or contributions		$ 22	0	175
Equity-method investment, dividends or distributions		40	33	13
Delaware Basin Gas Gathering System [Member]
Schedule of Investments [Line Items]
Impairment of equity-method investments		59	503
Equity-method investments		$ 988	977
Equity-method investment, ownership percentage		50.00%
Equity-method investment, payments to purchase or contributions		$ 105	57	20
Equity-method investment, dividends or distributions		39	33	0
Appalachia Midstream Investments [Member]
Schedule of Investments [Line Items]
Impairment of equity-method investments		294	562
Equity earnings (losses)		(19)
Gain on sale of equity-method investment		27
Equity-method investments	[1]	$ 2,062	2,464
Equity-method investment, ownership percentage		41.00%
Equity-method investment, payments to purchase or contributions		$ 28	93	84
Equity-method investment, dividends or distributions		211	219	130
Utica East Ohio Midstream, LLC [Member]
Schedule of Investments [Line Items]
Impairment of equity-method investments		0	241
Equity-method investments		$ 1,448	1,525
Equity-method investment, ownership percentage		62.00%
Equity-method investment, payments to purchase or contributions		$ 0	357	57
Equity-method investment, dividends or distributions		92	42	0
Discovery Producer Services LLC [Member]
Schedule of Investments [Line Items]
Equity-method investments		$ 572	602
Equity-method investment, ownership percentage		60.00%
Equity-method investment, payments to purchase or contributions		$ 0	35	106
Equity-method investment, dividends or distributions		141	116	36
Laurel Mountain Midstream, LLC [Member]
Schedule of Investments [Line Items]
Impairment of equity-method investments		50	45
Equity-method investments		$ 324	391
Equity-method investment, ownership percentage		69.00%
Equity-method investment, dividends or distributions		$ 28	31	39
Overland Pass Pipeline Company LLC [Member]
Schedule of Investments [Line Items]
Equity-method investments		$ 430	445
Equity-method investment, ownership percentage		50.00%
Equity-method investment, dividends or distributions		$ 69	45	27
Gulfstream Natural Gas System, L.L.C.[Member]
Schedule of Investments [Line Items]
Equity-method investments		$ 261	293
Equity-method investment, ownership percentage		50.00%
Equity-method investment, dividends or distributions		$ 100	88	81
Special distribution from equity-method investment			396
Contribution to equity-method investment for repayment of debt		148	248
Access Midstream Partners [Member]
Schedule of Investments [Line Items]
Equity earnings (losses)				(7)
Equity-method investment, payments to purchase or contributions					$ 2,190
Equity-method investment, dividends or distributions		0	0	64
Access Midstream Partners [Member] | Adjustment for amortization of difference between carrying amount and underlying equity [Member]
Schedule of Investments [Line Items]
Equity earnings (losses)				(30)
Ranch Westex JV LLC [Member]
Schedule of Investments [Line Items]
Impairment of equity-method investments		24	0
Other [Member]
Schedule of Investments [Line Items]
Impairment of equity-method investments		3	8
Equity-method investments		190	221
Equity-method investment, payments to purchase or contributions		22	53	40
Equity-method investment, dividends or distributions		22	26	50
Bluegrass Pipeline [Member]
Schedule of Investments [Line Items]
Equity earnings (losses)				(67)
Moss Lake [Member]
Schedule of Investments [Line Items]
Equity earnings (losses)				(4)
Former Venezuela Operations [Member]
Schedule of Investments [Line Items]
Investment income, nonoperating		36	27	41
Equity-Method Investment Debt Due November 1, 2015 [Member] | Gulfstream Natural Gas System, L.L.C.[Member]
Schedule of Investments [Line Items]
Equity-method investment debt			$ 500
Equity-Method Investment Debt Due June 1, 2016 [Member] | Gulfstream Natural Gas System, L.L.C.[Member]
Schedule of Investments [Line Items]
Equity-method investment debt		$ 300
Access Midstream Partners Acquisition [Member] | Income Loss From Equity-Method Investment [Member]
Schedule of Investments [Line Items]
Business Combination, Integration Related Costs				$ 19

[1] Includes equity-method investments in multiple gathering systems in the Marcellus Shale with an approximate average 41 percent interest.

XML

Other Income and Expenses (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Gain on asset retirement	[1]	$ 138	$ 15
Other income (expense) - net [Member] | Williams Partners [Member]
Segment Reporting Information [Line Items]
Amortization of regulatory assets associated with asset retirement obligations		33	33	$ 33
Accrual of regulatory liability related to overcollection of certain employee expenses		25	20	14
Project development costs related to Constitution (Note 4)		28	0	0
Net foreign currency exchange (gains) losses (1)	[2]	10	(10)	(3)
Contingency gain settlement (2)	[3]	0	0	(154)
Net gain related to partial acreage dedication release		0	0	(12)
Gain on asset retirement		(11)	0	0
Loss related to sale of certain assets		0	0	10
Other income (expense) - net [Member] | Williams NGL & Petchem Services [Member]
Segment Reporting Information [Line Items]
Gain on sale of unused pipe		(10)	0	0
Selling, general and administrative expenses [Member] | Williams Partners [Member] | Acquisition and Merger [Member]
Segment Reporting Information [Line Items]
Business combination, acquisition related costs			26	27
Selling, general and administrative expenses [Member] | Williams Partners [Member] | Acquisition [Member]
Segment Reporting Information [Line Items]
Business combination, acquisition related costs				16
Selling, general and administrative expenses [Member] | Williams Partners [Member] | Transition [Member]
Segment Reporting Information [Line Items]
Business combination, integration related costs			9	15
Selling, general and administrative expenses [Member] | Other [Member] | Other Restructuring [Member]
Segment Reporting Information [Line Items]
Business combination, integration related costs			32	10
Operation and maintenance expenses [Member] | Williams Partners [Member] | Transition [Member]
Segment Reporting Information [Line Items]
Business combination, integration related costs			12	15
Interest incurred [Member] | Acquisition [Member]
Segment Reporting Information [Line Items]
Business combination, acquisition related costs				9
Interest incurred [Member] | Merger [Member]
Segment Reporting Information [Line Items]
Business combination, acquisition related costs			2
Service revenues [Member] | Williams Partners [Member]
Segment Reporting Information [Line Items]
Deferred Revenue, Revenue Recognized		173
Minimum volume commitment fees		58	239	167
Selling, general, and administrative expenses and Operating and maintenance expenses [Member]
Segment Reporting Information [Line Items]
Severance and other related costs		42
Other income (expense) - net [Member] | Williams Partners [Member]
Segment Reporting Information [Line Items]
Allowance for funds used during construction, capitalized cost of equity		89	95	44
Gain on extinguishment of debt			14
Disposal Group, Not Discontinued Operations [Member] | Canadian Operations [Member] | Other income (expense) - net [Member]
Segment Reporting Information [Line Items]
Loss on sale of Canadian operations (Note 3)		66
Disposal Group, Not Discontinued Operations [Member] | Canadian Operations [Member] | Other income (expense) - net [Member] | Williams Partners [Member]
Segment Reporting Information [Line Items]
Loss on sale of Canadian operations (Note 3)		34	0	0
Disposal Group, Not Discontinued Operations [Member] | Canadian Operations [Member] | Other income (expense) - net [Member] | Williams NGL & Petchem Services [Member]
Segment Reporting Information [Line Items]
Loss on sale of Canadian operations (Note 3)		$ 32	$ 0	$ 0

[1] Several factors are considered in the annual review process, including inflation rates, current estimates for removal cost, market risk premiums, discount rates, and the estimated remaining useful life of the assets. The 2016 revisions reflect changes in removal cost estimates, increases in the estimated remaining useful life of certain assets, and decreases in the inflation rate and discount rates used in the annual review process. The 2015 revisions reflect changes in removal cost estimates and the estimated remaining useful life of assets, a decrease in the inflation rate, and increases in the discount rates used in the annual review process.

[2] Primarily relates to gains and losses incurred on foreign currency transactions and the remeasurement of U.S. dollar-denominated current assets and liabilities within our former Canadian operations (see Note 3 – Divestiture).

[3] In November 2014, we settled a claim arising from the resolution of a contingent gain related to claims associated with the purchase of a business in a prior period. Pursuant to the settlement, we received $154 million in cash, all of which was recognized as a gain in the fourth quarter of 2014.

XML

Provision (Benefit) for Income Taxes Tax Provison (Benefit) Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Current :
Federal	$ 0	$ 0	$ (9)
State	2	(7)	2
Foreign	(1)	(55)	10
Total	1	(62)	3
Deferred:
Federal	(6)	(317)	1,108
State	61	(25)	119
Foreign	(81)	5	19
Total	(26)	(337)	1,246
Provision (benefit) for income taxes	$ (25)	$ (399)	$ 1,249

XML

Provision (Benefit) for Income Taxes Reconciliations to Recorded Tax Provision (Benefit) Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Effective Income Tax Rate Reconciliation [Abstract]
Provision (benefit) at statutory rate	$ (131)	$ (600)	$ 1,255
Increases (decreases) in taxes resulting from:
Impact of nontaxable noncontrolling interests	(22)	263	(75)
State income taxes (net of federal benefit)	3	(21)	82
State deferred income tax rate change	43	0	0
Foreign operations – net (Including tax effect of Canadian Sale)	78	8	(11)
Taxes on undistributed earnings of foreign subsidiaries - net	0	0	(37)
Translation adjustment of certain unrecognized tax benefits	(1)	(71)	0
Other – net	5	22	35
Provision (benefit) for income taxes	$ (25)	$ (399)	$ 1,249

XML

Provision (Benefit) for Income Taxes Deferred Tax Table (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Deferred income tax liabilities:
Property, plant, and equipment	$ 0	$ 4
Investments	5,300	5,272
Other	29	15
Total deferred income tax liabilities	5,329	5,291
Deferred income tax assets:
Accrued liabilities	145	150
Minimum tax credits	139	139
Foreign tax credit	140	193
Federal loss carryovers	651	485
State losses and credits	313	296
Other	37	42
Total deferred income tax assets	1,425	1,305
Less valuation allowance	334	190
Net deferred income tax assets	1,091	1,115
Overall net deferred income tax liabilities	$ 4,238	$ 4,176

XML

Provision (Benefit) for Income Taxes Reconciliation of Unrecognized Tax Benefits Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at beginning of period	$ 55	$ 89
Additions for tax positions of prior years	0	2
Reductions for tax positions of prior years	(4)	0
Changes due to currency translation	(1)	(36)
Balance at end of period	$ 50	$ 55

XML

Provision (Benefit) for Income Taxes Textuals (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Contingency [Line Items]
Foreign income (loss) in Income from continuing operations before income taxes	$ (885,000)	$ 20,000	$ 102,000
Impairment Loss		2,700,000
Gain on remeasurement of equity-method investment (Note 2)	0	0	2,544,000
Deferred Tax Assets, Capital Loss Carryforwards	364,000
Minimum tax credits	139,000	139,000
Deferred Tax Assets, Tax Credit Carryforwards, Foreign	140,000	193,000
Employee Share-based Compensation Tax Benefit Excluded From Deferred Income Tax Assets	38,000
Cash payments for income taxes (net of refunds and including discontinued operations)	5,000	(136,000)	29,000
Unrecognized tax benefits	50,000	55,000	89,000
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	49,000	51,000
Total interest and penalties recognized as part of income tax provision	300	(22,000)	$ 8,000
Total interest and penalties accrued as uncertain tax positions	3,000	2,000
Unrecognized Tax Benefits Income Tax Penalties And Interest Expense Due To Currency Fluctuations [Member]
Income Tax Contingency [Line Items]
Total interest and penalties recognized as part of income tax provision		$ (35,000)
Federal [Member] | Federal Net Operating Loss And Charitable Contribution Carryforwards [Member]
Income Tax Contingency [Line Items]
Deferred Tax Assets, Operating Loss Carryforwards, Domestic	$ 1,600,000

XML

Earnings (Loss) Per Common Share from Continuing Operations (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2016		Dec. 31, 2015		Dec. 31, 2014
Earnings (loss) per common share from continuing operations
Income (loss) from continuing operations attributable to The Williams Companies, Inc. available to common stockholders for basic and diluted earnings (loss) per common share	$ (424)		$ (571)		$ 2,110
Basic weighted-average shares	750,673		749,271		719,325
Effect of dilutive securities:
Diluted weighted-average shares	750,673	[1]	749,271	[1]	723,641
Earnings (loss) per common share from continuing operations:
Basic	$ (0.57)		$ (0.76)		$ 2.93
Diluted	$ (0.57)		$ (0.76)		$ 2.91
Nonvested restricted stock units [Member]
Effect of dilutive securities:
Incremental common shares attributable to share-based payment arrangements under effects of dilutive securities item	0		0		2,234
Earnings (loss) per common share from continuing operations (Textuals) [Abstract]
Number of weighted-average shares excluded from computation of diluted earnings per common share	600		1,700
Stock options [Member]
Effect of dilutive securities:
Incremental common shares attributable to share-based payment arrangements under effects of dilutive securities item	0		0		2,064
Earnings (loss) per common share from continuing operations (Textuals) [Abstract]
Number of weighted-average shares excluded from computation of diluted earnings per common share	500		1,500
Convertible debentures [Member]
Effect of dilutive securities:
Incremental dilutive shares, Convertible debt	0		0		18

[1] For the years ended December 31, 2016 and December 31, 2015, 0.6 million and 1.7 million weighted-average nonvested restricted stock units, and 0.5 million and 1.5 million weighted-average stock options have been excluded from the computation of diluted earnings (loss) per common share as their inclusion would be antidilutive due to our loss from continuing operations attributable to The Williams Companies, Inc.

XML

EBPs Obligation Rollforward (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Pension Plan, Defined Benefit [Member]
Change in benefit obligation:
Benefit obligation at beginning of year	$ 1,464	$ 1,544
Service cost	54	59	$ 40
Interest cost	62	58	62
Plan participants' contributions	0	0
Benefits paid	(130)	(101)
Actuarial loss (gain)	20	(91)
Settlements	(4)	(5)
Net increase (decrease) in benefit obligation	2	(80)
Benefit obligation at end of year	1,466	1,464	1,544
Other Postretirement Benefits [Member]
Change in benefit obligation:
Benefit obligation at beginning of year	202	233
Service cost	1	2	2
Interest cost	8	9	10
Plan participants' contributions	2	2
Benefits paid	(15)	(13)
Actuarial loss (gain)	(1)	(31)
Settlements	0	0
Net increase (decrease) in benefit obligation	(5)	(31)
Benefit obligation at end of year	$ 197	$ 202	$ 233

XML

EBP Asset rollforward and B.S. classification (Details 1) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Pension Benefits [Member]
Change in plan assets:
Fair value of plan assets at beginning of year	$ 1,241	$ 1,293
Actual return on plan assets	82	(11)
Employer contributions	65	65
Plan participants' contributions	0	0
Benefits paid	(130)	(101)
Settlements	(4)	(5)
Net increase (decrease) in fair value of plan assets	13	(52)
Fair value of plan asets at end of year	1,254	1,241
Funded status - overfunded (underfunded)	(212)	(223)
Accumulated benefit obligation	1,440	1,432
Overfunded/(underfunded) status of our pension plans and other postretirement benefit plans
Current liabilities	(2)	(2)
Noncurrent liabilities	(210)	(221)
Amounts included in accumulated other comprehensive income (loss):
Prior service credit	0	0
Net actuarial loss	(535)	(544)
Amounts included in regulatory liabilities associated with Transco and Northwest Pipeline
Net regulatory assets (liabilities)	(21)	(8)
Other Postretirement Benefits [Member]
Change in plan assets:
Fair value of plan assets at beginning of year	201	208
Actual return on plan assets	13	(1)
Employer contributions	7	5
Plan participants' contributions	2	2
Benefits paid	(15)	(13)
Settlements	0	0
Net increase (decrease) in fair value of plan assets	7	(7)
Fair value of plan asets at end of year	208	201
Funded status - overfunded (underfunded)	11	(1)
Overfunded/(underfunded) status of our pension plans and other postretirement benefit plans
Current liabilities	(7)	(7)
Noncurrent assets	18	6
Amounts included in accumulated other comprehensive income (loss):
Prior service credit	5	11
Net actuarial loss	(18)	(18)
Amounts included in regulatory liabilities associated with Transco and Northwest Pipeline
Prior service credit	10	19
Net actuarial gain (loss)	8	6
Net regulatory assets (liabilities)	$ (94)	$ (78)

XML

EBP Net Periodic Benefit Cost & OCI (Details 2) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Pension Benefits [Member]
Components of net periodic benefit cost:
Service cost	$ 54	$ 59	$ 40
Interest cost	62	58	62
Expected return on plan assets	(85)	(75)	(76)
Amortization of prior service cost (credit)	0	0	0
Amortization of net actuarial loss	30	42	39
Net actuarial (gain) loss from settlements and curtailments	2	2	1
Reclassification to regulatory liability	0	0	0
Net periodic benefit cost	63	86	66
Other changes in plan assets and benefit obligations recognized in other comprehensive income (loss):
Net actuarial gain (loss)	(23)	5	(142)
Prior service (cost) credit	0	0	0
Amortization of prior service cost (credit) included in net periodic benefit cost	0	0	0
Amortization of net actuarial loss	30	42	39
Loss from settlements and curtailments	2	2	1
Other changes in plan assets and benefit obligations recognized in other comprehensive income (loss)	9	49	(102)
Amounts included in accumulated other comprehensive income (loss):
Prior service cost (credit) expected to be amortized in next fiscal year	0
Net actuarial (gain) loss expected to be amortized in next fiscal year	28
Other Postretirement Benefits [Member]
Components of net periodic benefit cost:
Service cost	1	2	2
Interest cost	8	9	10
Expected return on plan assets	(12)	(12)	(12)
Amortization of prior service cost (credit)	(15)	(17)	(20)
Amortization of net actuarial loss	0	2	0
Net actuarial (gain) loss from settlements and curtailments	0	0	(1)
Reclassification to regulatory liability	4	3	4
Net periodic benefit cost	(14)	(13)	(17)
Other changes in plan assets and benefit obligations recognized in other comprehensive income (loss):
Net actuarial gain (loss)	0	8	(18)
Prior service (cost) credit	0	0	(1)
Amortization of prior service cost (credit) included in net periodic benefit cost	(6)	(6)	(8)
Amortization of net actuarial loss	0	2	0
Loss from settlements and curtailments	0	0	1
Other changes in plan assets and benefit obligations recognized in other comprehensive income (loss)	(6)	4	(26)
Other changes in plan assets and benefit obligations recognized in regulatory (assets) liabilities:
Net actuarial gain (loss) recognized in regulatory liabilities (assets)	2	10	(2)
Amortization of prior service cost (credit) from regulatory assets (liabilities)	(9)	$ (11)	$ (12)
Amounts included in accumulated other comprehensive income (loss):
Prior service cost (credit) expected to be amortized in next fiscal year	(5)
Net actuarial (gain) loss expected to be amortized in next fiscal year	0
Amounts included in regulatory liabilities associated with Transco and Northwest Pipeline
Prior service cost (credit) expected to be amortized in next fiscal year	(8)
Net actuarial (gain) loss expected to be amortized in next fiscal year	$ 0

XML

EBP Key Assumptions (Details 3) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Pension Benefits [Member]
Weighted average assumptions utilized to determine benefit obligations
Discount rate	4.17%	4.38%
Rate of compensation increase	4.87%	4.88%
Weighted average assumptions utilized to determine net periodic benefit cost
Discount rate	4.37%	3.96%	4.68%
Expected long-term rate of return on plan assets	6.85%	6.38%	6.85%
Rate of compensation increase	4.88%	4.62%	4.56%
Other Postretirement Benefits [Member]
Weighted average assumptions utilized to determine benefit obligations
Discount rate	4.27%	4.50%
Weighted average assumptions utilized to determine net periodic benefit cost
Discount rate	4.50%	4.12%	4.80%
Expected long-term rate of return on plan assets	6.11%	5.70%	6.11%
One percentage point change in assumed health care cost trend rates effects
Effect on total of service and interest cost components, Point increase	$ 0
Effect on total of service and interest cost components, Point decrease	0
Effect on other postretirement benefit obligation, Point increase	6
Effect on other postretirement benefit obligation, Point decrease	$ (5)
Health care cost trend rate assumed for next fiscal year	7.50%
Direction and pattern of change for assumed health care cost trend rate	decreases
Ultimate health care cost trend rate	4.50%
Year that rate reaches ultimate trend rate	2025

XML

EBP Plan Assets (Details 4) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Maximum percentage of total stock portfolio invested in the common stock of any one corporation	5.00%
Maximum percentage of portfolio invested in fixed income securities of any one issuer with exception of bond index funds and U. S. government guaranteed and agency securities	5.00%
Fair value, plan assets, Level 1 to Level 2 transfers, amount	$ 0	$ 0
Fair value, plan assets, Level 2 to Level 1 transfers, amount	$ 0	0
Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Investment Redemption, Notice Period	30 days
Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Investment Redemption, Notice Period	10 days
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value, plan assets, Level 1 to Level 2 transfers, amount	$ 0
Fair value, plan assets, Level 2 to Level 1 transfers, amount	0
Fair values of plan assets
Total assets at fair value	$ 1,254	$ 1,241	$ 1,293
Pension Benefits [Member] | Equity securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan asset target allocation	60.00%
Pension Benefits [Member] | Fixed income securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan asset target allocation	40.00%
Weighted average duration of fixed income security portfolio	8 years	8 years
Pension Benefits [Member] | Plan assets within fair value hierarchy [Member]
Fair values of plan assets
Total assets at fair value	$ 489	$ 465
Pension Benefits [Member] | Cash management fund [Member]
Fair values of plan assets
Total assets at fair value	14	8
Pension Benefits [Member] | U.S. large cap [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	87	83
Pension Benefits [Member] | U.S. small cap [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	77	64
Pension Benefits [Member] | U.S. Treasury securities [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	68	65
Pension Benefits [Member] | Government and municipal bonds [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	10	8
Pension Benefits [Member] | Mortgage and asset-backed securities [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	80	87
Pension Benefits [Member] | Corporate bonds [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	148	145
Pension Benefits [Member] | Insurance company investment contracts and other [Member]
Fair values of plan assets
Total assets at fair value	5	5
Pension Benefits [Member] | Equities - U.S. large cap [Member] | Commingled investment funds - equities [Member]
Fair values of plan assets
Total assets at fair value	369	367
Pension Benefits [Member] | Equities - International small cap [Member] | Commingled investment funds - equities [Member]
Fair values of plan assets
Total assets at fair value	27	27
Pension Benefits [Member] | Equities - International emerging markets [Member] | Commingled investment funds - equities [Member]
Fair values of plan assets
Total assets at fair value	50	50
Pension Benefits [Member] | Equities - International developed markets [Member] | Commingled investment funds - equities [Member]
Fair values of plan assets
Total assets at fair value	149	153
Pension Benefits [Member] | Fixed income - U.S. long duration [Member] | Commingled investment funds - fixed income [Member]
Fair values of plan assets
Total assets at fair value	88	95
Pension Benefits [Member] | Fixed income - Corporate bonds [Member] | Commingled investment funds - fixed income [Member]
Fair values of plan assets
Total assets at fair value	82	84
Pension Benefits [Member] | Level 1 [Member]
Fair values of plan assets
Total assets at fair value	246	220
Pension Benefits [Member] | Level 1 [Member] | Cash management fund [Member]
Fair values of plan assets
Total assets at fair value	14	8
Pension Benefits [Member] | Level 1 [Member] | U.S. large cap [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	87	83
Pension Benefits [Member] | Level 1 [Member] | U.S. small cap [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	77	64
Pension Benefits [Member] | Level 1 [Member] | U.S. Treasury securities [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	68	65
Pension Benefits [Member] | Level 1 [Member] | Government and municipal bonds [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Pension Benefits [Member] | Level 1 [Member] | Mortgage and asset-backed securities [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Pension Benefits [Member] | Level 1 [Member] | Corporate bonds [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Pension Benefits [Member] | Level 1 [Member] | Insurance company investment contracts and other [Member]
Fair values of plan assets
Total assets at fair value	0	0
Pension Benefits [Member] | Level 2 [Member]
Fair values of plan assets
Total assets at fair value	243	245
Pension Benefits [Member] | Level 2 [Member] | Cash management fund [Member]
Fair values of plan assets
Total assets at fair value	0	0
Pension Benefits [Member] | Level 2 [Member] | U.S. large cap [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Pension Benefits [Member] | Level 2 [Member] | U.S. small cap [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Pension Benefits [Member] | Level 2 [Member] | U.S. Treasury securities [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Pension Benefits [Member] | Level 2 [Member] | Government and municipal bonds [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	10	8
Pension Benefits [Member] | Level 2 [Member] | Mortgage and asset-backed securities [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	80	87
Pension Benefits [Member] | Level 2 [Member] | Corporate bonds [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	148	145
Pension Benefits [Member] | Level 2 [Member] | Insurance company investment contracts and other [Member]
Fair values of plan assets
Total assets at fair value	5	5
Pension Benefits [Member] | Level 3 [Member]
Fair values of plan assets
Total assets at fair value	0	0
Pension Benefits [Member] | Level 3 [Member] | Cash management fund [Member]
Fair values of plan assets
Total assets at fair value	0	0
Pension Benefits [Member] | Level 3 [Member] | U.S. large cap [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Pension Benefits [Member] | Level 3 [Member] | U.S. small cap [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Pension Benefits [Member] | Level 3 [Member] | U.S. Treasury securities [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Pension Benefits [Member] | Level 3 [Member] | Government and municipal bonds [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Pension Benefits [Member] | Level 3 [Member] | Mortgage and asset-backed securities [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Pension Benefits [Member] | Level 3 [Member] | Corporate bonds [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Pension Benefits [Member] | Level 3 [Member] | Insurance company investment contracts and other [Member]
Fair values of plan assets
Total assets at fair value	$ 0	0
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Proportion of assets subjected to income tax	38.00%
Fair values of plan assets
Total assets at fair value	$ 208	$ 201	$ 208
Other Postretirement Benefits [Member] | Fixed income securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted average duration of fixed income security portfolio	8 years	7 years
Other Postretirement Benefits [Member] | Plan assets within fair value hierarchy [Member]
Fair values of plan assets
Total assets at fair value	$ 128	$ 122
Other Postretirement Benefits [Member] | Cash management fund [Member]
Fair values of plan assets
Total assets at fair value	11	11
Other Postretirement Benefits [Member] | U.S. large cap [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	24	37
Other Postretirement Benefits [Member] | U.S. small cap [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	15	20
Other Postretirement Benefits [Member] | International developed markets large cap growth [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	5	10
Other Postretirement Benefits [Member] | Emerging markets growth [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value		1
Other Postretirement Benefits [Member] | U.S. Treasury securities [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	7	7
Other Postretirement Benefits [Member] | Government and municipal bonds [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	1	12
Other Postretirement Benefits [Member] | Mortgage and asset-backed securities [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	8	9
Other Postretirement Benefits [Member] | Corporate bonds [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	15	15
Other Postretirement Benefits [Member] | Equities - U.S. large cap [Member] | Commingled investment funds - equities [Member]
Fair values of plan assets
Total assets at fair value	38	37
Other Postretirement Benefits [Member] | Equities - International small cap [Member] | Commingled investment funds - equities [Member]
Fair values of plan assets
Total assets at fair value	3	3
Other Postretirement Benefits [Member] | Equities - International emerging markets [Member] | Commingled investment funds - equities [Member]
Fair values of plan assets
Total assets at fair value	5	5
Other Postretirement Benefits [Member] | Equities - International developed markets [Member] | Commingled investment funds - equities [Member]
Fair values of plan assets
Total assets at fair value	16	16
Other Postretirement Benefits [Member] | Fixed income - U.S. long duration [Member] | Commingled investment funds - fixed income [Member]
Fair values of plan assets
Total assets at fair value	9	10
Other Postretirement Benefits [Member] | Fixed income - Corporate bonds [Member] | Commingled investment funds - fixed income [Member]
Fair values of plan assets
Total assets at fair value	9	8
Other Postretirement Benefits [Member] | Mutual fund - Municipal bonds [Member]
Fair values of plan assets
Total assets at fair value	42
Other Postretirement Benefits [Member] | Level 1 [Member]
Fair values of plan assets
Total assets at fair value	99	76
Other Postretirement Benefits [Member] | Level 1 [Member] | Cash management fund [Member]
Fair values of plan assets
Total assets at fair value	11	11
Other Postretirement Benefits [Member] | Level 1 [Member] | U.S. large cap [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	24	37
Other Postretirement Benefits [Member] | Level 1 [Member] | U.S. small cap [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	15	20
Other Postretirement Benefits [Member] | Level 1 [Member] | International developed markets large cap growth [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	0	1
Other Postretirement Benefits [Member] | Level 1 [Member] | Emerging markets growth [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value		0
Other Postretirement Benefits [Member] | Level 1 [Member] | U.S. Treasury securities [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	7	7
Other Postretirement Benefits [Member] | Level 1 [Member] | Government and municipal bonds [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Other Postretirement Benefits [Member] | Level 1 [Member] | Mortgage and asset-backed securities [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Other Postretirement Benefits [Member] | Level 1 [Member] | Corporate bonds [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Other Postretirement Benefits [Member] | Level 1 [Member] | Mutual fund - Municipal bonds [Member]
Fair values of plan assets
Total assets at fair value	42
Other Postretirement Benefits [Member] | Level 2 [Member]
Fair values of plan assets
Total assets at fair value	29	46
Other Postretirement Benefits [Member] | Level 2 [Member] | Cash management fund [Member]
Fair values of plan assets
Total assets at fair value	0	0
Other Postretirement Benefits [Member] | Level 2 [Member] | U.S. large cap [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Other Postretirement Benefits [Member] | Level 2 [Member] | U.S. small cap [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Other Postretirement Benefits [Member] | Level 2 [Member] | International developed markets large cap growth [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	5	9
Other Postretirement Benefits [Member] | Level 2 [Member] | Emerging markets growth [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value		1
Other Postretirement Benefits [Member] | Level 2 [Member] | U.S. Treasury securities [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Other Postretirement Benefits [Member] | Level 2 [Member] | Government and municipal bonds [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	1	12
Other Postretirement Benefits [Member] | Level 2 [Member] | Mortgage and asset-backed securities [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	8	9
Other Postretirement Benefits [Member] | Level 2 [Member] | Corporate bonds [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	15	15
Other Postretirement Benefits [Member] | Level 2 [Member] | Mutual fund - Municipal bonds [Member]
Fair values of plan assets
Total assets at fair value	0
Other Postretirement Benefits [Member] | Level 3 [Member]
Fair values of plan assets
Total assets at fair value	0	0
Other Postretirement Benefits [Member] | Level 3 [Member] | Cash management fund [Member]
Fair values of plan assets
Total assets at fair value	0	0
Other Postretirement Benefits [Member] | Level 3 [Member] | U.S. large cap [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Other Postretirement Benefits [Member] | Level 3 [Member] | U.S. small cap [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Other Postretirement Benefits [Member] | Level 3 [Member] | International developed markets large cap growth [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Other Postretirement Benefits [Member] | Level 3 [Member] | Emerging markets growth [Member] | Equity securities [Member]
Fair values of plan assets
Total assets at fair value		0
Other Postretirement Benefits [Member] | Level 3 [Member] | U.S. Treasury securities [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Other Postretirement Benefits [Member] | Level 3 [Member] | Government and municipal bonds [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Other Postretirement Benefits [Member] | Level 3 [Member] | Mortgage and asset-backed securities [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	0	0
Other Postretirement Benefits [Member] | Level 3 [Member] | Corporate bonds [Member] | Fixed income securities [Member]
Fair values of plan assets
Total assets at fair value	0	$ 0
Other Postretirement Benefits [Member] | Level 3 [Member] | Mutual fund - Municipal bonds [Member]
Fair values of plan assets
Total assets at fair value	$ 0

XML

EBP Benefit Pymts & Defined Contribution Plans (Details 5) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Benefit Plan Disclosure [Line Items]
Employer's contributions charged to expense under defined contribution plans	$ 36	$ 39	$ 39
Other Postretirement Benefits [Member]
Benefit Plan Disclosure [Line Items]
Expected total plans contribution, approximate	7
Expected benefit payments
2017	13
2018	13
2019	13
2020	13
2021	13
2022-2026	62
Pension Benefits [Member]
Benefit Plan Disclosure [Line Items]
Expected total plans contribution, approximate	62
Expected benefit payments
2017	99
2018	103
2019	103
2020	106
2021	111
2022-2026	562
Nonqualified Pension Benefits - Supplemental Employee Retirement Benefits [Member]
Benefit Plan Disclosure [Line Items]
Expected total plans contribution, approximate	2
Tax-qualified Pension Benefits [Member]
Benefit Plan Disclosure [Line Items]
Expected total plans contribution, approximate	$ 60

XML

Property, Plant, and Equipment (Details PPE) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Property, Plant, and Equipment
Property, plant, and equipment, at cost		$ 38,912	$ 39,039
Accumulated depreciation and amortization		(10,484)	(9,460)
Property, plant, and equipment - net		28,428	29,579
Depreciation and amortization expenses		1,407	1,382	$ 967
Nonregulated [Member] | Natural gas gathering and processing facilities [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		$ 20,413	20,789
Nonregulated [Member] | Natural gas gathering and processing facilities [Member] | Minimum [Member]
Property, Plant, and Equipment
Property, Plant and Equipment, Useful Life	[1]	5 years
Nonregulated [Member] | Natural gas gathering and processing facilities [Member] | Maximum [Member]
Property, Plant, and Equipment
Property, Plant and Equipment, Useful Life	[1]	40 years
Nonregulated [Member] | Construction in Progress [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		$ 412	1,366
Nonregulated [Member] | Other Capitalized Property Plant and Equipment [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		$ 2,202	2,170
Nonregulated [Member] | Other Capitalized Property Plant and Equipment [Member] | Minimum [Member]
Property, Plant, and Equipment
Property, Plant and Equipment, Useful Life	[1]	2 years
Nonregulated [Member] | Other Capitalized Property Plant and Equipment [Member] | Maximum [Member]
Property, Plant, and Equipment
Property, Plant and Equipment, Useful Life	[1]	45 years
Regulated [Member] | Natural gas transmission facilities [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		$ 12,692	12,189
Regulated [Member] | Natural gas transmission facilities [Member] | Minimum [Member]
Property, Plant, and Equipment
Property, Plant, and Equipment, Depreciation Rate	[1]	1.20%
Regulated [Member] | Natural gas transmission facilities [Member] | Maximum [Member]
Property, Plant, and Equipment
Property, Plant, and Equipment, Depreciation Rate	[1]	6.97%
Regulated [Member] | Construction in Progress [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		$ 1,603	941
Regulated [Member] | Other Capitalized Property Plant and Equipment [Member]
Property, Plant, and Equipment
Property, plant, and equipment, at cost		$ 1,590	1,584
Regulated [Member] | Other Capitalized Property Plant and Equipment [Member] | Minimum [Member]
Property, Plant, and Equipment
Property, Plant and Equipment, Useful Life	[1]	5 years
Property, Plant, and Equipment, Depreciation Rate	[1]	1.35%
Regulated [Member] | Other Capitalized Property Plant and Equipment [Member] | Maximum [Member]
Property, Plant, and Equipment
Property, Plant and Equipment, Useful Life	[1]	45 years
Property, Plant, and Equipment, Depreciation Rate	[1]	33.33%
Regulated [Member] | Acquisition Adjustment Of Regulated Facilities [Member]
Property, Plant, and Equipment
Property, Plant and Equipment, Plant Acquisition Adjustments for Intangible Utility Plants		$ 665	$ 706
Period of straight-line amortization		40 years

[1] Estimated useful life and depreciation rates are presented as of December 31, 2016. Depreciation rates and estimated useful lives for regulated assets are prescribed by the FERC.

XML

Property, Plant, and Equipment (Details ARO) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015
Asset Retirement Obligations
Asset Retirement Obligations, Noncurrent		$ 801	$ 858
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance		915	831
Liabilities incurred		24	42
Liabilities settled		(8)	(3)
Accretion expense		69	60
Revisions (1)	[1]	(138)	(15)
Ending balance		862	$ 915
Asset Retirement Obligation Costs [Member]
Unusual or Infrequent Item [Line Items]
Transco's annual funding commitment for ARO		$ 36

[1] Several factors are considered in the annual review process, including inflation rates, current estimates for removal cost, market risk premiums, discount rates, and the estimated remaining useful life of the assets. The 2016 revisions reflect changes in removal cost estimates, increases in the estimated remaining useful life of certain assets, and decreases in the inflation rate and discount rates used in the annual review process. The 2015 revisions reflect changes in removal cost estimates and the estimated remaining useful life of assets, a decrease in the inflation rate, and increases in the discount rates used in the annual review process.

XML

Goodwill (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Goodwill [Line Items]
Impairment of goodwill	$ (1,098)	$ 0	$ (1,098)	$ 0
Williams Partners [Member]
Goodwill [Line Items]
Goodwill	$ 47	$ 47	47	$ 1,120
Goodwill, purchase accounting adjustments			25
Impairment of goodwill			$ (1,098)

XML

Other Intangible Assets (Details) - USD ($) $ in Millions	1 Months Ended	6 Months Ended	12 Months Ended
	May 31, 2015	Jul. 02, 2014	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Finite-Lived Intangible Assets [Line Items]
Amortization of Intangible Assets			$ 356	$ 353	$ 209
Finite-Lived Intangible Assets, Amortization Expense, Next Twelve Months			356
Finite-Lived Intangible Assets, Amortization Expense, Year Two			356
Finite-Lived Intangible Assets, Amortization Expense, Year Three			356
Finite-Lived Intangible Assets, Amortization Expense, Year Four			356
Finite-Lived Intangible Assets, Amortization Expense, Year Five			356
Contractual customer relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross			10,635	10,633
Finite-Lived Intangible Assets, Accumulated Amortization			$ (1,019)	$ (663)
Access Midstream Partners Acquisition [Member]
Finite-Lived Intangible Assets [Line Items]
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life		30 years
Acquired Finite-lived Intangible Asset, Weighted-Average Period before Renewal or Extension		17 years
Eagle Ford Gathering System [Member]
Finite-Lived Intangible Assets [Line Items]
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	30 years
Acquired Finite-lived Intangible Asset, Weighted-Average Period before Renewal or Extension	10 years

XML

Accrued Liabilities Table (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Accrued Liabilities, Current [Abstract]
Deferred income	$ 338	$ 94
Interest on debt	310	284
Employee costs	223	215
Refundable deposits	160	0
Special distribution repayable to Gulfstream (See Note 6 - Investing Activities)	0	149
Asset retirement obligations	61	57
Other, including other loss contingencies	356	279
Other accrued liabilities	$ 1,448	$ 1,078

XML

Accrued Liabilities Accrued Liabilities Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016 USD ($)
Accrued Liabilities, Current [Abstract]
Refundable deposits, contracted	$ 240
Refundable deposits, proceeds	$ 160

XML

Long-Term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2016		Jun. 15, 2016	Apr. 15, 2016	Jan. 22, 2016	Dec. 31, 2015		Apr. 15, 2015	Mar. 03, 2015
Long-term Debt
Capital lease obligations	$ 0					$ 1
Debt issuance costs	(119)					(123)
Net unamortized debt premium (discount)	88					110
Total long-term debt, including current portion	23,409					23,988
Long-term debt due within one year	(785)					(176)
Long-term debt	22,624					23,812
Transcontinental Gas Pipe Line Company, LLC [Member] | 6.4% Senior Unsecured Notes due 2016 [Member]
Long-term Debt
Long-term debt	0					$ 200	[1]
Long-term debt interest rate				6.40%		6.40%
Transcontinental Gas Pipe Line Company, LLC [Member] | 6.05% Senior Unsecured Notes due 2018 [Member]
Long-term Debt
Long-term debt	$ 250					$ 250
Long-term debt interest rate	6.05%
Transcontinental Gas Pipe Line Company, LLC [Member] | 7.08% Debentures due 2026 [Member]
Long-term Debt
Long-term debt	$ 8					8
Long-term debt interest rate	7.08%
Transcontinental Gas Pipe Line Company, LLC [Member] | 7.25% Debentures due 2026 [Member]
Long-term Debt
Long-term debt	$ 200					200
Long-term debt interest rate	7.25%
Transcontinental Gas Pipe Line Company, LLC [Member] | 7.85% Senior Unsecured Notes Due 2026 [Member]
Long-term Debt
Long-term debt	$ 1,000					0
Long-term debt interest rate	7.85%				7.85%
Transcontinental Gas Pipe Line Company, LLC [Member] | 5.4% Senior Unsecured Notes due 2041 [Member]
Long-term Debt
Long-term debt	$ 375					375
Long-term debt interest rate	5.40%
Transcontinental Gas Pipe Line Company, LLC [Member] | 4.45% Senior Unsecured Notes due 2042 [Member]
Long-term Debt
Long-term debt	$ 400					400
Long-term debt interest rate	4.45%
Northwest Pipeline LLC [Member] | 7% Senior Unsecured Notes due 2016 [Member]
Long-term Debt
Long-term debt	$ 0					$ 175
Long-term debt interest rate			7.00%			7.00%
Northwest Pipeline LLC [Member] | 5.95% Senior Unsecured Notes due 2017 [Member]
Long-term Debt
Long-term debt	$ 185					$ 185
Long-term debt interest rate	5.95%
Northwest Pipeline LLC [Member] | 6.05% Senior Unsecured Notes due 2018 [Member]
Long-term Debt
Long-term debt	$ 250					250
Long-term debt interest rate	6.05%
Northwest Pipeline LLC [Member] | 7.125% Debentures due 2025 [Member]
Long-term Debt
Long-term debt	$ 85					85
Long-term debt interest rate	7.125%
Williams Partners L.P. [Member]
Long-term Debt
Credit facility loans	$ 0	[2]				1,310
Williams Partners L.P. [Member] | 7.25% Senior Unsecured Notes due 2017 [Member]
Long-term Debt
Long-term debt	$ 600					600
Long-term debt interest rate	7.25%
Williams Partners L.P. [Member] | 5.25% Senior Unsecured Notes due 2020 [Member]
Long-term Debt
Long-term debt	$ 1,500					1,500
Long-term debt interest rate	5.25%
Williams Partners L.P. [Member] | 4.125% Senior Unsecured Notes due 2020 [Member]
Long-term Debt
Long-term debt	$ 600					600
Long-term debt interest rate	4.125%
Williams Partners L.P. [Member] | 4% Senior Unsecured Notes due 2021 [Member]
Long-term Debt
Long-term debt	$ 500					500
Long-term debt interest rate	4.00%
Williams Partners L.P. [Member] | 3.6% Senior Unsecured Notes due 2022 [Member]
Long-term Debt
Long-term debt	$ 1,250					1,250
Long-term debt interest rate	3.60%								3.60%
Williams Partners L.P. [Member] | 5.875% Senior Unsecured Notes due 2021 [Member]
Long-term Debt
Long-term debt interest rate								5.875%
Williams Partners L.P. [Member] | 3.35% Senior Unsecured Notes due 2022 [Member]
Long-term Debt
Long-term debt	$ 750					750
Long-term debt interest rate	3.35%
Williams Partners L.P. [Member] | 6.125% Senior Unsecured Notes due 2022 [Member]
Long-term Debt
Long-term debt	$ 750					750
Long-term debt interest rate	6.125%
Williams Partners L.P. [Member] | 4.5% Senior Unsecured Notes due 2023 [Member]
Long-term Debt
Long-term debt	$ 600					600
Long-term debt interest rate	4.50%
Williams Partners L.P. [Member] | 4.875% Senior Unsecured Notes due 2023 [Member]
Long-term Debt
Long-term debt	$ 1,400					1,400
Long-term debt interest rate	4.875%
Williams Partners L.P. [Member] | 4.3% Senior Unsecured Notes Due 2024 [Member]
Long-term Debt
Long-term debt	$ 1,000					1,000
Long-term debt interest rate	4.30%
Williams Partners L.P. [Member] | 4.875% Senior Unsecured Notes due 2024 [Member]
Long-term Debt
Long-term debt	$ 750					750
Long-term debt interest rate	4.875%
Williams Partners L.P. [Member] | 3.9% Senior Unsecured Notes due 2025 [Member]
Long-term Debt
Long-term debt	$ 750					750
Long-term debt interest rate	3.90%
Williams Partners L.P. [Member] | 4% Senior Unsecured Notes due 2025 [Member]
Long-term Debt
Long-term debt	$ 750					750
Long-term debt interest rate	4.00%								4.00%
Williams Partners L.P. [Member] | 6.3% Senior Unsecured Notes due 2040 [Member]
Long-term Debt
Long-term debt	$ 1,250					1,250
Long-term debt interest rate	6.30%
Williams Partners L.P. [Member] | 5.8% Senior Unsecured Notes due 2043 [Member]
Long-term Debt
Long-term debt	$ 400					400
Long-term debt interest rate	5.80%
Williams Partners L.P. [Member] | 5.4% Senior Unsecured Notes Due 2044 [Member]
Long-term Debt
Long-term debt	$ 500					500
Long-term debt interest rate	5.40%
Williams Partners L.P. [Member] | 4.9% Senior Unsecured Notes due 2045 [Member]
Long-term Debt
Long-term debt	$ 500					500
Long-term debt interest rate	4.90%
Williams Partners L.P. [Member] | 5.1% Senior Unsecured Notes due 2045 [Member]
Long-term Debt
Long-term debt	$ 1,000					1,000
Long-term debt interest rate	5.10%								5.10%
Williams Partners L.P. [Member] | Variable Interest Term Loan due 2018 [Member]
Long-term Debt
Long-term debt	$ 850					850
Long-term debt interest rate	2.50%
The Williams Companies, Inc. [Member]
Long-term Debt
Credit facility loans	$ 775					650
The Williams Companies, Inc. [Member] | 7.875% Senior Unsecured Notes due 2021 [Member]
Long-term Debt
Long-term debt	$ 371					371
Long-term debt interest rate	7.875%
The Williams Companies, Inc. [Member] | 3.7% Senior Unsecured Notes due 2023 [Member]
Long-term Debt
Long-term debt	$ 850					850
Long-term debt interest rate	3.70%
The Williams Companies, Inc. [Member] | 4.55% Senior Unsecured Notes due 2024 [Member]
Long-term Debt
Long-term debt	$ 1,250					1,250
Long-term debt interest rate	4.55%
The Williams Companies, Inc. [Member] | 7.5% Debentures due 2031 [Member]
Long-term Debt
Long-term debt	$ 339					339
Long-term debt interest rate	7.50%
The Williams Companies, Inc. [Member] | 7.75% Senior Unsecured Notes due 2031 [Member]
Long-term Debt
Long-term debt	$ 252					252
Long-term debt interest rate	7.75%
The Williams Companies, Inc. [Member] | 8.75% Senior Unsecured Notes due 2032 [Member]
Long-term Debt
Long-term debt	$ 445					445
Long-term debt interest rate	8.75%
The Williams Companies, Inc. [Member] | 5.75% Senior Unsecured Notes due 2044 [Member]
Long-term Debt
Long-term debt	$ 650					650
Long-term debt interest rate	5.75%
The Williams Companies, Inc. [Member] | Various - 5.5% to 10.25% Senior Unsecured Notes and Debentures due 2019 to 2033 [Member]
Long-term Debt
Long-term debt	$ 55					$ 55
The Williams Companies, Inc. [Member] | Various - 5.5% to 10.25% Senior Unsecured Notes and Debentures due 2019 to 2033 Minimum Interest Rate [Member]
Long-term Debt
Long-term debt interest rate	5.50%
The Williams Companies, Inc. [Member] | Various - 5.5% to 10.25% Senior Unsecured Notes and Debentures due 2019 to 2033 Maximum Interest Rate [Member]
Long-term Debt
Long-term debt interest rate	10.25%

[1] Presented as long-term debt at December 31, 2015, due to Transco’s intent and ability to refinance.

[2] In managing our available liquidity, we do not expect a maximum outstanding amount in excess of the capacity of our credit facility inclusive of any outstanding amounts under our commercial paper program.

XML

Long-Term Debt Maturities (Details) $ in Millions	Dec. 31, 2016 USD ($)
Aggregate minimum maturities of long-term debt
2017	$ 785
2018	1,350
2019	32
2020	2,896
2021	$ 871

XML

Long-Term Debt Issuances and Retirements (Details) - USD ($) $ in Millions						1 Months Ended	12 Months Ended
	Feb. 01, 2017	Jun. 15, 2016	Apr. 15, 2016	Apr. 15, 2015	Feb. 15, 2015	Jan. 25, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Jan. 22, 2016	Dec. 23, 2015	Mar. 03, 2015
Debt Instrument [Line Items]
Repayments of Long-term Debt							$ 7,091	$ 6,516	$ 1,828
The Williams Companies, Inc. [Member] | 4.55% Senior Unsecured Notes due 2024 [Member]
Debt Instrument [Line Items]
Long-term debt interest rate							4.55%
The Williams Companies, Inc. [Member] | 5.75% Senior Unsecured Notes due 2044 [Member]
Debt Instrument [Line Items]
Long-term debt interest rate							5.75%
Williams Partners L.P. [Member] | Variable interest Rate [Member]
Debt Instrument [Line Items]
Long-term debt face amount											$ 850
Long-term debt interest rate							2.50%
Williams Partners L.P. [Member] | 3.8% Senior Unsecured Notes due 2015 [Member]
Debt Instrument [Line Items]
Long-term debt retired					$ 750
Long-term debt interest rate					3.80%
Williams Partners L.P. [Member] | 3.9% Senior Unsecured Notes due 2025 [Member]
Debt Instrument [Line Items]
Long-term debt interest rate							3.90%
Williams Partners L.P. [Member] | 4.9% Senior Unsecured Notes due 2045 [Member]
Debt Instrument [Line Items]
Long-term debt interest rate							4.90%
Williams Partners L.P. [Member] | 4.3% Senior Unsecured Notes Due 2024 [Member]
Debt Instrument [Line Items]
Long-term debt interest rate							4.30%
Williams Partners L.P. [Member] | 5.4% Senior Unsecured Notes Due 2044 [Member]
Debt Instrument [Line Items]
Long-term debt interest rate							5.40%
Williams Partners L.P. [Member] | 4.5% Senior Unsecured Notes due 2023 [Member]
Debt Instrument [Line Items]
Long-term debt interest rate							4.50%
Williams Partners L.P. [Member] | 5.8% Senior Unsecured Notes due 2043 [Member]
Debt Instrument [Line Items]
Long-term debt interest rate							5.80%
Williams Partners L.P. [Member] | 5.875% Senior Unsecured Notes due 2021 [Member]
Debt Instrument [Line Items]
Long-term debt retired				$ 750
Long-term debt interest rate				5.875%
Long-term Debt, Current Maturities				$ 797
Repayments of Long-term Debt				$ 783
Williams Partners L.P. [Member] | 3.6% Senior Unsecured Notes due 2022 [Member]
Debt Instrument [Line Items]
Long-term debt face amount												$ 1,250
Long-term debt interest rate							3.60%					3.60%
Williams Partners L.P. [Member] | 4% Senior Unsecured Notes due 2025 [Member]
Debt Instrument [Line Items]
Long-term debt face amount												$ 750
Long-term debt interest rate							4.00%					4.00%
Williams Partners L.P. [Member] | 5.1% Senior Unsecured Notes due 2045 [Member]
Debt Instrument [Line Items]
Long-term debt face amount												$ 1,000
Long-term debt interest rate							5.10%					5.10%
Williams Partners L.P. [Member] | 6.125% Senior Unsecured Notes due 2022 [Member]
Debt Instrument [Line Items]
Long-term debt interest rate							6.125%
Williams Partners L.P. [Member] | 6.125% Senior Unsecured Notes due 2022 [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Long-term debt retired						$ 750
Long-term debt interest rate						6.125%
Williams Partners L.P. [Member] | 7.25% Senior Unsecured Notes due 2017 [Member]
Debt Instrument [Line Items]
Long-term debt interest rate							7.25%
Williams Partners L.P. [Member] | 7.25% Senior Unsecured Notes due 2017 [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Long-term debt retired	$ 600
Long-term debt interest rate	7.25%
Northwest Pipeline LLC [Member] | 7% Senior Unsecured Notes due 2016 [Member]
Debt Instrument [Line Items]
Long-term debt retired		$ 175
Long-term debt interest rate		7.00%						7.00%
Transcontinental Gas Pipe Line Company, LLC [Member] | 7.85% Senior Unsecured Notes Due 2026 [Member]
Debt Instrument [Line Items]
Long-term debt face amount										$ 1,000
Long-term debt interest rate							7.85%			7.85%
Transcontinental Gas Pipe Line Company, LLC [Member] | 6.4% Senior Unsecured Notes due 2016 [Member]
Debt Instrument [Line Items]
Long-term debt retired			$ 200
Long-term debt interest rate			6.40%					6.40%

XML

Credit Facilities and Commercial Paper (Details) $ in Millions			12 Months Ended
	Dec. 18, 2015	Feb. 02, 2015 USD ($)	Dec. 31, 2016 USD ($)		Feb. 20, 2017 USD ($)	Dec. 31, 2015 USD ($)	Dec. 23, 2015 USD ($)	Aug. 26, 2015 USD ($)
Credit Facility and Commercial Paper [Line Items]
Commercial paper, outstanding			$ 93			$ 499
Williams Companies, Inc. [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity		$ 1,500	1,500
Credit facility, loans outstanding			775			650
Additional amount by which credit facility can be increased		$ 500
Maximum ratio of debt to EBITDA		5
Maximum ratio of debt to EBITDA after acquisition		5.5
Williams Companies, Inc. [Member] | Subsequent Event [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, loans outstanding					$ 235
Williams Companies, Inc. [Member] | Swingline Loan [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity		$ 50
Williams Companies, Inc. [Member] | Letters of credit [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity		675
Williams Companies, Inc. [Member] | Letters Of Credit Under Certain Bilateral Bank Agreements [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, letters of credit outstanding			13
Williams Partners L.P. [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity		3,500	3,500	[1]
Credit facility, loans outstanding			0	[1]		1,310
Additional amount by which credit facility can be increased		500
Williams Partners L.P. [Member] | Subsequent Event [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, loans outstanding					$ 0
Williams Partners L.P. [Member] | Rate addition to federal funds effective rate [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, basis spread on variable rate	0.50%
Williams Partners L.P. [Member] | Rate addition to London interbank offered rate (LIBOR) [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, basis spread on variable rate	1.00%
Williams Partners L.P. [Member] | Swingline Loan [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity		150
Williams Partners L.P. [Member] | Commercial paper [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity		3,000
Commercial paper, outstanding			$ 93			$ 499
Commercial paper, weighted average interest rate			1.06%			0.92%
Commercial paper, maximum maturity			397 days
Williams Partners L.P. [Member] | Letters of credit [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity		1,125
Williams Partners L.P. [Member] | Letters Of Credit Under Certain Bilateral Bank Agreements [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, letters of credit outstanding			$ 1
Williams Partners L.P. [Member] | Short-term facility [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity							$ 150	$ 1,000
Transcontinental Gas Pipe Line Company, LLC [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity		500
Maximum ratio of debt to capitalization	65.00%
Northwest Pipeline LLC [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity		$ 500
Maximum ratio of debt to capitalization	65.00%
Acquisition [Member] | Williams Partners L.P. [Member]
Credit Facility and Commercial Paper [Line Items]
Maximum ratio of debt to EBITDA	5.5
Mar 2017 & Subsequent Quarters [Member] | Williams Partners L.P. [Member]
Credit Facility and Commercial Paper [Line Items]
Maximum ratio of debt to EBITDA	5.00
Sep & Dec 2016 [Member] | Williams Partners L.P. [Member]
Credit Facility and Commercial Paper [Line Items]
Maximum ratio of debt to EBITDA	5.50
Dec 2015, Mar & Jun 2016 [Member] | Williams Partners L.P. [Member]
Credit Facility and Commercial Paper [Line Items]
Maximum ratio of debt to EBITDA	5.75
Variable Interest Term Loan due 2018 [Member] | Williams Partners L.P. [Member]
Credit Facility and Commercial Paper [Line Items]
Debt Instrument, Face Amount							$ 850

[1] In managing our available liquidity, we do not expect a maximum outstanding amount in excess of the capacity of our credit facility inclusive of any outstanding amounts under our commercial paper program.

XML

Cash Payments For Interest (Net of Amounts Capitalized) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Debt Disclosure [Abstract]
Cash payments for interest (net of amounts capitalized)	$ 1,152	$ 1,023	$ 681

XML

Restricted Net Assets of Subsidiaries (Details) $ in Billions	Dec. 31, 2016 USD ($)
Debt Disclosure [Abstract]
Amount of restricted net assets for consolidated and unconsolidated subsidiaries	$ 13
Restricted net assets threshold	25.00%

XML

Leases-Lessee (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Future minimum annual rentals under noncancelable operating leases
2017	$ 62
2018	58
2019	51
2020	46
2021	35
Thereafter	90
Total	342
Operating leases [Abstract]
Total rent expense	$ 64	$ 69	$ 62

XML

Stockholders' Equity (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions				1 Months Ended	12 Months Ended
	Feb. 20, 2017	Feb. 01, 2017	Jun. 23, 2014	Jan. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Jan. 13, 2017
Stockholders' Equity (Textuals) [Abstract]
Common Stock, Dividends, Per Share, Declared					$ 1.6800	$ 2.45	$ 1.9575
Stock Issued During Period, Shares, New Issues			61,000
Equity Issuance, Per Share Amount			$ 57.00
Common Units Sold In Offering			8,000
Proceeds from Issuance of Common Stock			$ 3,378		$ 9	$ 27	$ 3,416
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total, Beginning Balance				$ (339)	(442)
Other comprehensive income (loss)					172	(171)	(176)
Total, Ending Balance					(339)	(442)
Accumulated Other Comprehensive Income (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total, Beginning Balance				(339)	(442)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax					12
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax					91
Other comprehensive income (loss)					103	(101)	$ (157)
Total, Ending Balance					(339)	(442)
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total, Beginning Balance				0	(1)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax					2
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax					(1)
Other comprehensive income (loss)					1
Total, Ending Balance					0	(1)
Foreign currency translation [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total, Beginning Balance				(2)	(103)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax					25
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax					76
Other comprehensive income (loss)					101
Total, Ending Balance					(2)	(103)
Accumulated Defined Benefit Plans Adjustment [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total, Beginning Balance				$ (337)	(338)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax					(15)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax					16
Other comprehensive income (loss)					1
Total, Ending Balance					$ (337)	$ (338)
Subsequent Event [Member]
Stockholders' Equity (Textuals) [Abstract]
Common Stock, Dividends, Per Share, Declared	$ 0.30
Stock Issued During Period, Shares, New Issues		9,750		65,000
Equity Issuance, Per Share Amount								$ 29.00
Proceeds from Issuance of Common Stock		$ 2,100

XML

Stockholders' Equity Stockholders' Equity Reclassifications from AOCI (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Product sales	$ 2,328	$ 2,196	$ 3,521
Total cash flow hedges, energy commodity contract reclassifications	(375)	(1,713)	3,584
Provision (benefit) for income taxes	(25)	(399)	1,249
Net Of Tax Reclassifications Of Pension And Foreign Currency Adjustments	(350)	(1,314)	2,339
Net Income (Loss) Attributable to Noncontrolling Interest	74	$ (743)	$ 225
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(1)
Accumulated Defined Benefit Plans Adjustment [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	16
Foreign currency translation [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	76
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Reclassification from Accumulated Other Comprehensive Income, Current Period, before Tax	178
Provision (benefit) for income taxes	(45)
Net Of Tax Reclassifications Of Pension And Foreign Currency Adjustments	133
Net Income (Loss) Attributable to Noncontrolling Interest	(42)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	91
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Total cash flow hedges, energy commodity contract reclassifications	(3)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Defined Benefit Plans Adjustment [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior service (credit) inlcuded in net periodic benefit cost	(6)
Amortization of actuarial (gain) loss included in net periodic benefit cost	32
Other Comprehensive (Income) Loss, Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, before Tax	26
Reclassification out of Accumulated Other Comprehensive Income [Member] | Foreign currency translation [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Reclassification Adjustment from AOCI, Realized upon Sale or Liquidation, before Tax	155
Reclassification out of Accumulated Other Comprehensive Income [Member] | Energy Commodity Contract [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Product sales	$ (3)

XML

Equity-Based Compensation (Details) - USD ($)		12 Months Ended
		Dec. 31, 2016		Dec. 31, 2015	Dec. 31, 2014	May 22, 2014	May 20, 2010	May 17, 2007
Williams Companies Incentive Plan [Member]
Equity-Based Compensation (Textuals) [Abstract]
Shares reserved for issuance		27,000,000				10,000,000	11,000,000	19,000,000
Shares available for future grants		17,000,000
Equity-based compensation expense		$ 53,000,000		$ 56,000,000	$ 44,000,000
Tax benefit from equity-based compensation expense		20,000,000		$ 21,000,000	17,000,000
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized [Abstract]
Unrecognized equity-based compensation expense		67,000,000
Estimated forfeitures under employee equity-based awards		$ 2,000,000
Unrecognized equity-based compensation expense, Weighted-average period of recognition in years		1 year 11 months
Williams Companies Incentive Plan [Member] | Stock options [Member]
Equity-Based Compensation (Textuals) [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period		3 years
Share-based Compensation Arrangement by Share-based Payment Award, Expiration Period		10 years
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized [Abstract]
Unrecognized equity-based compensation expense - Stock Options		$ 5,000,000
Rollforward of stock option activity and related information
Options Outstanding, Beginning Balance		5,700,000
Options, Granted		900,000
Options, Exercised		(300,000)
Options, Cancelled		(100,000)
Options Outstanding, Ending Balance		6,200,000		5,700,000
Options Exercisable at Period End		5,000,000
Options, Aggregate Intrinsic Value, Ending Balance		$ 28,000,000
Options, Aggregate Intrinsic Value, Exercisable at Period End		23,000,000
Total intrinsic value of options exercised		2,000,000		$ 37,000,000	48,000,000
Tax benefits realized on options exercised		1,000,000		13,000,000	18,000,000
Cash received from the exercise of options		$ 4,000,000		$ 20,000,000	$ 31,000,000
Stock Options Outstanding, Weighted Average Remaining Contractual Life		5 years 6 months
Stock Options Exercisable, Weighted Average Remaining Contractual Life		4 years 2 months
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price [Abstract]
Options, Weighted Average Exercise Price, Beginning Balance		$ 31.51
Options, Weighted Average Exercise Price, Granted		24.99
Options, Weighted Average Exercise Price, Exercised		17.84
Options, Weighted Average Exercise Price, Cancelled		24.04
Options, Weighted Average Exercise Price, Ending Balance		31.32		$ 31.51
Options, Weighted Average Exercise Price, Exercisable at Period End		29.75
Estimated fair value at date of grant of options for common stock granted
Weighted-average grant date fair value of options for our common stock granted during the year, per share		$ 7.90		$ 7.61	$ 7.50
Weighted-average assumptions:
Dividend yield		3.20%		4.80%	4.20%
Volatility		44.70%		27.80%	28.00%
Risk-free interest rate		1.20%		1.80%	2.20%
Expected life (years)		6 years		6 years	6 years 6 months
Duration Of Base Term For Peer Group Historical Volatility Measurement		10 years
Williams Companies Incentive Plan [Member] | Nonvested Restricted Stock Units [Member]
Equity-Based Compensation (Textuals) [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period		3 years
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized [Abstract]
Unrecognized equity-based compensation expense - Restricted Stock Units		$ 62,000,000
Rollforward of nonvested restricted stock unit activity and related information
Restricted Stock Units, Nonvested shares, Beginning Balance		3,400,000
Restricted Stock Units, Granted		1,500,000
Restricted Stock Units, Forfeited		(100,000)
Restricted Stock Units, Vested		(900,000)
Restricted Stock Units, Nonvested shares, Ending Balance		3,900,000		3,400,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Restricted Stock Units, Nonvested, Weighted-Average Fair Value, Beginning Balance	[1]	$ 39.38
Weighted-average grant date fair value of restricted stock units granted during the year, per share		26.51	[1]	$ 40.15	$ 42.79
Restricted Stock Units, Forfeited, Weighted-Average Fair Value	[1]	38.18
Restricted Stock Units, Vested, Weighted-Average Fair Value	[1]	35.49
Restricted Stock Units, Nonvested, Weighted-Average Fair Value, Ending Balance	[1]	$ 35.19		$ 39.38
Restricted Stock Units, Vested in Period, Fair Value		$ 32,000,000		$ 42,000,000	$ 27,000,000
Williams Companies Incentive Plan [Member] | Performance Shares [Member]
Equity-Based Compensation (Textuals) [Abstract]
Share Based Compensation Arrangement By Share Based Payment Award Duration Of Postvesting Restriction On Sale		2 years
Rollforward of nonvested restricted stock unit activity and related information
Performance based nonvested restricted stock units as a percent of total nonvested restricted stock units outstanding		40.00%
Williams Companies Incentive Plan [Member] | Performance Shares [Member] | Minimum [Member]
Rollforward of nonvested restricted stock unit activity and related information
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Discount for Postvesting Restrictions		5.83%
Range of vested shares based on extent to which certain financial targets are achieved		0.00%
Williams Companies Incentive Plan [Member] | Performance Shares [Member] | Maximum [Member]
Rollforward of nonvested restricted stock unit activity and related information
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Discount for Postvesting Restrictions		15.58%
Range of vested shares based on extent to which certain financial targets are achieved		500.00%
Employee Stock Purchase Plan [Member]
Equity-Based Compensation (Textuals) [Abstract]
Shares reserved for issuance						1,600,000		2,000,000
Shares available for future grants		1,400,000
Maximum annual amount for purchase of common stock per participant under employee stock purchase plan		$ 15,000
Number of shares eligible for employee to purchase per offering period		750
Percentage of purchase price is the lower of closing price of either the first or the last day of the offering period		85.00%
No. of shares purchases by employees		111,000
Average price of shares purchased		$ 23.93
Share Based Compensation Arrangement By Share Based Payment Award Duration Of Postvesting Restriction On Sale		1 year
Williams Partners Long Term Incentive Plan [Member] | Nonvested Restricted Stock Units [Member]
Equity-Based Compensation (Textuals) [Abstract]
Equity-based compensation expense		$ 20,000,000		$ 29,000,000	$ 11,000,000
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized [Abstract]
Unrecognized equity-based compensation expense - Restricted Stock Units		11,000,000
Estimated forfeitures under employee equity-based awards		$ 1,000,000
Unrecognized equity-based compensation expense, Weighted-average period of recognition in years		1 year 2 months
Rollforward of nonvested restricted stock unit activity and related information
Restricted Stock Units, Nonvested shares, Beginning Balance		1,200,000
Restricted Stock Units, Granted		0		0
Restricted Stock Units, Forfeited		(100,000)
Restricted Stock Units, Vested		(500,000)
Restricted Stock Units, Nonvested shares, Ending Balance		600,000		1,200,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Restricted Stock Units, Nonvested, Weighted-Average Fair Value, Beginning Balance		$ 55.93
Restricted Stock Units, Forfeited, Weighted-Average Fair Value		52.85
Restricted Stock Units, Vested, Weighted-Average Fair Value		59.09
Restricted Stock Units, Nonvested, Weighted-Average Fair Value, Ending Balance		$ 52.97		$ 55.93
Williams Partners Long Term Incentive Plan [Member] | Nonvested Restricted Stock Units [Member] | Minimum [Member]
Equity-Based Compensation (Textuals) [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period		1 year
Williams Partners Long Term Incentive Plan [Member] | Nonvested Restricted Stock Units [Member] | Maximum [Member]
Equity-Based Compensation (Textuals) [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period		4 years

[1] Performance-based restricted stock units are valued utilizing a Monte Carlo valuation method using measures of total shareholder return. Certain of the performance-based restricted stock units are subject to a holding period of up to two years after the vesting date. Discounts for the restrictions of liquidity were applied to the estimated fair value at the date of certain awards and ranged from 5.83 percent to 15.58 percent. The discounts were developed using the Chaffe model and the Finnerty model. All other restricted stock units are valued at the grant-date market price. Restricted stock units generally vest after three years.

XML

Fair Value Measurements Recurring Measurements and Additional (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Additional disclosures:
Fair Value, Level 1 to level 2 Transfers, Amount	$ 0	$ 0
Fair Value, Level 2 to level 1 Transfers, Amount	0	0
Wiltel Guarantee [Member]
Additional disclosures:
Guarantor Obligations, Maximum Exposure, Undiscounted	32
Carrying Amount [Member]
Additional disclosures:
Other receivables	15	12
Long-term debt, including current portion	(23,409)	(23,987)	[1]
Guarantees	(44)	(29)
Carrying Amount [Member] | Former Venezuela Operations [Member]
Additional disclosures:
Notes Receivable, Fair Value Disclosure	0	0
Fair Value [Member]
Additional disclosures:
Other receivables	15	30
Long-term debt, including current portion	(24,090)	(19,606)	[1]
Guarantees	(30)	(16)
Fair Value [Member] | Former Venezuela Operations [Member]
Additional disclosures:
Notes Receivable, Fair Value Disclosure		18
Level 1 [Member]
Additional disclosures:
Other receivables	15	10
Long-term debt, including current portion	0	0	[1]
Guarantees	0	0
Level 2 [Member]
Additional disclosures:
Other receivables	0	2
Long-term debt, including current portion	(24,090)	(19,606)	[1]
Guarantees	(14)	(16)
Level 3 [Member]
Additional disclosures:
Other receivables	0	18
Long-term debt, including current portion	0	0	[1]
Guarantees	(16)	0
Fair Value, Measurements, Recurring [Member] | Carrying Amount [Member]
Measured on a recurring basis:
ARO Trust investments	96	67
Fair Value, Measurements, Recurring [Member] | Carrying Amount [Member] | Designated as Hedging Instrument [Member]
Measured on a recurring basis:
Energy derivatives assets	2
Fair Value, Measurements, Recurring [Member] | Carrying Amount [Member] | Not Designated as Hedging Instrument [Member]
Measured on a recurring basis:
Energy derivatives assets	1	5
Energy derivatives liabilities	(6)	(2)
Fair Value, Measurements, Recurring [Member] | Fair Value [Member]
Measured on a recurring basis:
ARO Trust investments	96	67
Fair Value, Measurements, Recurring [Member] | Fair Value [Member] | Designated as Hedging Instrument [Member]
Measured on a recurring basis:
Energy derivatives assets	2
Fair Value, Measurements, Recurring [Member] | Fair Value [Member] | Not Designated as Hedging Instrument [Member]
Measured on a recurring basis:
Energy derivatives assets	1	5
Energy derivatives liabilities	(6)	(2)
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Measured on a recurring basis:
ARO Trust investments	96	67
Fair Value, Measurements, Recurring [Member] | Level 1 [Member] | Designated as Hedging Instrument [Member]
Measured on a recurring basis:
Energy derivatives assets	0
Fair Value, Measurements, Recurring [Member] | Level 1 [Member] | Not Designated as Hedging Instrument [Member]
Measured on a recurring basis:
Energy derivatives assets	0	0
Energy derivatives liabilities	0	0
Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Measured on a recurring basis:
ARO Trust investments	0	0
Fair Value, Measurements, Recurring [Member] | Level 2 [Member] | Designated as Hedging Instrument [Member]
Measured on a recurring basis:
Energy derivatives assets	2
Fair Value, Measurements, Recurring [Member] | Level 2 [Member] | Not Designated as Hedging Instrument [Member]
Measured on a recurring basis:
Energy derivatives assets	0	3
Energy derivatives liabilities	0	0
Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Measured on a recurring basis:
ARO Trust investments	0	0
Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Designated as Hedging Instrument [Member]
Measured on a recurring basis:
Energy derivatives assets	0
Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Not Designated as Hedging Instrument [Member]
Measured on a recurring basis:
Energy derivatives assets	1	2
Energy derivatives liabilities	$ (6)	$ (2)

[1] Excludes capital leases.

XML

Fair Value Measurements Nonrecurring Measurements (Details) - USD ($) $ in Millions		3 Months Ended																9 Months Ended		12 Months Ended
		Dec. 31, 2016		Jun. 30, 2016		Mar. 31, 2016		Dec. 31, 2015		Sep. 30, 2015		Jun. 30, 2015	[3]	Dec. 31, 2014		Jun. 30, 2014	[3]	Sep. 30, 2015		Dec. 31, 2016		Dec. 31, 2015		Dec. 31, 2014
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Impairment of goodwill								$ 1,098												$ 0		$ 1,098		$ 0
Impairment of certain assets																				873		209		52
Impairment of equity-method investments																				430		1,359		0
Delaware Basin Gas Gathering System [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Impairment of equity-method investments																				59		503
Appalachia Midstream Investments [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Impairment of equity-method investments																				294		562
Williams Partners [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Impairment of goodwill																						1,098
Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Williams Partners [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Impairment of goodwill																		$ 0
Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Williams Partners [Member] | Minimum [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Discount rate								10.00%
Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Williams Partners [Member] | Maximum [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Discount rate								13.00%
Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | West [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Impairment of goodwill								$ 0
Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Property, plant, and equipment, net [Member] | Williams Partners [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Fair value of property, plant, and equipment				$ 18	[1]			13	[2]			$ 17		$ 32	[3]	$ 46						13	[2]	32	[3]
Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Property, plant, and equipment, net [Member] | Williams Ngl And Petchem Services [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Fair value of property, plant, and equipment		$ 73						40	[4]											73		40	[4]
Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Assets Held For Sale [Member] | Williams Partners [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Assets Held-for-sale, Long Lived, Fair Value Disclosure	[3]													1										1
Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Investments [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Fair value of investment						$ 0		58														58
Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Investments [Member] | Williams Partners [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Fair value of investment		$ 1,295	[5]			$ 1,294	[6]	$ 4,017	[7]	$ 1,203	[8]							$ 1,203	[8]	1,295	[5]	4,017	[7]
Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Investments [Member] | Williams Partners [Member] | Minimum [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Discount rate						13.00%	[6]	10.80%	[7]
Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Investments [Member] | Williams Partners [Member] | Maximum [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Discount rate						13.30%	[6]	14.40%	[7]
Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Investments [Member] | Williams Partners [Member] | Delaware Basin Gas Gathering System [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Discount rate	[8]									11.80%
Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Investments [Member] | Williams Partners [Member] | Appalachia Midstream Investments [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Discount rate		10.20%	[5]							8.80%	[8]
Canadian Operations [Member] | Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Assets Held For Sale [Member] | Williams Partners [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Assets Held-for-sale, Long Lived, Fair Value Disclosure	[9]			924
Canadian Operations [Member] | Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Assets Held For Sale [Member] | Williams Ngl And Petchem Services [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Assets Held-for-sale, Long Lived, Fair Value Disclosure	[9]			206
Impairment Of Goodwill [Member] | Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Williams Partners [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Impairment of goodwill								$ 1,098
Impairment Of Certain Assets [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Impairment of certain assets																				873		209		52
Impairment Of Certain Assets [Member] | Fair Value, Measurements, Nonrecurring [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Impairment of certain assets	[10]																			70		31		10
Impairment Of Certain Assets [Member] | Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Impairment of certain assets																				803		178		$ 42
Impairment Of Certain Assets [Member] | Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Williams Partners [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Impairment of certain assets				48	[1]			94	[2]			$ 20		13	[3]	$ 17
Impairment of Long-Lived Assets to be Disposed of	[3]													$ 12
Impairment Of Certain Assets [Member] | Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Williams Ngl And Petchem Services [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Impairment of certain assets		$ 8						64	[4]
Impairment Of Certain Assets [Member] | Canadian Operations [Member] | Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Williams Partners [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Disposal Group, Not Discontinued Operation, Loss (Gain) on Write-down	[9]			341
Impairment Of Certain Assets [Member] | Canadian Operations [Member] | Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Williams Ngl And Petchem Services [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Disposal Group, Not Discontinued Operation, Loss (Gain) on Write-down	[9]			$ 406
Impairment Of Equity-Method Investments [Member] | Fair Value, Measurements, Nonrecurring [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Impairment of equity-method investments																				$ 430		$ 1,359
Impairment Of Equity-Method Investments [Member] | Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Impairment of equity-method investments						$ 3		8
Impairment Of Equity-Method Investments [Member] | Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Williams Partners [Member]
Fair Value Assets Measured On Nonrecurring Basis [Abstract]
Impairment of equity-method investments		$ 318	[5]			$ 109	[6]	$ 890	[7]	$ 461	[8]

[1] Relates to certain gathering assets within the Mid-Continent region. The estimated fair value was determined by a market approach based on our analysis of observable inputs in the principal market.

[2] Relates to a gas processing plant, the completion of which is considered remote due to unfavorable impact of low natural gas prices on customer drilling activities. The assessed fair value primarily represents the estimated salvage value of certain equipment measured using a market approach based on our analysis of observable inputs in the principal market.

[3] Relates to certain surplus equipment. The estimated fair value was determined by a market approach based on our analysis of observable inputs in the principal market.

[4] Relates to an olefins pipeline project, the completion of which is considered remote due to lack of customer interest. The assessed fair value primarily represents the estimated fair value of unused pipeline measured using a market approach based on our analysis of observable inputs in the principal market.

[5] Relates to equity-method investments in Ranch Westex and multiple Appalachia Midstream Investments. The historical carrying value of these investments was initially recorded based on estimated fair value during the third quarter of 2014 in conjunction with the acquisition of ACMP. We estimated the fair value of these Appalachia Midstream Investments using an income approach based on expected future cash flows and appropriate discount rates. The determination of estimated future cash flows involved significant assumptions regarding gathering volumes, rates, and related capital spending. The discount rate utilized for the Appalachia Midstream Investments evaluation was 10.2 percent and reflected our cost of capital as impacted by market conditions and risks associated with the underlying businesses. In addition to utilizing an income approach, we also considered a market approach for certain Appalachia Midstream Investments and Ranch Westex based on an agreement reached in February 2017 to exchange our interests in DBJV and Ranch Westex for additional interests in certain Appalachia Midstream Investments and cash.

[6] Relates to equity-method investments in DBJV and Laurel Mountain. Our carrying values in these equity-method investments had been written down to fair value at December 31, 2015. Our first-quarter 2016 analysis reflected higher discount rates for both of these investments, along with lower natural gas prices for Laurel Mountain. We estimated the fair value of these investments using an income approach based on expected future cash flows and appropriate discount rates. The determination of estimated future cash flows involved significant assumptions regarding gathering volumes and related capital spending. Discount rates utilized ranged from 13.0 percent to 13.3 percent and reflected increases in our cost of capital, revised estimates of expected future cash flows, and risks associated with the underlying businesses.

[7] Relates to equity-method investments in DBJV, certain of the Appalachia Midstream Investments, UEOM, and Laurel Mountain. We estimated the fair value of these investments using an income approach based on expected future cash flows and appropriate discount rates. The determination of estimated future cash flows involved significant assumptions regarding gathering volumes and related capital spending. Discount rates utilized ranged from 10.8 percent to 14.4 percent and reflected further fourth-quarter 2015 increases in our cost of capital, revised estimates of expected future cash flows, and risks associated with the underlying businesses.

[8] Relates to equity-method investments in DBJV and certain of the Appalachia Midstream Investments. The historical carrying value of these investments was initially recorded based on estimated fair value during the third quarter of 2014 in conjunction with the acquisition of ACMP. We estimated the fair value of these investments using an income approach based on expected future cash flows and appropriate discount rates. The determination of estimated future cash flows involved significant assumptions regarding gathering volumes and related capital spending. Discount rates utilized were 11.8 percent and 8.8 percent for DBJV and certain of the Appalachia Midstream Investments, respectively, and reflected our cost of capital as impacted by market conditions, and risks associated with the underlying businesses.

[9] Relates to our Canadian operations. We designated these operations as held for sale as of June 30, 2016. As a result, we measured the fair value of the disposal group, resulting in an impairment charge. The estimated fair value was determined by a market approach based primarily on inputs received in the marketing process and reflected our estimate of the potential assumed proceeds. We disposed of our Canadian operations through a sale during the third quarter of 2016. See Note 3 – Divestiture.

[10] Reflects multiple individually insignificant impairments and write-downs of other certain assets that may no longer be in use or are surplus in nature for which the fair value was determined to be zero or an insignificant salvage value.

XML

Fair Value Measurements Concentration of Credit Risk (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Concentration Risk [Line Items]
Trade accounts and other receivables	$ 938	$ 1,041
NGLs, natural gas, and related products and services [Member]
Concentration Risk [Line Items]
Trade accounts and other receivables	736	823
Transportation of natural gas and related products [Member]
Concentration Risk [Line Items]
Trade accounts and other receivables	187	202
Other Receivable [Member]
Concentration Risk [Line Items]
Trade accounts and other receivables	15	16
Chesapeake Energy Corporation [Member] | Customer Concentration Risk [Member] | Accounts receivable [Member] | Williams Partners [Member]
Concentration Risk [Line Items]
Trade accounts and other receivables	$ 133	$ 364
Chesapeake Energy Corporation [Member] | Customer Concentration Risk [Member] | Sales Revenue, Net [Member] | Williams Partners [Member]
Concentration Risk [Line Items]
Consolidated revenue, major customer, percentage	14.00%	18.00%

XML

Contingent Liabilities and Commitments (Details) - USD ($) $ in Millions	May 20, 2016	Dec. 31, 2016
Loss Contingencies [Line Items]
Accrued environmental loss liabilities		$ 38
Capital Addition Purchase Commitments [Member]
Loss Contingencies [Line Items]
Commitments for construction and acquisition of property, plant, and equipment		244
Energy Transfer Merger [Member]
Loss Contingencies [Line Items]
Loss contingency, damages sought, value	$ 1,480
Gas Pipeline [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities		9
Natural gas underground storage facilities [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities		7
Former Operations [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities		22
Williams Partners [Member] | General Liability [Member] | Geismar Incident [Member]
Loss Contingencies [Line Items]
Aggregate limit of insurance		610
Insurance deductibles		2
Maximum [Member] | Former Alaska Refinery [Member]
Loss Contingencies [Line Items]
Loss contingency, range of possible loss, maximum		$ 32

XML

Segment Disclosures Geographic Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Revenues from external customers:
Revenues from external customers	$ 7,499	$ 7,360	$ 7,637
Long-lived assets:
Long-lived assets	38,091	39,596	39,654
United States [Member]
Revenues from external customers:
Revenues from external customers	7,425	7,247	7,229
Long-lived assets:
Long-lived assets	38,091	38,016	38,290
Canada [Member]
Revenues from external customers:
Revenues from external customers	74	113	408
Long-lived assets:
Long-lived assets	$ 0	$ 1,580	$ 1,364

XML

Segment Disclosures Recon from Segment to Consolidated - Revenues (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment revenues [Line Items]
Service revenues	$ 5,171	$ 5,164	$ 4,116
Product sales	2,328	2,196	3,521
Total revenues	7,499	7,360	7,637
Other financial information:
Additions to long-lived assets	2,145	3,336	20,756
Proportional Modified Ebitda Equity Method Investments	754	699	438
Williams Partners [Member]
Segment revenues [Line Items]
Service revenues	5,140	5,134	3,887
Product sales	2,318	2,196	3,521
Williams Ngl And Petchem Services [Member]
Segment revenues [Line Items]
Service revenues	2	2	0
Product sales	10	0	0
Other [Member]
Segment revenues [Line Items]
Service revenues	29	28	229
Product sales	0	0	0
Intersegment Eliminations [Member]
Segment revenues [Line Items]
Service revenues	(52)	(159)	(31)
Product sales	(16)	0	0
Total revenues	(68)	(159)	(31)
Other financial information:
Additions to long-lived assets	(1)	(12)	(2)
Proportional Modified Ebitda Equity Method Investments	0	0	0
Intersegment Eliminations [Member] | Williams Partners [Member]
Segment revenues [Line Items]
Service revenues	(33)	(1)	(1)
Product sales	0	0	0
Intersegment Eliminations [Member] | Williams Ngl And Petchem Services [Member]
Segment revenues [Line Items]
Service revenues	0	0	0
Product sales	(16)	0	0
Intersegment Eliminations [Member] | Other [Member]
Segment revenues [Line Items]
Service revenues	(19)	(158)	(30)
Product sales	0	0	0
Operating Segments [Member] | Williams Partners [Member]
Segment revenues [Line Items]
Service revenues	5,173	5,135	3,888
Product sales	2,318	2,196	3,521
Total revenues	7,491	7,331	7,409
Other financial information:
Additions to long-lived assets	2,102	2,960	20,413	[1]
Proportional Modified Ebitda Equity Method Investments	754	699	431
Operating Segments [Member] | Williams Ngl And Petchem Services [Member]
Segment revenues [Line Items]
Service revenues	2	2	0
Product sales	26	0	0
Total revenues	28	2	0
Other financial information:
Additions to long-lived assets	33	360	291
Proportional Modified Ebitda Equity Method Investments	0	0	(78)
Operating Segments [Member] | Other [Member]
Segment revenues [Line Items]
Service revenues	48	186	259
Product sales	0	0	0
Total revenues	48	186	259
Other financial information:
Additions to long-lived assets	11	28	54
Proportional Modified Ebitda Equity Method Investments	$ 0	$ 0	$ 85

[1] 2014 Additions to long-lived assets within our Williams Partners segment primarily includes the acquisition-date fair value of long-lived assets from the ACMP Acquisition. (See Note 2 - Acquisitions.)

XML

Segment Disclosures Recon from Modified EBITDA to Net Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Reconciliation of Modified EBITDA to Net Income (Loss)
Modified EBITDA		$ 3,322	$ 3,891	$ 3,232
Accretion expense associated with asset retirement obligations for nonregulated operations		(31)	(28)	(18)
Depreciation and amortization expenses		(1,763)	(1,738)	(1,176)
Impairment of goodwill	$ (1,098)	0	(1,098)	0
Equity earnings (losses)		397	335	144
Gain on remeasurement of equity-method investment (Note 2)		0	0	2,544
Impairment of equity-method investments		(430)	(1,359)	0
Other investing income (loss) – net		63	27	43
Proportional Modified Ebitda Equity Method Investments		(754)	(699)	(438)
Interest Expense		(1,179)	(1,044)	(747)
(Provision) benefit for income taxes		25	399	(1,249)
Income (loss) from discontinued operations, net of tax		0	0	4
Net income (loss)		(350)	(1,314)	2,339
Williams Partners [Member]
Reconciliation of Modified EBITDA to Net Income (Loss)
Impairment of goodwill			(1,098)
Intersegment Eliminations [Member]
Reconciliation of Modified EBITDA to Net Income (Loss)
Proportional Modified Ebitda Equity Method Investments		0	0	0
Operating Segments [Member] | Williams Partners [Member]
Reconciliation of Modified EBITDA to Net Income (Loss)
Modified EBITDA		3,864	4,003	3,244
Proportional Modified Ebitda Equity Method Investments		(754)	(699)	(431)
Operating Segments [Member] | Williams NGL & Petchem Services [Member]
Reconciliation of Modified EBITDA to Net Income (Loss)
Modified EBITDA		(540)	(83)	(115)
Proportional Modified Ebitda Equity Method Investments		0	0	78
Operating Segments [Member] | Other [Member]
Reconciliation of Modified EBITDA to Net Income (Loss)
Modified EBITDA		(2)	(29)	103
Proportional Modified Ebitda Equity Method Investments		$ 0	$ 0	$ (85)

XML

Segment Disclosures Recon from Segment to Consolidated - Assets and Investments (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	$ 46,835	$ 49,020
Equity-method investments	6,701	7,336
Operating Segments [Member] | Williams Partners [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	46,265	47,870
Equity-method investments	6,701	7,336
Operating Segments [Member] | Williams Ngl And Petchem Services [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	249	835
Equity-method investments	0	0
Operating Segments [Member] | Other [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	674	850
Equity-method investments	0	0
Intersegment Eliminations [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	(353)	(535)
Equity-method investments	$ 0	$ 0

XML

Schedule I Condensed Financial Information Of Registrant (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions		12 Months Ended
	Jun. 23, 2014	Dec. 31, 2016		Dec. 31, 2015		Dec. 31, 2014	Dec. 31, 2016	Dec. 31, 2015
Condensed Statement Of Comprehensive Income Parent Company Only [Abstract]
Equity earnings (losses)		$ 397		$ 335		$ 144
Interest incurred - external		(1,217)		(1,118)		(888)
Gain on remeasurement of equity-method investment (Note 2)		0		0		2,544
Other income (expense) – net		74		102		31
Income (loss) from continuing operations before income taxes		(375)		(1,713)		3,584
Provision (benefit) for income taxes		(25)		(399)		1,249
Income (loss) from continuing operations		(424)		(571)		2,110
Income (loss) from discontinued operations		0		0		4
Net income (loss) attributable to The Williams Companies, Inc.		$ (424)		$ (571)		$ 2,114
Basic earnings (loss) per common share:
Income (loss) from continuing operations		$ (0.57)		$ (0.76)		$ 2.93
Income (loss) from discontinued operations		0.00		0.00		0.01
Net income (loss)		$ (0.57)		$ (0.76)		$ 2.94
Weighted-average shares (thousands)		750,673		749,271		719,325
Diluted earnings (loss) per common share:
Income (loss) from continuing operations		$ (0.57)		$ (0.76)		$ 2.91
Income (loss) from discontinued operations		0.00		0.00		0.01
Net income (loss)		$ (0.57)		$ (0.76)		$ 2.92
Weighted-average shares (thousands)		750,673	[1]	749,271	[1]	723,641
Other comprehensive income (loss):
Other comprehensive income (loss)		$ 172		$ (171)		$ (176)
Comprehensive Income (loss) attributable to The Williams Companies, Inc.		(321)		(672)		1,957
Assets, Current [Abstract]
Cash and cash equivalents		100		240		681	$ 170	$ 100
Other current assets and deferred charges							216	259
Total current assets							1,462	1,527
Property, plant, and equipment – net							28,428	29,579
Other noncurrent assets							581	561
Total assets							46,835	49,020
Liabilities, Current [Abstract]
Accounts payable							623	744
Total current liabilities							2,949	2,497
Long-term debt							22,624	23,812
Deferred income taxes							4,238	4,218
Contingent liabilities and commitments
Equity: [Abstract]
Common stock							785	784
Total stockholders’ equity							4,643	6,148
Total liabilities and stockholders' equity							46,835	49,020
Condensed Statement Of Cash Flows Parent Company Only [Abstract]
Net Cash Provided (Used) by Operating Activities		3,664		2,678		2,115
FINANCING ACTIVITIES:
Proceeds from long-term debt		6,528		9,772		7,321
Payments of long-term debt		(7,091)		(6,516)		(1,828)
Proceeds from issuance of common stock	$ 3,378	9		27		3,416
Dividends paid		(1,261)		(1,836)		(1,412)
Other – net		0		(1)		17
Net cash provided (used) by financing activities		(3,178)		481		7,601
INVESTING ACTIVITIES:
Capital expenditures		(2,145)		(3,336)		(20,756)
Other – net		290		168		74
Net cash provided (used) by investing activities		(416)		(3,299)		(10,157)
Increase (decrease) in cash and cash equivalents		70		(140)		(441)
Cash and cash equivalents at beginning of year		100		240		681
Cash and cash equivalents at end of year		170		100		240
Parent Company [Member]
Condensed Statement Of Comprehensive Income Parent Company Only [Abstract]
Equity in earnings of consolidated subsidiaries		522		232		1,799
Equity earnings (losses)		0		0		(7)
Interest incurred - external		(268)		(255)		(206)
Interest incurred - affiliate		(568)		(828)		(797)
Interest income - affiliate		0		6		10
Gain on remeasurement of equity-method investment (Note 2)		0		0		2,544
Other income (expense) – net		(53)		(75)		(13)
Income (loss) from continuing operations before income taxes		(367)		(920)		3,330
Provision (benefit) for income taxes		57		(349)		1,220
Income (loss) from continuing operations		(424)		(571)		2,110
Income (loss) from discontinued operations		0		0		4
Net income (loss) attributable to The Williams Companies, Inc.		$ (424)		$ (571)		$ 2,114
Basic earnings (loss) per common share:
Income (loss) from continuing operations		$ (0.57)		$ (0.76)		$ 2.93
Income (loss) from discontinued operations		0.00		0.00		0.01
Net income (loss)		$ (0.57)		$ (0.76)		$ 2.94
Weighted-average shares (thousands)		750,673		749,271		719,325
Diluted earnings (loss) per common share:
Income (loss) from continuing operations		$ (0.57)		$ (0.76)		$ 2.91
Income (loss) from discontinued operations		0.00		0.00		0.01
Net income (loss)		$ (0.57)		$ (0.76)		$ 2.92
Weighted-average shares (thousands)		750,673		749,271		723,641
Other comprehensive income (loss):
Equity in other comprehensive income (loss) of consolidated subsidiaries		$ 171		$ (204)		$ (96)
Other comprehensive income (loss) attributable to The Williams Companies, Inc.		1		33		(80)
Other comprehensive income (loss)		172		(171)		(176)
Other comprehensive income (loss) attributable to noncontrolling interests		69		(70)		(19)
Comprehensive Income (loss) attributable to The Williams Companies, Inc.		(321)		(672)		1,957
Assets, Current [Abstract]
Cash and cash equivalents		12		49		282	14	12
Other current assets and deferred charges							16	62
Total current assets							30	74
Investments in and advances to consolidated subsidiaries							22,359	30,927
Property, plant, and equipment – net							77	99
Other noncurrent assets							8	12
Total assets							22,474	31,112
Liabilities, Current [Abstract]
Accounts payable							27	27
Other current liabilities							169	163
Total current liabilities							196	190
Long-term debt							4,939	4,811
Notes payable - affiliates							8,171	15,506
Pension, other postretirement and other noncurrent liabilities							287	336
Deferred income taxes							4,238	4,121
Equity: [Abstract]
Common stock							785	784
Other stockholders' equity							3,858	5,364
Total stockholders’ equity							4,643	6,148
Total liabilities and stockholders' equity							22,474	$ 31,112
Condensed Statement Of Cash Flows Parent Company Only [Abstract]
Net Cash Provided (Used) by Operating Activities		(833)		(1,209)		(500)
FINANCING ACTIVITIES:
Proceeds from long-term debt		2,280		2,097		2,935
Payments of long-term debt		(2,155)		(1,817)		(671)
Changes in notes payable to affiliates		9		2,211		2,465
Tax benefit of stock-based awards		0		0		25
Proceeds from issuance of common stock		9		27		3,416
Dividends paid		(1,261)		(1,836)		(1,412)
Other – net		0		(2)		(17)
Net cash provided (used) by financing activities		(1,118)		680		6,741
INVESTING ACTIVITIES:
Capital expenditures		(13)		(29)		(54)
Purchase of Access Midstream Partners		0		0		(5,995)
Changes in investments in and advances to consolidated subsidiaries		1,966		521		(450)
Other – net		0		0		25
Net cash provided (used) by investing activities		1,953		492		(6,474)
Increase (decrease) in cash and cash equivalents		2		(37)		(233)
Cash and cash equivalents at beginning of year		12		49		282
Cash and cash equivalents at end of year		14		12		49
Guarantees [Abstract]
Guarantor Obligations, Maximum Exposure, Undiscounted							$ 305
Cash Dividends Received [Abstract]
Proceeds from Dividends Received		$ 1,700		$ 1,800		$ 1,900

[1] For the years ended December 31, 2016 and December 31, 2015, 0.6 million and 1.7 million weighted-average nonvested restricted stock units, and 0.5 million and 1.5 million weighted-average stock options have been excluded from the computation of diluted earnings (loss) per common share as their inclusion would be antidilutive due to our loss from continuing operations attributable to The Williams Companies, Inc.

XML

Schedule II Valuation and Qualifying Accounts (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Allowance for doubtful accounts and for notes receivable [Member]
Valuation And Qualifying Accounts
Beginning Balance	[1]	$ 3	$ 0	$ 0
Additions Charged (Credited) To Cost and Expenses		6	3	0
Additions Other		0	0	0
Deductions		3	0	0
Ending Balance	[1]	6	3	0
Deferred Tax Asset Valuation Allowance [Member]
Valuation And Qualifying Accounts
Beginning Balance	[1]	190	206	181
Additions Charged (Credited) To Cost and Expenses		144	(16)	25
Additions Other		0	0	0
Deductions		0	0	0
Ending Balance	[1]	$ 334	$ 190	$ 206

[1] Deducted from related assets.