WILLIAMS COMPANIES, INC. - Quarter Report: 2015 June (Form 10-Q)

Large accelerated filer þ

Accelerated filer ¨

Non-accelerated filer ¨

Smaller reporting company ¨

(Do not check if a smaller reporting company)

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)



þ	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2015



¨	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)		(I.R.S. Employer Identification No.)

ONE WILLIAMS CENTER
TULSA, OKLAHOMA		74172-0172
(Address of principal executive offices)		(Zip Code)

Registrant’s telephone number, including area code: (918) 573-2000

NO CHANGE

(Former name, former address and former fiscal year, if changed since last report.)

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). þ Yes ¨ No

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):

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

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.



Class		Shares Outstanding at July 27, 2015
Common Stock, $1 par value		749,711,274

The Williams Companies, Inc.

Index



		Page
Part I. Financial Information
Item 1. Financial Statements
Consolidated Statement of Income – Three and Six Months Ended June 30, 2015 and 2014		6
Consolidated Statement of Comprehensive Income – Three and Six Months Ended June 30, 2015 and 2014		7
Consolidated Balance Sheet – June 30, 2015 and December 31, 2014		8
Consolidated Statement of Changes in Equity – Six Months Ended June 30, 2015		9
Consolidated Statement of Cash Flows – Six Months Ended June 30, 2015 and 2014		10
Notes to Consolidated Financial Statements		11
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations		30
Item 3. Quantitative and Qualitative Disclosures About Market Risk		53
Item 4. Controls and Procedures		54
Part II. Other Information		54
Item 1. Legal Proceedings		54
Item 1A. Risk Factors		55
Item 6. Exhibits		57

Certain matters contained in this report include “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. 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 facts, 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:


•	Expected levels of cash distributions by Williams Partners L.P. (WPZ) with respect to general partner interests, incentive distribution rights, and limited partner interests;


•	Levels of dividends to stockholders;


•	The status, expected timing, and expected outcome of our proposed acquisition of all of the publicly held outstanding common units of WPZ in exchange for shares of our common stock (Acquisition of WPZ Public Units);


•	The status, expected timing, and expected outcome of the unsolicited proposal for us to be acquired in an all-equity transaction (Unsolicited Proposal) and our Board of Directors’ ongoing review of strategic alternatives;


•	Our future credit ratings;


•	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 supply, prices 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:


•	Satisfaction of the conditions to the completion of the Acquisition of WPZ Public Units, including receipt of the approval of our stockholders;


•	The results of our Board of Directors’ ongoing review of strategic alternatives;


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


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


•	Availability of supplies, market demand, and volatility of prices;


•	Inflation, interest rates, fluctuation in foreign exchange rates, and general economic conditions (including future disruptions and volatility in the global credit markets and the impact of these events on our 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 execute investment opportunities;


•	Our ability to acquire new businesses and assets and successfully integrate those operations and assets into our existing businesses, as well as successfully expand our facilities;


•	Development of alternative energy sources;


•	The impact of operational and development hazards and unforeseen interruptions;


•	Costs of, changes in, or the results of laws, government regulations (including safety and environmental regulations), environmental liabilities, litigation, and rate proceedings;


•	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 our debt agreements, future changes in our credit ratings, as well as the credit rating of WPZ 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;


•	Risks associated with weather and natural phenomena, including climate conditions;


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


•	Additional risks described in our filings with the 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 to 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. For a detailed discussion of those factors, see Part I, Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2014, and Part II, Item 1A. Risk Factors of this Form 10-Q.

DEFINITIONS

The following is a listing of certain abbreviations, acronyms, and other industry terminology used throughout this Form 10-Q.

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 June 30, 2015, we account for as an equity-method investment, including principally the following:

Bluegrass Pipeline: 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

Government and Regulatory:

EPA: Environmental Protection Agency

FERC: Federal Energy Regulatory Commission

SEC: Securities and Exchange Commission

Other:

B/B Splitter: Butylene/Butane splitter

RGP Splitter: Refinery grade propylene splitter

Fractionation: The process by which a mixed stream of natural gas liquids is separated into constituent products, such as ethane, propane, and butane

GAAP: U.S. generally accepted accounting principles

IDR: Incentive distribution right

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

PART I – FINANCIAL INFORMATION

The Williams Companies, Inc.

Consolidated Statement of Income

(Unaudited)



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
	(Millions, except per-share amounts)
Revenues:
Service revenues	$	1,241		$	825		$	2,438		$	1,644
Product sales	598			853			1,117			1,783
Total revenues	1,839			1,678			3,555			3,427
Costs and expenses:
Product costs	494			724			956			1,493
Operating and maintenance expenses	437			308			824			606
Depreciation and amortization expenses	428			214			855			428
Selling, general, and administrative expenses	174			136			370			286
Net insurance recoveries – Geismar Incident	(126		)	(42		)	(126		)	(161		)
Other (income) expense – net	40			27			57			44
Total costs and expenses	1,447			1,367			2,936			2,696
Operating income (loss)	392			311			619			731
Equity earnings (losses)	93			37			144			(11		)
Other investing income (loss) – net	9			18			9			32
Interest incurred	(278		)	(192		)	(551		)	(361		)
Interest capitalized	16			29			38			58
Other income (expense) – net	34			4			50			5
Income (loss) from continuing operations before income taxes	266			207			309			454
Provision (benefit) for income taxes	83			84			113			135
Income (loss) from continuing operations	183			123			196			319
Income (loss) from discontinued operations	—			4			—			4
Net income (loss)	183			127			196			323
Less: Net income (loss) attributable to noncontrolling interests	69			24			12			80
Net income (loss) attributable to The Williams Companies, Inc.	$	114		$	103		$	184		$	243
Amounts attributable to The Williams Companies, Inc.:
Income (loss) from continuing operations	$	114		$	99		$	184		$	239
Income (loss) from discontinued operations	—			4			—			4
Net income (loss)	$	114		$	103		$	184		$	243
Basic earnings (loss) per common share:
Income (loss) from continuing operations	$	.15		$	.14		$	.25		$	.34
Income (loss) from discontinued operations	—			.01			—			.01
Net income (loss)	$	.15		$	.15		$	.25		$	.35
Weighted-average shares (thousands)	749,253			696,553			748,669			690,695
Diluted earnings (loss) per common share:
Income (loss) from continuing operations	$	.15		$	.14		$	.24		$	.34
Income (loss) from discontinued operations	—			.01			—			.01
Net income (loss)	$	.15		$	.15		$	.24		$	.35
Weighted-average shares (thousands)	752,775			700,696			752,403			694,832
Cash dividends declared per common share	$	.5900		$	.4250		$	1.1700		$	.8275

See accompanying notes.

The Williams Companies, Inc.

Consolidated Statement of Comprehensive Income

(Unaudited)



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
	(Millions)
Net income (loss)	$	183		$	127		$	196		$	323
Other comprehensive income (loss):
Foreign currency translation adjustments, net of taxes of ($6) and $10 in 2015 and ($9) and ($8) in 2014, respectively	10			37			(85		)	(7		)
Pension and other postretirement benefits:
Amortization of prior service cost (credit) included in net periodic benefit cost, net of taxes of $0 and $1 in 2015 and $1 and $2 in 2014, respectively	(1		)	(1		)	(2		)	(2		)
Amortization of actuarial (gain) loss included in net periodic benefit cost, net of taxes of ($4) and ($8) in 2015 and ($4) and ($7) in 2014, respectively	7			6			14			12
Other comprehensive income (loss)	16			42			(73		)	3
Comprehensive income (loss)	199			169			123			326
Less: Comprehensive income (loss) attributable to noncontrolling interests	74			37			(18		)	93
Comprehensive income (loss) attributable to The Williams Companies, Inc.	$	125		$	132		$	141		$	233

See accompanying notes.

The Williams Companies, Inc.

Consolidated Balance Sheet

(Unaudited)



	June 30, 2015			December 31, 2014
	(Millions, except per-share amounts)
ASSETS
Current assets:
Cash and cash equivalents	$	204		$	240
Accounts and notes receivable – net:
Trade and other	742			972
Income tax receivable	9			167
Deferred income tax asset	68			67
Inventories	168			231
Other current assets and deferred charges	235			213
Total current assets	1,426			1,890
Investments	8,712			8,400
Property, plant, and equipment, at cost	38,070			36,435
Accumulated depreciation and amortization	(8,981		)	(8,354		)
Property, plant and equipment – net	29,089			28,081
Goodwill	1,145			1,120
Other intangible assets – net of accumulated amortization	10,158			10,453
Regulatory assets, deferred charges, and other	633			619
Total assets	$	51,163		$	50,563
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	723		$	865
Accrued liabilities	924			900
Commercial paper	1,743			798
Long-term debt due within one year	378			4
Total current liabilities	3,768			2,567
Long-term debt	21,285			20,888
Deferred income taxes	4,665			4,712
Other noncurrent liabilities	2,274			2,224
Contingent liabilities (Note 12)
Equity:
Stockholders’ equity:
Common stock (960 million shares authorized at $1 par value; 784 million shares issued at June 30, 2015 and 782 million shares issued at December 31, 2014)	784			782
Capital in excess of par value	14,812			14,925
Retained deficit	(6,243		)	(5,548		)
Accumulated other comprehensive income (loss)	(384		)	(341		)
Treasury stock, at cost (35 million shares of common stock)	(1,041		)	(1,041		)
Total stockholders’ equity	7,928			8,777
Noncontrolling interests in consolidated subsidiaries	11,243			11,395
Total equity	19,171			20,172
Total liabilities and equity	$	51,163		$	50,563

See accompanying notes.

The Williams Companies, Inc.

Consolidated Statement of Changes in Equity

(Unaudited)



	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, 2014	$	782	$	14,925		$	(5,548	)	$	(341	)	$	(1,041	)	$	8,777		$	11,395		$	20,172
Net income (loss)	—		—			184			—			—			184			12			196
Other comprehensive income (loss)	—		—			—			(43		)	—			(43		)	(30		)	(73		)
Cash dividends – common stock	—		—			(876		)	—			—			(876		)	—			(876		)
Dividends and distributions to noncontrolling interests	—		—			—			—			—			—			(462		)	(462		)
Stock-based compensation and related common stock issuances, net of tax	2		48			—			—			—			50			—			50
Changes in ownership of consolidated subsidiaries, net	—		(160		)	—			—			—			(160		)	256			96
Contributions from noncontrolling interests	—		—			—			—			—			—			57			57
Other	—		(1		)	(3		)	—			—			(4		)	15			11
Net increase (decrease) in equity	2		(113		)	(695		)	(43		)	—			(849		)	(152		)	(1,001		)
Balance – June 30, 2015	$	784	$	14,812		$	(6,243	)	$	(384	)	$	(1,041	)	$	7,928		$	11,243		$	19,171

See accompanying notes.

The Williams Companies, Inc.

Consolidated Statement of Cash Flows

(Unaudited)



	Six Months Ended June 30,
	2015			2014
	(Millions)
OPERATING ACTIVITIES:
Net income (loss)	$	196		$	323
Adjustments to reconcile to net cash provided (used) by operating activities:
Depreciation and amortization	855			428
Provision (benefit) for deferred income taxes	108			31
Amortization of stock-based awards	46			23
Cash provided (used) by changes in current assets and liabilities:
Accounts and notes receivable	350			17
Inventories	64			(81		)
Other current assets and deferred charges	(45		)	(37		)
Accounts payable	(48		)	(34		)
Accrued liabilities	(7		)	60
Other, including changes in noncurrent assets and liabilities	(36		)	29
Net cash provided (used) by operating activities	1,483			759
FINANCING ACTIVITIES:
Proceeds from (payments of) commercial paper – net	942			(226		)
Proceeds from long-term debt	5,720			4,935
Payments of long-term debt	(4,922		)	—
Proceeds from issuance of common stock	21			3,408
Dividends paid	(876		)	(567		)
Dividends and distributions paid to noncontrolling interests	(462		)	(296		)
Contributions from noncontrolling interests	57			122
Payments for debt issuance costs	(29		)	(37		)
Other – net	32			17
Net cash provided (used) by financing activities	483			7,356
INVESTING ACTIVITIES:
Property, plant, and equipment:
Capital expenditures (1)	(1,654		)	(1,839		)
Net proceeds from dispositions	6			28
Purchase of business	(112		)	—
Purchases of and contributions to equity-method investments	(483		)	(246		)
Cash held for ACMP Acquisition	—			(5,995		)
Other – net	241			116
Net cash provided (used) by investing activities	(2,002		)	(7,936		)

Increase (decrease) in cash and cash equivalents	(36		)	179
Cash and cash equivalents at beginning of year	240			681
Cash and cash equivalents at end of period	$	204		$	860
_________
(1) Increases to property, plant, and equipment	$	(1,554	)	$	(1,789	)
Changes in related accounts payable and accrued liabilities	(100		)	(50		)
Capital expenditures	$	(1,654	)	$	(1,839	)

See accompanying notes.

The Williams Companies, Inc.

Notes to Consolidated Financial Statements

(Unaudited)

Note 1 – General, Description of Business, and Basis of Presentation

General

Our accompanying interim consolidated financial statements do not include all the notes in our annual financial statements and, therefore, should be read in conjunction with the consolidated financial statements and notes thereto for the year ended December 31, 2014, in Exhibit 99.1 of our Form 8-K dated May 6, 2015. The accompanying unaudited financial statements include all normal recurring adjustments and others that, in the opinion of management, are necessary to present fairly our interim financial statements.

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.

Unless the context clearly indicates otherwise, references in this report to “we,” “our,” “us,” or like terms refer to The Williams Companies, Inc. and its subsidiaries. Unless the context clearly indicates otherwise, references to “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.

Merger

On February 2, 2015, we completed the merger of our consolidated master limited partnerships, Williams Partners L.P. (Pre-merger WPZ) and Access Midstream Partners, L.P. (ACMP) (Merger). The merged partnership is named Williams Partners L.P. Under the terms of the merger agreement, each ACMP unitholder received 1.06152 ACMP units for each ACMP unit owned immediately prior to the Merger. In conjunction with the Merger, each Pre-merger WPZ common unit held by the public was exchanged for 0.86672 ACMP common units. Each Pre-merger WPZ common unit held by us was exchanged for 0.80036 ACMP common units. Prior to the closing of the Merger, the Class D limited partner units of Pre-merger WPZ, all of which were held by us, were converted into WPZ common units on a one-for-one basis pursuant to the terms of the WPZ partnership agreement. Following the Merger, we own approximately 60 percent of the merged partnership, including the general partner interest and incentive distribution rights (IDRs). In this report, we refer to the post-merger partnership as “WPZ” and the pre-merger entities as “Pre-merger WPZ” and “ACMP.”

Acquisition of WPZ Public Units

On May 12, 2015, we entered into an agreement for a unit-for-stock transaction whereby we will acquire all of the publicly held outstanding common units of WPZ in exchange for shares of our common stock (Acquisition of WPZ Public Units). Each such WPZ common unit will be converted into the right to receive 1.115 shares of our common stock. In the event this agreement is terminated under certain circumstances, we could be required to pay a $410 million termination fee to WPZ, of which we currently own approximately 60 percent, including the interests of the general partner and IDRs. Such termination fee would be settled through a reduction of quarterly incentive distributions we are entitled to receive from WPZ (such reduction not to exceed $102.5 million per quarter).

Strategic Alternatives

Notes (Continued)

of strategic alternatives, which could include, among other things, a merger, a sale of us, or continuing to pursue our existing operating and growth plan.

Description of Business

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 former Access Midstream segment is reported within Williams Partners. For periods prior to the ACMP Acquisition, the results associated with our former equity-method investment in Access Midstream are reported within Other. Prior periods segment disclosures have been recast.

Williams Partners

Williams Partners consists of our consolidated master limited partnership, Williams Partners L.P. (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., and a 41 percent interest in Constitution Pipeline Company, LLC (Constitution) (a consolidated entity).

WPZ’s midstream businesses primarily consist of (1) natural gas gathering, treating, and processing; (2) natural gas liquid (NGL) fractionation, storage and transportation; (3) oil 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 Marcellus and Utica shale plays as well as the Eagle Ford, Haynesville, Barnett, Mid-Continent, and Niobrara areas.

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 in the Mid-Continent region, a 69 percent equity-method investment in Laurel Mountain Midstream, LLC, a 58 percent equity-method investment in Caiman Energy II, LLC, a 60 percent equity-method investment in Discovery Producer Services LLC, a 50 percent equity-method investment in Overland Pass Pipeline, LLC, and Appalachia Midstream Services, LLC, which owns an approximate average 45 percent equity-method investment interest in 11 gas gathering systems in the Marcellus Shale.

The midstream businesses also include our Canadian midstream operations, which are comprised of an oil sands offgas processing plant near Fort McMurray, Alberta, an NGL/olefin fractionation facility and butylene/butane splitter facility at Redwater, Alberta, and the Boreal Pipeline.

Williams NGL & Petchem Services

Williams NGL & Petchem Services includes certain other domestic olefins pipeline assets and certain Canadian growth projects under development (including a propane dehydrogenation facility and a liquids extraction plant).

Other

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

Basis of Presentation

Consolidated master limited partnership

As of June 30, 2015, we own approximately 60 percent of the interests in WPZ, including the interests of the general partner, which are wholly owned by us, and IDRs.

Notes (Continued)

The previously described Merger and other equity issuances by WPZ had the combined net impact of increasing Noncontrolling interests in consolidated subsidiaries by $256 million and decreasing Capital in excess of par value by $160 million and Deferred income taxes by $96 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 9 – Debt and Banking Arrangements.) Cash distributions from WPZ to us, including any associated with our IDRs, occur through the normal partnership distributions from WPZ to all partners.

Discontinued operations

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

Accounting standards issued but not yet adopted

In July 2015, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2015-11 “Simplifying the Measurement of Inventory” (ASU 2015-11). ASU 2015-11 simplifies the guidance on the subsequent measurement of inventory, excluding inventory measured using last-in, first out or the retail inventory method. Under the new standard, in scope inventory should be measured at the lower of cost and net realizable value. The new standard is effective for interim and annual periods beginning after December 15, 2016, with early adoption permitted. We are evaluating the impact of the new standard.

In May 2015, the FASB issued ASU 2015-07 “Fair Value Measurement (Topic 820) Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent)” (ASU 2015-07). ASU 2015-17 removes from the fair value hierarchy investments measured using the net asset value per share (or its equivalent) practical expedient. The standard primarily impacts certain investments included in our employee benefit plans. The guidance is effective for financial statements issued for reporting periods beginning after December 15, 2015, and interim periods within the reporting periods and requires retrospective presentation. Early adoption is permitted. We are evaluating the impact of the new standard and our timing for adoption.

In April 2015, the FASB issued ASU 2015-3 “Interest - Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs” (ASU 2015-3). ASU 2015-3 simplifies the presentation of debt issuance costs by requiring such costs be presented as a deduction from the corresponding debt liability. The guidance is effective for financial statements issued for reporting periods beginning after December 15, 2015, and interim periods within the reporting periods and requires retrospective presentation. We are evaluating the impact of the new standard.

In February 2015, the FASB issued ASU 2015-2 “Amendments to the Consolidation Analysis” (ASU 2015-2). ASU 2015-2 alters the models used to determine consolidation conclusions for certain entities, including limited partnerships, and may require additional disclosures. The ASU is effective for financial statements issued for reporting periods beginning after December 15, 2015, and interim periods within the reporting periods with either retrospective or modified retrospective presentation allowed. We are currently evaluating the impact of the new standard on our consolidated financial statements.

In May 2014, the FASB issued ASU 2014-09 establishing Accounting Standards Codification 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. The standard is effective for annual reporting periods beginning after December 15, 2017, and interim periods within the reporting period. 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 both the impact of this new standard on our consolidated financial statements and the transition method we will utilize for adoption.

Notes (Continued)

Note 2 – Acquisitions

ACMP

We acquired control of ACMP on July 1, 2014 (ACMP Acquisition). 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.

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. 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		)

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 preliminary allocation of the acquisition-date fair value of the major classes of assets acquired include $60 million of Property, plant, and equipment, at cost and $52 million of Other intangible assets – net of accumulated amortization in the Consolidated Balance Sheet.

UEOM Equity-Method Investment

In June 2015, WPZ acquired an approximate 13 percent additional equity 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 have agreed to waive approximately $2 million of our WPZ IDR payments each quarter through 2017.

Note 3 – Variable Interest Entities

As of June 30, 2015, we consolidate the following variable interest entities (VIEs):

Gulfstar One

WPZ owns a 51 percent interest 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

Notes (Continued)

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. Construction of an expansion project is underway that will provide production handling and gathering services for the Gunflint oil and gas discovery in the eastern deepwater Gulf of Mexico. The expansion project is expected to be in service in the first quarter of 2016. The current estimate of the total remaining construction costs for the expansion project is approximately $99 million, which is expected to be funded with revenues received from customers and capital contributions from WPZ and the other equity partner on a proportional basis.

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 building a pipeline connecting its gathering system in Susquehanna County, Pennsylvania, to the Iroquois Gas Transmission and the Tennessee Gas Pipeline systems. WPZ plans to place the project in service in the second half of 2016 and estimates the total remaining construction costs of the project to be approximately $634 million, which is expected to be funded with capital contributions from WPZ and the other equity partners on a proportional basis.

Cardinal

WPZ owns a 66 percent interest in Cardinal Gas Services, L.L.C (Cardinal), a subsidiary that provides gathering services for the Utica 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.

Notes (Continued)

The following table presents amounts included in our Consolidated Balance Sheet that are for the use or obligation of our consolidated VIEs.



	June 30, 2015			December 31, 2014			Classification
	(Millions)
Assets (liabilities):
Cash and cash equivalents	$	91		$	113		Cash and cash equivalents
Accounts receivable	59			52			Accounts and notes receivable – net, Trade and other
Other current assets	3			3			Other current assets and deferred charges
Property, plant and equipment – net	2,882			2,794			Property, plant and equipment – net
Goodwill	107			103			Goodwill
Other intangible assets – net	1,461			1,493			Other intangible assets – net of accumulated amortization
Other noncurrent assets	3			14			Regulatory assets, deferred charges, and other
Accounts payable	(32		)	(48		)	Accounts payable
Accrued liabilities	(22		)	(36		)	Accrued liabilities
Current deferred revenue	(63		)	(45		)	Accrued liabilities
Noncurrent deferred income taxes	—			(13		)	Deferred income taxes
Asset retirement obligation	(95		)	(94		)	Other noncurrent liabilities
Noncurrent deferred revenue associated with customer advance payments	(357		)	(395		)	Other noncurrent liabilities

Note 4 – Other Income and Expenses

The following table presents certain losses reflected in Other (income) expense – net within Costs and expenses in our Consolidated Statement of Income:



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
	(Millions)
Williams Partners
Amortization of regulatory assets associated with asset retirement obligations	$	9	$	8	$	17	$	17
Impairment of certain assets (See Note 11)	24		17		27		17

Geismar Incident

On June 13, 2013, an explosion and fire occurred at Williams Partners’ Geismar olefins plant. The incident (Geismar Incident) rendered the facility temporarily inoperable and resulted in significant human, financial, and operational effects.

At the time of the incident, we had insurance coverage for repair and replacement costs, lost production, and additional expenses related to the incident as follows:


•	Property damage and business interruption coverage with a combined per-occurrence limit of $500 million and retentions (deductibles) of $10 million per occurrence for property damage and a waiting period of 60 days per occurrence for business interruption;


•	General liability coverage with per-occurrence and aggregate annual limits of $610 million and retentions (deductibles) of $2 million per occurrence;

Notes (Continued)


•	Workers’ compensation coverage with statutory limits and retentions (deductibles) of $1 million total per occurrence.

We received $126 million of insurance recoveries related to the Geismar Incident during the three and six months ended June 30, 2015, and we received $50 million and $175 million during the three and six months ended June 30, 2014, respectively. The three and six month periods ended June 30, 2014, also include $8 million and $14 million, respectively, of related covered insurable expenses incurred in excess of our retentions (deductibles). These amounts are reported within Williams Partners and reflected as a net gain in Net insurance recoveries – Geismar Incident in the Consolidated Statement of Income.

Since June 2013, we have settled claims associated with $480 million of available property damage and business interruption coverage for a total of $422 million.

Additional Items

Selling, general, and administrative expenses includes $1 million and $26 million for the three and six months ended June 30, 2015, respectively, and $2 million for the three and six months ended June 30, 2014, primarily related to professional advisory fees associated with the ACMP Acquisition and Merger, reported within the Williams Partners segment. Selling, general, and administrative expenses for the three and six months ended June 30, 2015, also includes $4 million and $8 million, respectively, of related employee transition costs reported within the Williams Partners segment, in addition to $7 million and $13 million, respectively, of general corporate expenses associated with integration and re-alignment of resources. Operating and maintenance expenses for the three and six months ended June 30, 2015, includes $8 million and $12 million, respectively, of transition costs reported within the Williams Partners segment. Additionally, Interest incurred includes $2 million for the six months ended June 30, 2015, and $9 million for the three and six months ended June 30, 2014, of transaction-related financing costs.

The six months ended June 30, 2014, includes $19 million of project development costs related to the Bluegrass Pipeline Company LLC (Bluegrass Pipeline) reported within Williams NGL & Petchem Services and reflected in Selling, general, and administrative expenses in the Consolidated Statement of Income.

Equity earnings (losses) for the six months ended June 30, 2014, include $70 million of losses reported within Williams NGL & Petchem Services related to the write-off of previously capitalized project development costs by Bluegrass Pipeline, Moss Lake Fractionation LLC, and Moss Lake LPG Terminal LLC after our management decided to discontinue further funding of the projects. These entities were dissolved in the fourth quarter of 2014.

The three and six month periods ended June 30, 2015, each include $9 million, and the three and six month periods ended June 30, 2014, include $14 million and $27 million, respectively, of interest income associated with a receivable related to the sale of certain former Venezuela assets reflected in Other investing income (loss) – net in the Consolidated Statement of Income. 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. In second quarter 2015, we received a payment greater than the remaining carrying amount of the receivable, which resulted in the recognition of interest income.

The three and six month periods ended June 30, 2015, include $19 million and $36 million, respectively, and the three and six month periods ended June 30, 2014, include $7 million and $10 million, respectively, of allowance for equity funds used during construction (AFUDC) reported within Williams Partners in Other income (expense) – net below Operating income (loss). AFUDC increased during 2015 due to the increase in spending on various Transco expansion projects and Constitution.

Other income (expense) – net below Operating income (loss) includes a $14 million gain for the three and six month periods ended June 30, 2015, resulting from the early retirement of certain debt.

Notes (Continued)

Note 5 – Provision (Benefit) for Income Taxes

The Provision (benefit) for income taxes includes:



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015		2014
	(Millions)
Current:
Federal	$	—		$	(24	)	$	—	$	113
State	1			(1		)	1		4
Foreign	2			3			4		5
	3			(22		)	5		122
Deferred:
Federal	73			95			98		(1		)
State	(1		)	6			2		5
Foreign	8			5			8		9
	80			106			108		13

Total provision (benefit)	$	83		$	84		$	113	$	135

The effective income tax rate for the total provision for the three months ended June 30, 2015, is less than the federal statutory rate primarily due to the impact of nontaxable noncontrolling interests, partially offset by taxes on foreign operations.

The effective income tax rate for the total provision for the six months ended June 30, 2015, is greater than the federal statutory rate primarily due to a $14 million tax provision associated with an adjustment to the prior year taxable foreign income, taxes on foreign operations, and the effect of state income taxes, partially offset by the impact of nontaxable noncontrolling interests.

The effective income tax rate for the total provision for the three months ended June 30, 2014, is greater than the federal statutory rate primarily due to a provision associated with a revision of our estimate of the undistributed earnings related to the contribution of certain Canadian operations to WPZ, taxes on foreign operations, and the effect of state income taxes, partially offset by the impact of nontaxable noncontrolling interests.

The effective income tax rate for the total provision for the six months ended June 30, 2014, is less than the federal statutory rate primarily due to a tax benefit related to the contribution of certain Canadian operations to WPZ in the first quarter of 2014 and the impact of nontaxable noncontrolling interests, partially offset by the effect of state income taxes and taxes on foreign operations.

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.

Notes (Continued)

Note 6 – Earnings (Loss) Per Common Share from Continuing Operations



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		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	$	114	$	99	$	184	$	239
Basic weighted-average shares	749,253		696,553		748,669		690,695
Effect of dilutive securities:
Nonvested restricted stock units	1,755		2,091		1,985		2,094
Stock options	1,750		2,034		1,732		2,025
Convertible debentures	17		18		17		18
Diluted weighted-average shares	752,775		700,696		752,403		694,832
Earnings (loss) per common share from continuing operations:
Basic	$	.15	$	.14	$	.25	$	.34
Diluted	$	.15	$	.14	$	.24	$	.34

Note 7 – Employee Benefit Plans

Net periodic benefit cost (credit) is as follows:



	Pension Benefits
	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
	(Millions)
Components of net periodic benefit cost:
Service cost	$	15		$	10		$	29		$	20
Interest cost	14			15			29			31
Expected return on plan assets	(18		)	(19		)	(37		)	(38		)
Amortization of net actuarial loss	10			10			21			19
Net periodic benefit cost	$	21		$	16		$	42		$	32



	Other Postretirement Benefits
	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
	(Millions)
Components of net periodic benefit cost (credit):
Service cost	$	—		$	—		$	1		$	1
Interest cost	2			3			4			5
Expected return on plan assets	(3		)	(3		)	(6		)	(6		)
Amortization of prior service credit	(4		)	(5		)	(8		)	(10		)
Amortization of net actuarial loss	1			—			1			—
Reclassification to regulatory liability	1			1			2			2
Net periodic benefit cost (credit)	$	(3	)	$	(4	)	$	(6	)	$	(8	)

Notes (Continued)

Amortization of prior service credit and net actuarial loss included in net periodic benefit cost (credit) for our other postretirement benefit plans associated with Transco and Northwest Pipeline are recorded to regulatory assets/liabilities instead of other comprehensive income (loss). The amounts of amortization of prior service credit recognized in regulatory liabilities were $3 million for the three months ended June 30, 2015 and 2014, respectively, and $5 million and $6 million for the six months ended June 30, 2015 and 2014, respectively.

During the six months ended June 30, 2015, we contributed $32 million to our pension plans and $3 million to our other postretirement benefit plans. We presently anticipate making additional contributions of approximately $32 million to our pension plans and approximately $3 million to our other postretirement benefit plans in the remainder of 2015.

Note 8 – Inventories



	June 30, 2015		December 31, 2014
	(Millions)
Natural gas liquids, olefins, and natural gas in underground storage	$	95	$	150
Materials, supplies, and other	73		81
	$	168	$	231

Note 9 – Debt and Banking Arrangements

Long-Term Debt

Issuances and retirements

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.

Commercial Paper Program

As of June 30, 2015, WPZ had $1,743 million of Commercial paper outstanding under its $3 billion commercial paper program with a weighted average interest rate of 0.55 percent.

Notes (Continued)

Credit Facilities

On February 2, 2015, we entered into a Credit Agreement with aggregate commitments remaining at $1.5 billion, and the credit facilities for Pre-merger WPZ and ACMP were terminated in connection with the Merger. WPZ also entered into a $3.5 billion credit facility.



	June 30, 2015
	Stated Capacity		Outstanding
	(Millions)

WMB
Loans	$	1,500	$	350
Swingline loans sublimit	50		—
Letters of credit sublimit	675		—
Letters of credit under certain bilateral bank agreements			16
WPZ
Loans (1)	3,500		—
Swingline loans sublimit	150		—
Letters of credit sublimit	1,125		—
Letters of credit under certain bilateral bank agreements			3


(1)	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.

On February 3, 2015, WPZ entered into a $1.5 billion short-term credit facility. In accordance with its terms, this facility terminated on March 3, 2015, upon the completion of the previously described debt offering. WPZ did not borrow under this credit facility.

Note 10 – Stockholders’ Equity

The following table presents the changes in Accumulated other comprehensive income (loss) by component, net of income taxes:



	Cash Flow Hedges			Foreign Currency Translation			Pension and Other Post Retirement Benefits			Total
	(Millions)
Balance at December 31, 2014	$	(1	)	$	31		$	(371	)	$	(341	)
Other comprehensive income (loss) before reclassifications	—			(55		)	—			(55		)
Amounts reclassified from accumulated other comprehensive income (loss)	—			—			12			12
Other comprehensive income (loss)	—			(55		)	12			(43		)
Balance at June 30, 2015	$	(1	)	$	(24	)	$	(359	)	$	(384	)

Notes (Continued)

Reclassifications out of Accumulated other comprehensive income (loss) are presented in the following table by

component for the six months ended June 30, 2015:




Component	Reclassifications			Classification
	(Millions)
Pension and other postretirement benefits:
Amortization of prior service cost (credit) included in net periodic benefit cost	$	(3	)	Note 7 – Employee Benefit Plans
Amortization of actuarial (gain) loss included in net periodic benefit cost	22			Note 7 – Employee Benefit Plans
Total pension and other postretirement benefits, before income taxes	19
Income tax benefit	(7		)	Provision (benefit) for income taxes
Reclassifications during the period	$	12

Note 11 – Fair Value Measurements and Guarantees

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 June 30, 2015:
Measured on a recurring basis:
ARO Trust investments	$	63		$	63		$	63	$	—		$	—
Energy derivatives assets designated as hedging instruments	1			1			—		1			—
Energy derivatives assets not designated as hedging instruments	2			2			—		—			2
Energy derivatives liabilities not designated as hedging instruments	(2		)	(2		)	—		—			(2		)
Additional disclosures:
Notes receivable and other	6			14			3		3			8
Long-term debt, including current portion (1)	(21,660		)	(21,635		)	—		(21,635		)	—
Guarantee	(30		)	(25		)	—		(25		)	—

Assets (liabilities) at December 31, 2014:
Measured on a recurring basis:
ARO Trust investments	$	48		$	48		$	48	$	—		$	—
Energy derivatives assets not designated as hedging instruments	3			3			1		—			2
Energy derivatives liabilities not designated as hedging instruments	(2		)	(2		)	—		—			(2		)
Additional disclosures:
Notes receivable and other	30			57			—		4			53
Long-term debt, including current portion (1)	(20,887		)	(21,131		)	—		(21,131		)	—
Guarantee	(31		)	(27		)	—		(27		)	—

___________________________________

(1) Excludes capital leases

Notes (Continued)

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 (ARO Trust) that is specifically designated to fund future asset retirement obligations (ARO). 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 (OTC) 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 Other noncurrent liabilities 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 six months ended June 30, 2015 or 2014.

Additional fair value disclosures

Notes receivable and other: Notes receivable and other consists of various notes, including 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 $8 million at June 30, 2015. We began accounting for the receivable under a cost recovery model in first-quarter 2015, and in second-quarter 2015, we received a payment greater than the carrying amount of the receivable. As a result, the carrying value of this receivable is zero at June 30, 2015. See Note 4 – Other Income and Expenses for interest income associated with this receivable. The current and noncurrent portions of our receivables are reported in Accounts and notes receivable – net, Other current assets and deferred charges, and Regulatory assets, deferred charges, and other, respectively, in the Consolidated Balance Sheet.

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.

Guarantee: The guarantee represented in the table consists 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.

To estimate the disclosed fair value of the 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. This guarantee is reported in Accrued liabilities in the Consolidated Balance Sheet.

Notes (Continued)

Assets measured at fair value on a nonrecurring basis

During the second quarter of 2015, we recorded impairment charges of $20 million for our Williams Partners segment associated with certain surplus equipment reported in Property, plant, and equipment, at cost in the Consolidated Balance Sheet. The estimated fair value of this equipment at June 30, 2015, is $17 million. The estimated fair value is determined by a market approach based on our analysis of observable inputs in the principal market. These impairment charges are recorded in Other (income) expense – net within Costs and expenses in the Consolidated Statement of Income. These nonrecurring fair value measurements fall within Level 3 of the fair value hierarchy. Certain of these assets were previously presented as held for sale, but are now reported as held for use.

Guarantees

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.

Regarding our previously described guarantee of WilTel’s lease performance, the maximum potential exposure is approximately $33 million at June 30, 2015. Our exposure declines systematically throughout the remaining term of WilTel’s obligation.

Note 12 – Contingent Liabilities

Indemnification of WPX

We have agreed to indemnify our former affiliate, WPX and its subsidiaries, related to the following matter.

Reporting of natural gas-related information to trade publications

Direct and indirect purchasers of natural gas in various states filed class actions against WPX 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.

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 future charges 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.

Other Legal Matters

Geismar Incident

As a result of the previously discussed Geismar Incident, there were two fatalities and numerous individuals (including employees and contractors) reported injuries, which varied from minor to serious. We are addressing the following matters in connection with the Geismar Incident.

On October 21, 2013, the 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 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.

Notes (Continued)

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 trial for certain plaintiffs claiming personal injury, that was set to begin on June 15, 2015 in Iberville Parish, Louisiana, has been continued or postponed for at least 120 days. For these and all other unsettled lawsuits, we believe it is probable that additional losses will be incurred, while for the others we believe it is only reasonably possible that losses will be incurred. However, due to ongoing litigation concerning 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 annual limit of $610 million 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.

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 November 26, 2014, the City of North Pole (North Pole) filed suit in Alaska state court in Fairbanks against FHRA and WAPI, alleging nuisance and violations of municipal and state statutes based upon the sulfolane contamination allegedly emanating from the North Pole refinery. North Pole claims an unspecified amount of past and future damages as well as punitive damages against WAPI. FHRA filed cross-claims against us.

Independent of the litigation matter described in the preceding paragraphs, in 2013, the Alaska Department of Environmental Conservation (ADEC) 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. On March 6, 2014, the State of Alaska filed suit against FHRA and us in state court in Fairbanks seeking injunctive relief and damages in connection with the sulfolane contamination. On May 5, 2014, FHRA filed cross-claims against us in the State of Alaska suit, and FHRA also seeks injunctive relief and damages. 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.

Shareholder litigation

In July 2015, a purported stockholder of us filed a putative class and derivative action on behalf of us in the Court of Chancery of the State of Delaware. The action names as defendants certain members of our Board of Directors (Individual Defendants), as well as WPZ, and names us as a nominal defendant. Among other things, the action seeks to enjoin the Acquisition of WPZ Public Units and seeks monetary damages, including the repayment of the $410 million termination fee that may become payable by us, in certain circumstances, if there were a termination of the merger agreement for the Acquisition of WPZ Public Units. The action alleges, among other things, that the Individual Defendants breached their fiduciary duties owed to us and our stockholders by failing to adequately evaluate an

Notes (Continued)

unsolicited proposal to acquire us in an all-equity transaction and by putting their personal interests ahead of the interests of us and our stockholders in connection with that unsolicited proposal. The action further alleges that WPZ aided and abetted the alleged breaches. We cannot reasonably estimate a range of potential loss at this time.

Royalty Matters

Certain of our customers, including one major customer, have been named in various lawsuits alleging underpayment of royalties. In certain of these cases, we have also been named as a defendant 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. We believe that the claims asserted to date are subject to indemnity obligations owed to us by that major customer. Due to the preliminary status of the cases, we are unable to estimate a range of liability at this time.

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 June 30, 2015, we have accrued liabilities totaling $41 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 ground level ozone, one hour nitrogen dioxide emission limits, and new air quality standards impacting storage vessels, pressure valves, and compressors. We are unable to estimate the costs of asset additions or modifications necessary to comply with these new regulations 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 June 30, 2015, we have accrued liabilities of $10 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 June 30, 2015, we have accrued liabilities totaling $8 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

Notes (Continued)

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 June 30, 2015, we have accrued environmental liabilities of $23 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 June 30, 2015, 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.

Note 13 – 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, and Basis of Presentation.)

Performance Measurement

Prior to first quarter of 2015, we evaluated segment operating performance based on Segment profit (loss) from operations. Beginning in the first quarter of 2015, 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. Prior period segment disclosures have been recast to reflect this change.

Notes (Continued)

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);

◦Other investing income (loss) – net;

◦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 table reflects the reconciliation of Segment revenues to Total revenues as reported in the Consolidated Statement of Income and Total assets by reportable segment.



	Williams Partners		Williams NGL & Petchem Services (1)		Other		Eliminations			Total
	(Millions)
Three Months Ended June 30, 2015
Segment revenues:
Service revenues
External	$	1,231	$	1	$	9	$	—		$	1,241
Internal	—		—		38		(38		)	—
Total service revenues	1,231		1		47		(38		)	1,241
Product sales
External	598		—		—		—			598
Internal	1		—		—		(1		)	—
Total product sales	599		—		—		(1		)	598
Total revenues	$	1,830	$	1	$	47	$	(39	)	$	1,839

Three Months Ended June 30, 2014
Segment revenues:
Service revenues
External	$	763	$	—	$	62	$	—		$	825
Internal	—		—		4		(4		)	—
Total service revenues	763		—		66		(4		)	825
Product sales
External	853		—		—		—			853
Internal	—		—		—		—			—
Total product sales	853		—		—		—			853
Total revenues	$	1,616	$	—	$	66	$	(4	)	$	1,678

Six Months Ended June 30, 2015
Segment revenues:
Service revenues
External	$	2,423	$	1	$	14	$	—		$	2,438
Internal	—		—		59		(59		)	—
Total service revenues	2,423		1		73		(59		)	2,438
Product sales
External	1,117		—		—		—			1,117
Internal	1		—		—		(1		)	—
Total product sales	1,118		—		—		(1		)	1,117

Notes (Continued)



	Williams Partners		Williams NGL & Petchem Services (1)		Other		Eliminations			Total
	(Millions)
Total revenues	$	3,541	$	1	$	73	$	(60	)	$	3,555

Six Months Ended June 30, 2014
Segment revenues:
Service revenues
External	$	1,526	$	—	$	118	$	—		$	1,644
Internal	—		—		7		(7		)	—
Total service revenues	1,526		—		125		(7		)	1,644
Product sales
External	1,783		—		—		—			1,783
Internal	—		—		—		—			—
Total product sales	1,783		—		—		—			1,783
Total revenues	$	3,309	$	—	$	125	$	(7	)	$	3,427

June 30, 2015
Total assets	$	50,040	$	731	$	1,064	$	(672	)	$	51,163
December 31, 2014
Total assets	$	49,322	$	612	$	1,220	$	(591	)	$	50,563

_________________


(1)	Includes certain projects under development and thus nominal reported revenues to date.

The following table reflects the reconciliation of Modified EBITDA to Net income (loss) as reported in the Consolidated Statement of Income.



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
	(Millions)
Modified EBITDA by Segment:
Williams Partners	$	1,053		$	596		$	1,870		$	1,304
Williams NGL & Petchem Services	(3		)	(8		)	(8		)	(108		)
Other	(4		)	60			(4		)	118
	1,046			648			1,858			1,314
Accretion expense associated with asset retirement obligations for nonregulated operations	(9		)	(6		)	(15		)	(9		)
Depreciation and amortization expenses	(428		)	(214		)	(855		)	(428		)
Equity earnings (losses)	93			37			144			(11		)
Other investing income (loss) – net	9			18			9			32
Proportional Modified EBITDA of equity-method investments	(183		)	(113		)	(319		)	(141		)
Interest expense	(262		)	(163		)	(513		)	(303		)
(Provision) benefit for income taxes	(83		)	(84		)	(113		)	(135		)
Income (loss) from discontinued operations, net of tax	—			4			—			4
Net income (loss)	$	183		$	127		$	196		$	323

Item 2

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, but span from the deepwater Gulf of Mexico to the Canadian oil sands, 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 June 30, 2015, we own approximately 60 percent of the interests in WPZ, including the interests of the general partner, which is wholly owned by us, and IDRs.

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 interest in Gulfstream and a 41 percent interest in Constitution. As of December 31, 2014, Transco and Northwest Pipeline own and operate a combined total of approximately 13,600 miles of pipelines with a total annual throughput of approximately 3,870 TBtu of natural gas and peak-day delivery capacity of approximately 14 MMdth of natural gas.

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 in the Mid-Continent region, a 69 percent equity-method investment in Laurel Mountain Midstream, LLC, a 58 percent equity-method investment in Caiman Energy II, LLC, a 60 percent equity-method investment in Discovery Producer Services LLC, a 50 percent equity-method investment in Overland Pass Pipeline, LLC, and Appalachia Midstream Services, LLC, which owns an approximate average 45 percent equity-method investment interest in 11 gas gathering systems in the Marcellus Shale.

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 utilizing our low cost-of-capital to invest in growing markets, including the deepwater Gulf of Mexico, the Marcellus Shale, the Gulf Coast Region, the Canadian oil sands, 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

Management’s Discussion and Analysis (Continued)

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 little 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 other domestic olefins pipeline assets and certain Canadian growth projects under development, including a propane dehydrogenation facility and a liquids extraction plant. These projects are under development and thus have had limited operating revenues to date.

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 of this Form 10-Q and our annual consolidated financial statements and notes thereto in Exhibit 99.1 of our Form 8-K dated May 6, 2015.

Dividends

In June 2015, we paid a regular quarterly dividend of $0.59 per share, which was 39 percent higher than the same period last year.

Overview of Six Months Ended June 30, 2015

Net income (loss) attributable to The Williams Companies, Inc., for the six months ended June 30, 2015, decreased $59 million compared to the six months ended June 30, 2014, primarily due to higher depreciation expense caused by significant projects that have gone into service in 2014 and 2015, increased interest expense associated with new debt issuances, as well as declines in NGL margins driven by 59 percent lower prices. These decreases were partially offset by new fee revenue associated with certain growth projects that were placed in service in 2014 and 2015 and the absence of equity losses in 2014 associated with the discontinuance of the Bluegrass Pipeline project. See additional discussion in Results of Operations.

Abundant and low-cost natural gas reserves in the United States continue to drive demand for midstream and pipeline infrastructure. We believe that we have successfully positioned our energy infrastructure businesses for significant future growth.

Acquisition of WPZ Public Units

Strategic Alternatives

On June 21, 2015, we publicly announced in a press release that we had received and subsequently rejected an unsolicited proposal to acquire us in an all-equity transaction. The unsolicited proposal was contingent on the termination of our pending Acquisition of WPZ Public Units. Our Board of Directors has authorized a process to explore a range of strategic alternatives, which could include, among other things, a merger, a sale of us, or continuing to pursue our existing operating and growth plan.

Management’s Discussion and Analysis (Continued)

Williams Partners

Access Merger

On February 2, 2015, we completed a merger of our consolidated master limited partnerships, Pre-merger WPZ and ACMP (Merger). The merged partnership was renamed Williams Partners L.P.

Under the terms of the merger agreement, each ACMP unitholder received 1.06152 ACMP units for each ACMP unit owned immediately prior to the Merger. In conjunction with the Merger, each Pre-merger WPZ common unit held by the public was exchanged for 0.86672 ACMP common units. Each WPZ common unit held by us was exchanged for 0.80036 ACMP common units. Prior to the closing of the Merger, the Class D limited partner units of Pre-merger WPZ, all of which were held by us, were converted into WPZ common units on a one-for-one basis pursuant to the terms of the Pre-merger WPZ partnership agreement. Following the Merger, we own an approximate 60 percent of the merged partnership, including the general partner interest and incentive distribution rights.

Geismar Incident and Plant Expansion

On June 13, 2013, an explosion and fire occurred at William Partners’ Geismar olefins plant. The incident (Geismar Incident) rendered the facility temporarily inoperable and resulted in significant human, financial, and operational effects. The Geismar plant ramped up in the second quarter of 2015 and the expanded plant is now online.

Our total property damage and business interruption loss exceeded our $500 million policy limit. Since June 2013, we have settled claims associated with $480 million of available property damage and business interruption coverage for a total of $422 million. This total includes $126 million which we received in the second quarter of 2015. The remaining insurance limits total approximately $20 million and we are vigorously pursuing collection.

Northeast Connector

In May 2015, the Northeast Connector project was placed into service, which increased additional firm transportation capacity to 100 Mdth/d from Transco’s Station 195 in southeastern Pennsylvania to the Rockaway Delivery Lateral.

Rockaway Delivery Lateral

In May 2015, Transco’s Rockaway Delivery Lateral expansion between William’s Transco transmission pipeline and the National Grid distribution system was placed in service, which enabled us to begin providing 647 Mdth/d of additional firm transportation service to a distribution system in New York.

Mobile Bay South III

In April 2015, Transco’s Mobile Bay South III expansion south from Station 85 in west central Alabama to delivery points along the line was placed into service, which enabled us to begin providing 225 Mdth/d of additional firm transportation service on the Mobile Bay Lateral.

Bucking Horse Gas Processing Facility

The Bucking Horse gas processing plant (Bucking Horse) began operating in February 2015. Bucking Horse, is located in Converse County, Wyoming, and adds 120 MMcf/d of processing capacity in the Powder River basin Niobrara Shale play. Processed volumes at Bucking Horse have continued to increase through the second quarter of 2015 as existing rich gas production was re-directed from other third-party processing facilities. Bucking Horse has led to higher gathering volumes as previously curtailed production has increased due to the additional processing capability.

Management’s Discussion and Analysis (Continued)

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 capable of handling up to 100 MMcf/d in the Eagle Ford shale for $112 million. The acquisition will immediately contribute approximately 20 MMcf/d to the existing Eagle Ford throughput of approximately 400 MMcf/d.

UEOM

In June 2015, WPZ acquired an approximate 13 percent equity interest in UEOM for approximately $357 million, increasing our ownership from 49 percent to approximately 62 percent.

Volatile commodity prices

NGL margins were approximately 59 percent lower in the first six months of 2015 compared to the same period of 2014 driven primarily by 60 percent lower non-ethane prices partially offset by lower natural gas feedstock prices.

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 effects of margin volatility and NGL production and sales volumes, as well as the margin differential between ethane and non-ethane products and the relative mix of those products.

Management’s Discussion and Analysis (Continued)

The potential impact of commodity price changes on our business for the remainder of 2015 is further discussed in the following Company Outlook.

Williams NGL & Petchem Services

Texas Belle Pipeline

In March 2015, the Texas Belle Pipeline (Texas Belle) went into service in the Houston Ship Channel area. Texas Belle is a 32-mile pipeline that transports NGLs and was designed to deliver butanes and natural gasolines from Mont Belvieu, Texas, to new demand in the Houston Ship Channel area. Texas Belle is one of several projects under development that will provide open access, service-focused purity NGL and olefin transportation options to customers that have traditionally been primarily served by proprietary pipeline systems. These projects are a collection of pipeline systems developed in collaboration with producers and consumers to connect new supply sources to growing demand throughout the Gulf Coast region.

Company Outlook

As previously discussed, we are currently evaluating a range of strategic alternatives that could include, among other things, a merger, a sale of us, or continuing to pursue our existing operating and growth plan. The following discussion reflects continued pursuit of our existing operating and growth plan.

Our strategy is to provide large-scale energy infrastructure designed to maximize the opportunities created by the vast supply of natural gas, natural gas products, and crude oil that exists in North America. We seek to accomplish this through further developing our scale positions in current key markets and basins and entering new growth markets and basins where we can become the large-scale service provider. We will maintain a strong commitment to safety, environmental stewardship, operational excellence and customer satisfaction. We believe that accomplishing these goals will position us to deliver an attractive return to our shareholders.

Following the sharp decline in energy commodity prices in fourth quarter 2014, we expect crude oil, NGLs, and olefins prices to remain at lower levels throughout 2015 as compared to 2014 average prices, which will have an adverse effect on our operating results and cash flows. Fee-based businesses are a significant component of our portfolio and have further increased as a result of the ACMP Acquisition. This serves to somewhat reduce the influence of commodity price fluctuations on our operating results and cash flows. However, we anticipate producer activities will be impacted by lower natural gas prices which may reduce our gathering and processing volumes from the current levels.

Our business plan for 2015 continues to reflect both significant capital investment and continued dividend growth as compared to 2014. We continue to manage expenditures as appropriate without compromising safety and compliance. Our planned consolidated capital investments for 2015 total between $3.96 billion and $4.59 billion. We expect to maintain an attractive cost of capital and reliable access to capital markets, both of which will allow us to pursue development projects and acquisitions.

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


•	General economic, financial markets, or industry downturn;


•	Lower than anticipated energy commodity prices and margins;


•	Decreased volumes from third parties served by our midstream business;


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


•	Lower than expected distributions, including IDRs, from WPZ. WPZ’s liquidity could also be impacted by a lack of adequate access to capital markets to fund its growth;


•	Limited availability of capital due to a change in our financial condition, interest rates, market or industry conditions;

Management’s Discussion and Analysis (Continued)


•	Downgrade of our credit ratings and associated increase in cost of borrowings;


•	Counterparty credit and performance risk;


•	Changes in the political and regulatory environments;


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


•	Reduced availability of insurance coverage.

We continue to address these risks through disciplined investment strategies, sufficient liquidity from cash and cash equivalents and available capacity under our credit facilities.

In 2015, we anticipate an overall improvement in operating results compared to 2014 primarily due to increases in olefins volumes associated with the repair and expansion of the Geismar plant and in our fee-based businesses primarily as a result of the ACMP Acquisition, partially offset by lower NGL margins and higher operating expenses associated with the growth of our business.

The following factors, among others, could impact our businesses in 2015.

Commodity price changes

NGL and olefin price changes have historically correlated somewhat with changes in the price of crude oil, although NGL, olefin, crude, and natural gas prices are highly volatile, and difficult to predict. Commodity margins are highly dependent upon regional supply/demand balances of natural gas as they relate to NGL margins, while olefins are impacted by global supply and demand fundamentals. NGL products are currently the preferred feedstock for ethylene and propylene production, and are expected to remain advantaged over crude-based feedstocks into the foreseeable future. We continue to benefit from our strategic feedstock cost advantage in propylene production from Canadian oil sands offgas.

Following the sharp decline in overall energy commodity prices in the fourth quarter of 2014, we anticipate the following trends in 2015, compared to 2014:


•	Natural gas and ethane prices are expected to be lower primarily due to higher inventory levels in the marketplace.


•	Non-ethane prices, including propane, are expected to be lower primarily due to oversupply and the sharp decline in crude oil prices.


•	Olefins prices, including propylene, ethylene, and the overall ethylene crack spread, are expected to be lower than 2014 levels due to the lower prices of crude oil and correlated products.

Gathering, transportation, processing, and NGL sales volumes

The growth of natural gas production supporting our gathering and processing volumes is impacted by producer drilling activities, which are influenced by commodity prices, including natural gas, ethane and propane prices. In addition, the natural decline in production rates in producing areas impact the amount of gas available for gathering and processing.


•	Following the ACMP Acquisition, we began consolidating our Access Midstream business’ results of operations effective July 1, 2014. As such, we expect an increase in overall results for our Access Midstream business in 2015 compared to 2014 associated with a full year of consolidated results.


•	In the Gulf Coast region, we expect higher production handling volumes in 2015, following the completion of Gulfstar FPS in the fourth quarter of 2014.

Management’s Discussion and Analysis (Continued)


•	We anticipate higher natural gas transportation revenues at Transco compared to 2014, as a result of expansion projects placed into service in 2014 and anticipated to be placed in service in 2015.


•	In the northeast region, we anticipate growth in our natural gas gathering volumes compared to the prior year as our infrastructure grows to support producer activities in the region.


•	Volumes in the Haynesville area at our Access Midstream business are expected to be higher in 2015 as compared to 2014 primarily due to an increase in well connections in the area.


•	We expect an increase in volumes in 2015, as compared to 2014 at our Access Midstream business in the Utica area primarily due to the build out of the Cardinal system, relieving compression constraints and adding new well connections.


•	In the western region, we anticipate an unfavorable impact in NGL margins in 2015 compared to 2014, primarily due to the sharp decline in NGL prices.


•	In 2015, our domestic businesses anticipate a continuation of periods when it will not be economical to recover ethane.

Olefin production volumes


•	Our Gulf olefins business anticipates higher ethylene volumes in 2015 compared to 2014 substantially due to the repair and expansion of the Geismar plant, which returned to operations in late March.

Other

•

Operating results from our equity-method investments are expected to be higher in 2015 compared to 2014 primarily due to the completion of Discovery’s Keathley Canyon Connector lateral in the first quarter of 2015 and an anticipated increase in volumes as well as our increased ownership interest in UEOM. These increases are offset by an expected decrease in results from our equity-method investment in the Delaware basin gas gathering system primarily due to a redetermination of rates in association with a contract extension.


•	Amounts recognized under minimum volume commitments at our Access Midstream business in the Barnett area are expected to increase in 2015 compared to 2014.


•	We expect higher operating expenses in 2015 compared to 2014, related to our growing operations in the northeast region and expansion projects at Transco, partially offset by cost reductions and synergies associated with the ACMP Acquisition.

Expansion Projects

We expect to invest between $3.47 billion and $4.1 billion of capital among our business segments in 2015. Our ongoing major expansion projects include the following:

Williams Partners

Access Midstream Projects

We plan to expand our gathering infrastructure in the Eagle Ford, Mid-Continent, Utica, and Marcellus shale regions 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.

Management’s Discussion and Analysis (Continued)

Oak Grove Expansion

We plan to expand our processing capacity at our Oak Grove facility by adding a second 200MMcf/d cryogenic natural gas processing plant, which, based on our customers’ needs, is expected to be placed into service at the end of 2016.

Susquehanna Supply Hub

We will continue to expand the gathering system in the Susquehanna Supply Hub in northeastern Pennsylvania that is needed to meet our customers’ production plans. The expansion of the gathering infrastructure includes additional compression and gathering pipeline to the existing system.

Atlantic Sunrise

In March 2015, we filed an application with 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 plan to place the project into service during the second half of 2017, assuming timely receipt of all necessary regulatory approvals, and it is expected to increase capacity by 1,700 Mdth/d.

Leidy Southeast

In December 2014, we received approval from the FERC to expand Transco’s existing natural gas transmission system from the Marcellus Shale production region on Transco’s Leidy Line in Pennsylvania to delivery points along its mainline as far south as Station 85 in west central Alabama. In March 2015, we began providing firm transportation service through the mainline portion of the project on an interim basis, until the in-service date of the project as a whole. We plan to place the remainder of the project into service during the fourth quarter of 2015 and expect it to increase capacity by 525 Mdth/d.

Constitution Pipeline

In December 2014, we received approval from the FERC to construct and operate the jointly owned Constitution pipeline. We also received a Notice of Complete Application from the New York Department of Environmental Conservation in December 2014. 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 124-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. We plan to place the project into service in the second half of 2016, with an expected capacity of 650 Mdth/d.

Virginia Southside

In November 2013, we received approval from the FERC to expand Transco’s existing natural gas transmission system from New Jersey to a proposed power station in Virginia and delivery points in North Carolina. In December 2014, we placed a portion of the project into service, which enabled us to begin providing 250 Mdth/d of additional firm transportation service through the mainline portion of the project on an interim basis, until the in-service date of the project as a whole. We plan to place the remainder of the project into service during the third quarter of 2015. In total, the project is expected to increase capacity by 270 Mdth/d.

Rock Springs

In March 2015, we received approval from the FERC to expand Transco’s existing natural gas transmission system from New Jersey to a proposed generation facility in Maryland. The project is planned to be placed into service in third quarter 2016, assuming timely receipt of all other necessary regulatory approvals, and is expected to increase capacity by 192 Mdth/d.

Management’s Discussion and Analysis (Continued)

Hillabee

In November 2014, we filed an application with the FERC for approval of the initial phases of Transco’s Hillabee Expansion project, which involves an expansion of its existing natural gas transmission system from Station 85 in west central Alabama to a proposed new interconnection with Sabal Trail Transmission's system in Alabama. The project will be constructed in phases, and all of the project expansion capacity will be leased to Sabal Trail Transmission. We plan to place the initial phases of the project into service during the second quarters of 2017 and 2020, assuming timely receipt of all necessary regulatory approvals, and together they are expected to increase capacity by 1,025 Mdth/d.

Gulf Trace

In December 2014, we filed an application with the FERC to expand 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 westward to a new interconnection with Sabine Pass Liquefaction in Cameron Parish, Louisiana. We plan to place the project into service during the first half of 2017, assuming timely receipt of all necessary regulatory approvals, and it is expected to increase capacity by 1,200 Mdth/d.

Dalton

In March 2015, we filed an application with 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, assuming timely receipt of all necessary regulatory approvals, and it is expected to increase capacity by 448 Mdth/d.

Garden State

In February 2015, we filed an application with 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 fourth quarter of 2016 and the remaining portion in the third quarter of 2017, assuming timely receipt of all necessary regulatory approvals.

Virginia Southside II

In March 2015, we filed an application with the FERC to expand Transco’s existing natural gas transmission system together with greenfield facilities to provide incremental firm transportation capacity from New Jersey and Virginia to our Brunswick Lateral in Virginia. We plan to place the project into service during the fourth quarter of 2017, assuming timely receipt of all necessary regulatory approvals, and expect it to increase capacity by 250 Mdth/d.

New York Bay

In July 2015, we filed an application with 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, assuming timely receipt of all necessary regulatory approvals, and it is expected to increase capacity by 115 Mdth/d.

Redwater Expansion

As part of a long-term agreement to provide gas processing services to a second bitumen upgrader in Canada’s oil sands near Fort McMurray, Alberta, we are increasing the capacity of the Redwater facilities where NGL/olefins mixtures will be fractionated into an ethane/ethylene mix, propane, polymer grade propylene, normal butane, an alkylation feed and condensate. This capacity increase is expected to be placed into service during the fourth quarter of 2015.

Management’s Discussion and Analysis (Continued)

Williams NGL & Petchem Services

Canadian PDH Facility

We are planning to build a PDH facility in Alberta that will significantly increase production of polymer-grade propylene. Start-up for the PDH facility is expected to occur in the second half of 2019. The new PDH facility is expected to produce approximately 1.1 billion pounds annually, significantly increasing Williams’ production of polymer-grade propylene currently at 180 million pounds annually.

Canadian NGL Infrastructure Expansion

As part of a long-term agreement to provide gas processing to a second bitumen upgrader in Canada’s oil sands near Fort McMurray, Alberta, we are building a new liquids extraction plant and an interconnection with the Boreal Pipeline, owned by our Williams Partners segment. The interconnection will enable transportation of the NGL/olefins mixture on the Boreal pipeline from the new liquids extraction plant to the Redwater facilities, owned by our Williams Partners segment. We plan to place the new liquids extraction plant and interconnection with Boreal into service during the fourth quarter of 2015, and expect initial NGL/olefins recoveries of approximately 12 Mbbls/d. To mitigate ethane price risk associated with our processing services, we have a long-term agreement for ethane sales to a third-party customer.

Gulf Coast NGL and Olefin Infrastructure Expansion

In November 2012, we acquired 10 liquids pipelines in the Gulf Coast region. The acquired pipelines will 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. The Texas Belle pipeline started providing isobutane service in the first quarter of 2015 and is expected to be available for natural gasoline service in the first quarter of 2016. Additional projects under development and/ or construction are expected to be placed into service in 2016 and 2017.

Management’s Discussion and Analysis (Continued)

Results of Operations

Consolidated Overview

The following table and discussion is a summary of our consolidated results of operations for the three and six months ended June 30, 2015, compared to the three and six months ended June 30, 2014. The results of operations by segment are discussed in further detail following this consolidated overview discussion.



	Three Months Ended June 30,									Six Months Ended June 30,
	2015			2014			$ Change*	% Change*		2015			2014			$ Change*	% Change*
	(Millions)									(Millions)
Revenues:
Service revenues	$	1,241		$	825		+416	+50	%	$	2,438		$	1,644		+794	+48	%
Product sales	598			853			-255	-30	%	1,117			1,783			-666	-37	%
Total revenues	1,839			1,678						3,555			3,427
Costs and expenses:
Product costs	494			724			+230	+32	%	956			1,493			+537	+36	%
Operating and maintenance expenses	437			308			-129	-42	%	824			606			-218	-36	%
Depreciation and amortization expenses	428			214			-214	-100	%	855			428			-427	-100	%
Selling, general, and administrative expenses	174			136			-38	-28	%	370			286			-84	-29	%
Net insurance recoveries – Geismar Incident	(126		)	(42		)	+84	+200	%	(126		)	(161		)	-35	-22	%
Other (income) expense – net	40			27			-13	-48	%	57			44			-13	-30	%
Total costs and expenses	1,447			1,367						2,936			2,696
Operating income (loss)	392			311						619			731
Equity earnings (losses)	93			37			+56	+151	%	144			(11		)	+155	NM
Other investing income (loss) – net	9			18			-9	-50	%	9			32			-23	-72	%
Interest expense	(262		)	(163		)	-99	-61	%	(513		)	(303		)	-210	-69	%
Other income (expense) – net	34			4			+30	NM		50			5			+45	NM
Income (loss) from continuing operations before income taxes	266			207						309			454
Provision (benefit) for income taxes	83			84			+1	+1	%	113			135			+22	+16	%
Income (loss) from continuing operations	183			123						196			319
Income (loss) from discontinued operations	—			4			-4	-100	%	—			4			-4	-100	%
Net income (loss)	183			127						196			323
Less: Net income (loss) attributable to noncontrolling interests	69			24			-45	-188	%	12			80			+68	+85	%
Net income (loss) attributable to The Williams Companies, Inc.	$	114		$	103					$	184		$	243


*	+ = 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.

Management’s Discussion and Analysis (Continued)

Three months ended June 30, 2015 vs. three months ended June 30, 2014

Service revenues increased primarily due to contributions from operations acquired in the ACMP Acquisition in third quarter 2014. Additionally, production handling, gathering, processing, and transportation fee revenue all increased related to construction projects that have been placed into service, including Gulfstar One in the fourth quarter of 2014, expansion projects placed in service by Transco in late 2014 and in 2015, and new well connections and the completion of various compression projects in the Northeast. A decrease in Canadian construction management revenues reflecting a shift to internal customer construction projects partially offset these increases.

Product sales decreased primarily due to lower marketing sales driven by lower prices across all products, partially offset by higher non-ethane volumes. Equity NGL sales also decreased associated with sharp declines in NGL prices, partially offset by higher NGL volumes. These decreases were partially offset by higher olefin sales associated with the Geismar plant that returned to operations in late March 2015.

Product costs decreased primarily due to lower marketing purchases related to lower per-unit costs partially offset by higher non-ethane volumes. Natural gas purchases associated with the production of equity NGLs also decreased primarily related to lower natural gas prices, partially offset by higher volumes. These decreases were partially offset by an increase in olefin feedstock purchases primarily related to the Geismar plant return to operations.

Operating and maintenance expenses increased primarily due to new expenses associated with operations acquired in the ACMP Acquisition, the return to operations of the Geismar plant, and new projects placed in service, as well as planned maintenance at our Canadian facilities. These increases are partially offset by a decrease in Canadian construction management expenses that reflects a shift to internal customer construction projects.

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

Selling, general, and administrative expenses increased primarily due to new expenses associated with operations acquired in the ACMP Acquisition, including $13 million of merger and transition-related costs recognized in 2015, as well as $7 million of costs associated with exploring potential strategic alternatives.

Net insurance recoveries – Geismar Incident changed favorably primarily due to the receipt of $126 million of insurance recoveries in 2015 as compared to the receipt of $50 million of insurance recoveries in 2014.

Other (income) expense – net within Operating income (loss) changed unfavorably primarily due to $24 million of impairments of certain assets at Williams Partners in 2015 compared to $17 million in 2014.

Operating income (loss) changed favorably primarily due to increased service revenues at Williams Partners related to construction projects placed in service, higher insurance recoveries related to the Geismar Incident, contributions from the operations acquired in the ACMP Acquisition, and $34 million higher olefin margins primarily due to $50 million of margins contributed by our Geismar plant that returned to operations in 2015. These increases were partially offset by higher operating, maintenance, and depreciation expenses related to construction projects placed in service and the start-up of the Geismar plant, $56 million lower NGL margins driven by lower prices, 2015 costs related to WPZ’s merger and integration of ACMP, and higher impairments as previously discussed.

Equity earnings (losses) changed favorably primarily due to $42 million related to contributions from Appalachia Midstream Investments and UEOM acquired in the ACMP Acquisition and a $25 million increase at Discovery primarily related to the completion of the Keathley Canyon Connector in early 2015.

Interest expense increased due to an $86 million increase in Interest incurred primarily due to new debt issuances in 2014 and 2015 and new interest expense associated with debt assumed in conjunction with the ACMP Acquisition, partially offset by the absence of a $9 million ACMP Acquisition-related financing fee incurred in the second quarter of 2014 and lower interest due to 2015 debt retirements. In addition, Interest capitalized decreased $13 million primarily related to construction projects that have been placed into service, partially offset by new capitalized interest associated with assets acquired in the ACMP Acquisition. (See Note 2 – Acquisitions and Note 9 – Debt and Banking Arrangements of Notes to Consolidated Financial Statements.)

Management’s Discussion and Analysis (Continued)

Other income (expense) – net below Operating income (loss) changed favorably primarily due to a $14 million gain on early debt retirement in April 2015, as well as a $12 million benefit related to an increase in allowance for equity funds used during construction (AFUDC) associated with an increase in spending on various Transco expansion projects and Constitution.

Provision (benefit) for income taxes changed favorably primarily due to the absence of a second-quarter 2014 provision associated with a revision of our estimate of the undistributed earnings related to the contribution of certain Canadian operations to WPZ, partially offset by higher pretax income in 2015. See Note 5 – Provision (Benefit) for Income Taxes of Notes to Consolidated Financial Statements for a discussion of the effective tax rate compared to the federal statutory rate for both periods.

The increase in Net income (loss) attributable to noncontrolling interests related to our investment in WPZ is primarily due to improved operating results at WPZ and higher noncontrolling interest ownership percentages, partially offset by the impact of increased income allocated to the WPZ general partner, held by us, associated with IDRs. In addition, there was an increase related to our investment in Gulfstar One associated with its start up in 2014 and an increase related to our investments in Cardinal and Jackalope due to the consolidation of these entities following the ACMP Acquisition in third quarter 2014.

Six months ended June 30, 2015 vs. six months ended June 30, 2014

Service revenues increased primarily due to contributions from operations acquired in the ACMP Acquisition in third quarter 2014. Additionally, production handling, gathering, processing, and transportation fee revenue all increased related to construction projects that have been placed into service, including Gulfstar One in the fourth quarter of 2014, expansion projects placed in service by Transco in late 2014 and in 2015, and new well connections and the completion of various compression projects in the Northeast. A decrease in Canadian construction management revenues reflect a shift to internal customer construction projects partially offset these increases.

Product sales decreased primarily due to lower marketing sales driven by lower prices across all products, partially offset by higher non-ethane NGL volumes. Equity NGL sales also decreased associated with a decline in NGL prices, partially offset by higher NGL volumes. These decreases were partially offset by an increase in olefin sales primarily due to the resumption of our Geismar operations.

Product costs decreased primarily due to lower marketing costs related to lower per-unit costs across all products, partially offset by higher non-ethane volumes, as well as a decrease in natural gas purchases associated with the production of equity NGLs driven by lower per-unit natural gas costs as a result of the significant decline in energy commodity prices during the fourth quarter of 2014, partially offset by higher volumes. These decreases were partially offset by an increase in olefin feedstock purchases primarily related to the Geismar plant return to operations.

Operating and maintenance expenses increased primarily due to new expenses associated with operations acquired in the ACMP Acquisition, the return to operations of the Geismar plant in addition to new projects placed in service, and planned maintenance at our Canadian facilities. These increases are partially offset by a decrease in Canadian construction management expenses that reflect a shift to internal customer construction projects.

Selling, general, and administrative expenses increased primarily due to new expenses associated with operations acquired in the ACMP Acquisition, including $47 million of merger and transition-related costs recognized in 2015, as well as $7 million of costs associated with exploring potential strategic alternatives. These increases are partially offset by the absence of $19 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 attributable to noncontrolling interests.

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 $175 million of insurance recoveries in 2014.

Management’s Discussion and Analysis (Continued)

Other (income) expense – net within Operating income changed unfavorably primarily due to $27 million of impairments of certain assets at Williams Partners in 2015 compared to $17 million in 2014.

Operating income (loss) changed unfavorably primarily due to higher operating, maintenance, and depreciation expenses related to construction projects placed in service and the start-up of the Geismar plant, $118 million lower NGL margins driven by lower prices, 2015 costs related to WPZ’s merger and integration of ACMP, lower insurance recoveries related to the Geismar Incident, lower marketing margins, and higher impairments as previously discussed. These decreases were partially offset by increased service revenues at Williams Partners related to construction projects placed in service, contributions from the operations acquired in the ACMP Acquisition, the absence of 2014 Bluegrass project development costs, and $15 million higher olefin margins primarily due to $44 million of margins contributed by our Geismar plant that returned to operations in 2015, partially offset by lower olefin margins at our RGP splitter and at our Canadian operations.

Equity earnings (losses) changed favorably primarily due to the absence of $79 million of equity losses from Bluegrass Pipeline and Moss Lake in 2014 related primarily to the underlying write-off of previously capitalized project development costs. In addition, contributions from Appalachia Midstream Investments and UEOM acquired in the ACMP Acquisition increased 2015 equity earnings by $77 million and a $23 million increase at Discovery is primarily related to the completion of the Keathley Canyon Connector in early 2015. These increases are partially offset by the absence of 2014 equity earnings related to our former equity investment in ACMP and our share of impairments recorded by Laurel Mountain in 2015.

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 $190 million increase in Interest incurred primarily due to new debt issuances in 2014 and 2015 and new interest expense associated with debt assumed in conjunction with the ACMP Acquisition. This increase was partially offset by the absence of a $9 million of ACMP Acquisition transaction-related financing fee incurred in the second quarter of 2014 and lower interest due to 2015 debt retirements. In addition, Interest capitalized decreased $20 million primarily related to construction projects that have been placed into service, partially offset by new capitalized interest attributable to ACMP.

Other income (expense) – net below Operating income (loss) changed favorably primarily due to a $26 million benefit related to an increase in allowance for equity funds used during construction (AFUDC) associated with an increase in spending on various Transco expansion projects and Constitution, as well as a $14 million gain on early debt retirement in April 2015.

Provision (benefit) for income taxes changed favorably primarily due to lower pretax income. See Note 5 – Provision (Benefit) for Income Taxes of Notes to Consolidated Financial Statements for a discussion of the effective tax rate compared to the federal statutory rate for both periods.

The decrease in Net income (loss) attributable to noncontrolling interests related to our investment in WPZ is primarily due to lower operating results at WPZ, the impact of increased income allocated to the WPZ general partner, held by us, associated with IDRs, and the impact of increased income allocated to WPZ’s Class D units, held by us, related to the accelerated amortization of a beneficial conversion feature in advance of the Merger. These are offset with an increase related to our investment in Gulfstar One associated with its start up in 2014, an increase related to our former investment in Bluegrass Pipeline associated with our partner’s share of 2014 project development costs expensed by Bluegrass Pipeline, and an increase related to our investments in Cardinal and Jackalope due to consolidation of these entities following the ACMP Acquisition in third quarter 2014.

Period-Over-Period Operating Results - Segments

Beginning in the first quarter of 2015, we evaluate segment operating performance based upon Modified EBITDA. Note 13 – 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

Management’s Discussion and Analysis (Continued)

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



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
	(Millions)
Segment revenues	$	1,830		$	1,616		$	3,541		$	3,309
Segment costs and expenses	(1,086		)	(1,124		)	(2,116		)	(2,282		)
Net insurance recoveries – Geismar Incident	126			42			126			161
Proportional Modified EBITDA of equity-method investments	183			62			319			116
Williams Partners Modified EBITDA	$	1,053		$	596		$	1,870		$	1,304

Three months ended June 30, 2015 vs. three months ended June 30, 2014

Modified EBITDA increased primarily due to the acquisition of ACMP during the third quarter of 2014, resuming our Geismar operations, an increase in net insurance recoveries associated with the Geismar Incident, and initiating service of Gulfstar One during fourth quarter 2014. Partially offsetting these increases are decreases in NGL margins as a result of a significant decline in energy commodity prices that began during the fourth quarter of 2014. A more detailed discussion of Segment revenues and Segment costs and expenses follows.

The increase in Segment revenues includes:

•

A $468 million increase in service revenues primarily due to $352 million additional revenues associated with the ACMP Acquisition during 2014, $66 million in increased revenues associated with the start-up of operations at Gulfstar One during the fourth quarter of 2014, and $31 million in higher fees associated with increased volumes and additional contributions from expanded processing facilities at Williams Partners’ northeast gathering and processing operations. Additionally, service revenues reflect a $38 million increase in natural gas transportation fees due to new Transco projects placed in service in 2014 and 2015.


•	A $65 million increase in olefin sales primarily due to resuming our Geismar operations.


•	A $245 million decrease in marketing revenues primarily associated with lower prices across all products, partially offset by higher volumes (more than offset in marketing purchases).


•	A $77 million decrease in revenues from our equity NGLs reflecting a decrease of $89 million due to lower NGL prices, partially offset by a $12 million increase associated with higher NGL volumes.

The decrease in Segment costs and expenses includes:


•	A $249 million decrease in marketing purchases primarily due to a decrease in per-unit costs, partially offset by higher volumes (substantially offset in marketing revenues).


•	A $21 million decrease in the costs associated with the production of equity NGLs primarily due to decreased natural gas prices.


•	A $14 million gain associated with early retirement of certain debt.


•	A $12 million benefit related to an increase in AFUDC related to an increase in spending on various Transco expansion projects and Constitution.

Management’s Discussion and Analysis (Continued)


•	A $176 million increase in operating costs primarily due to new expenses associated with operations acquired in the ACMP Acquisition, additional costs associated with resuming our Geismar operations and increased maintenance and repair expenses.


•	A $32 million increase in olefin feedstock purchases primarily due to resuming our Geismar operations.


•	A $28 million increase in SG&A primarily due to additional expenses associated with operations acquired in the ACMP Acquisition.


•	An increase in other costs including $24 million of impairments of certain assets in 2015 compared to $17 million in 2014.

Six months ended June 30, 2015 vs. six months ended June 30, 2014

Modified EBITDA increased primarily due to the acquisition of ACMP during the third quarter of 2014, initiating service of Gulfstar One during the fourth quarter 2014 and increased fee revenue associated with contributions from new and expanded facilities. Partially offsetting these increases to modified EBITDA is the reduction of insurance recoveries related to the Geismar Incident and a decrease in NGL margins as a result of a significant decline in energy commodity prices beginning in the fourth quarter of 2014. A more detailed discussion of Segment revenues and Segment costs and expenses follows.

The increase in Segment revenues includes:

•

An $897 million increase in service revenues primarily due to $666 million additional revenues associated with the ACMP Acquisition during 2014, $122 million in increased revenues associated with the start-up of operations at Gulfstar One during the fourth quarter of 2014, and $73 million in higher fees associated with increased volumes and additional contributions from expanded processing facilities at Williams Partners’ northeast gathering and processing operations. Additionally, service revenues reflect a $58 million increase in natural gas transportation fees due to new Transco projects placed in service in 2014 and 2015.


•	A $58 million increase in olefin sales primarily due to resuming our Geismar operations during 2015.


•	A $538 million decrease in marketing revenues primarily associated with lower prices across all products, partially offset by higher volumes (substantially offset in marketing purchases).


•	A $167 million decrease in revenues from our equity NGLs reflecting a decrease of $206 million due to lower NGL prices, partially offset by a $39 million increase associated with higher NGL volumes.


•	An $18 million decrease in revenues associated with various other products.

The decrease in Segment costs and expenses includes:


•	A $527 million decrease in marketing purchases primarily due to a decrease in per-unit costs, partially offset by higher volumes (more than offset in marketing revenues).


•	A $48 million decrease in the costs associated with the production of equity NGLs primarily due to decreased natural gas prices.


•	A $26 million benefit related to an increase in AFUDC related to an increase in spending on various Transco expansion projects and Constitution.

Management’s Discussion and Analysis (Continued)


•	A $14 million gain associated with early retirement of certain debt.


•	A $306 million increase in operating costs primarily due to new expenses associated with operations acquired in the ACMP Acquisition, resuming operations at our Geismar facility and increased maintenance and repair expenses.


•	A $91 million increase in SG&A primarily due to additional expenses associated with operations acquired in the ACMP Acquisition, including $32 million of merger and transition-related costs recognized in 2015.


•	A $43 million increase in olefin feedstock purchases associated with resuming our Geismar operations.


•	An increase in other costs including $27 million of impairments of certain assets in 2015 compared to $17 million in 2014.

The increase in Proportional Modified EBITDA of equity-method investments is primarily due to investments acquired in the ACMP Acquisition and higher Discovery earnings associated with increased fees attributable to the completion of the Keathley Canyon Connector in the first quarter of 2015. Additionally, Caiman II reflects higher earnings of $8 million due to the return to service of a plant that was damaged for a period in 2014 and the results of assets placed into service in 2014 and 2015. Partially offsetting these increases were $14 million lower earnings at Laurel Mountain resulting primarily from $9 million of impairments, and lower gathering fees resulting from lower gathering rates indexed to natural gas prices.

Williams NGL & Petchem Services



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
	(Millions)
Segment revenues	$	1		$	—		$	1		$	—
Segment costs and expenses	(4		)	(6		)	(9		)	(29		)
Proportional Modified EBITDA of equity-method investments	—			(2		)	—			(79		)
Williams NGL & Petchem Services Modified EBITDA	$	(3	)	$	(8	)	$	(8	)	$	(108	)

Three months ended June 30, 2015 vs. three months ended June 30, 2014

The favorable change in Modified EBITDA is due primarily to the absence of equity losses from Bluegrass Pipeline and Moss Lake as well as costs incurred during the second quarter of 2014 related to the development of the Bluegrass Pipeline.

Six months ended June 30, 2015 vs. six months ended June 30, 2014

The favorable change in Modified EBITDA is due primarily to the absence of equity losses from Bluegrass Pipeline and Moss Lake as well as costs incurred during the first quarter of 2014 related to the development of the Bluegrass Pipeline.

Segment costs and expenses decreased primarily due to $19 million of project development costs during the first quarter of 2014 related to the Bluegrass Pipeline and higher development costs related to other projects.

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

Management’s Discussion and Analysis (Continued)

Other



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
	(Millions)
Segment revenues	$	47		$	66		$	73		$	125
Segment costs and expenses	(51		)	(59		)	(77		)	(111		)
Proportional Modified EBITDA of equity-method investment	—			53			—			104
Other Modified EBITDA	$	(4	)	$	60		$	(4	)	$	118

Modified EBITDA decreased as the results from the businesses acquired in the ACMP Acquisition are presented within Williams Partners for periods subsequent to the July 1, 2014, acquisition. For periods prior to that date, Other includes the proportional Modified EBITDA of our former equity-method investment in ACMP.

The decrease in Segment revenues and Segment costs and expenses reflect a shift from external service contracts to internal services provided by our Canadian construction management company, partially offset by costs associated with integration and re-alignment of resources with the ACMP transaction, and costs associated with exploring potential strategic alternatives.

The three and six months ended June 30, 2014 included Proportional Modified EBITDA of equity-method investment related to our investment in ACMP that we accounted for as an equity-method investment for the first half of 2014. (See Note 2 – Acquisitions of Notes to Consolidated Financial Statements.)

Management’s Discussion and Analysis (Continued)

Management’s Discussion and Analysis of Financial Condition and Liquidity

Outlook

We seek to manage our businesses with a focus on applying conservative financial policy in order to maintain investment-grade credit metrics. We continue to transition to an overall business mix that is increasingly fee-based. Although our cash flows are impacted by fluctuations in energy commodity prices, that impact is somewhat mitigated by certain of our cash flow streams that are not directly impacted by short-term commodity price movements, including:


•	Firm demand and capacity reservation transportation revenues under long-term contracts;


•	Fee-based revenues from certain gathering and processing services.

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.

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 2015. 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, including cash distributions from WPZ and our equity-method investees based on our level of ownership and incentive distribution rights;


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


•	Use of our credit facility.

These sources are available to us at either the parent or subsidiary level, as applicable, and are expected to be available to certain of our subsidiaries, particularly equity and debt issuances. WPZ is expected to be self-funding through its cash flows from operations, its credit facility and/or commercial paper program, and its access to capital markets. We anticipate our more significant uses of cash to be:


•	Maintenance and expansion capital expenditures;


•	Contributions to our equity-method investees to fund their expansion capital expenditures;


•	Interest on our long-term debt;


•	Quarterly dividends to our shareholders.

Potential risks associated with our planned levels of liquidity and the planned capital and investment expenditures discussed above include those previously discussed in Company Outlook.

Management’s Discussion and Analysis (Continued)

As of June 30, 2015, we had a working capital deficit (current liabilities, inclusive of commercial paper outstanding and long-term debt due within one year, in excess of current assets) of $2.342 billion. Excluding the impact of the $1.743 billion in commercial paper outstanding, which we consider to be a reduction of WPZ’s credit facility capacity as noted in the table below, our working capital deficit is $599 million. Our available liquidity to cover this deficit is as follows:



	June 30, 2015
Available Liquidity	WPZ		WMB		Total
	(Millions)
Cash and cash equivalents	$	186	$	18	$	204
Capacity available under our $1.5 billion credit facility (1)			1,150		1,150
Capacity available to WPZ under its $3.5 billion credit facility less amounts outstanding under its $3 billion commercial paper program (2)	1,757				1,757
	$	1,943	$	1,168	$	3,111


(1)	The highest amount outstanding under our credit facility during 2015 was $450 million. At June 30, 2015, we were in compliance with the financial covenants associated with this credit facility. See Note 9 – Debt and Banking Arrangements of Notes to Consolidated Financial Statements for additional information on our credit facility.

(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 $1.743 billion of commercial paper outstanding at June 30, 2015. The highest amount outstanding under WPZ’s commercial paper program and credit facility during 2015 was $3.1 billion. At June 30, 2015, WPZ was in compliance with the financial covenants associated with this credit facility and the commercial paper program. See Note 9 – Debt and Banking Arrangements of Notes to Consolidated Financial Statements for additional information on WPZ’s credit facility, WPZ’s commercial paper program, and termination of WPZ’s short-term facility.

Acquisition of WPZ Public Units

We may issue approximately 275 million shares of common stock associated with the agreement for the Acquisition of WPZ Public Units. In the event that agreement is terminated under certain circumstances, we could be required to pay a $410 million termination fee to WPZ, of which we currently own approximately 60 percent, including the interests of the general partner and IDRs. Such termination fee would be settled through a reduction of quarterly incentive distributions we are entitled to receive from WPZ (such reduction not to exceed $102.5 million per quarter). See Note 1 – General, Description of Business, and Basis of Presentation of Notes to Consolidated Financial Statements for additional information on the Acquisition of WPZ Public Units.

Debt Issuances and Retirements

On April 15, 2015, WPZ paid $783 million, including a redemption premium, to retire $750 million of 5.875 percent senior notes due 2021.

WPZ retired $750 million of 3.8 percent senior unsecured notes that matured on February 15, 2015.

Shelf Registrations

On May 11, 2015, we filed a shelf registration statement, as a well-known seasoned issuer. The shelf registration statement includes a prospectus describing some of the general terms that may apply to the registered securities and

Management’s Discussion and Analysis (Continued)

the general manner in which they may be offered. This filing allows us or our selling securityholders, who will be named in a prospectus supplement, from time to time to offer to sell debt securities, preferred stock, common stock, purchase contracts, warrants, or units. Each time we or a selling securityholder sells securities pursuant to such prospectus, we will provide a supplement to the prospectus that contains specific information about the offering and the specific terms of the securities offered. We may sell these securities directly to investors, or through agents, dealers, or underwriters as designated from time to time, or through a combination of these methods, on a continuous or delayed basis. As of June 30, 2015, no securities have been issued under this registration.

On February 25, 2015, WPZ 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 will 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 will be made pursuant to an equity distribution agreement between WPZ and certain banks who may act as sales agents or purchase for its own accounts as principals. As of June 30, 2015, no common units have been issued under this registration.

Distributions from Equity-Method Investees

The organizational documents of entities in which we have an equity-method interest 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.

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:	Standard & Poor’s	Credit Watch	BB+	BB+
	Moody’s Investors Service	Ratings Under Review	Baa3	N/A
	Fitch Ratings	Rating Watch Positive	BBB-	N/A

WPZ:	Standard & Poor’s	Credit Watch	BBB	BBB
	Moody’s Investors Service	Negative	Baa2	N/A
	Fitch Ratings	Stable	BBB	N/A

As previously discussed, on June 21, 2015, we publicly announced in a press release that our Board of Directors has authorized a process to explore a range of strategic alternatives after it had received and subsequently rejected an unsolicited proposal for us to be acquired in an all-equity transaction. Following this announcement, on June 22, 2015, the credit ratings agencies affirmed and/or revised the outlook and ratings as noted in the table above. While Fitch Ratings made no changes to the outlook for either WMB or WPZ on this date, the other agencies revised the outlook of both WMB and WPZ noting the uncertainty associated with these events.

Credit rating agencies perform independent analyses when assigning credit ratings. No assurance can be given that the credit rating agencies will continue to assign us investment grade ratings even if we meet or exceed their current criteria for investment grade ratios. A downgrade of our credit rating might increase our future cost of borrowing and would require us to post additional collateral with third parties, negatively impacting our available liquidity. As of June 30, 2015, we estimate that a downgrade to a rating below investment grade for us or WPZ could require us to post up to $1.1 million or $232 million, respectively, in additional collateral with third parties.

Management’s Discussion and Analysis (Continued)

Capital and Investment Expenditures

Each of our businesses is capital-intensive, requiring investment to upgrade or enhance existing operations and comply with safety and environmental regulations. The capital requirements of these businesses consist primarily of:

•

Maintenance capital expenditures, which are generally not discretionary, including: (1) capital expenditures made to replace partially or fully depreciated assets in order to maintain the existing operating capacity of our assets and to extend their useful lives; (2) expenditures which are mandatory and/or essential to comply with laws and regulations and maintain the reliability of our operations; and (3) certain well connection expenditures.


•	Expansion capital expenditures, which are generally more discretionary than maintenance capital expenditures, including: (1) expenditures to acquire additional assets to grow our business, to expand and upgrade plant or pipeline capacity and to construct new plants, pipelines and storage facilities; and (2) well connection expenditures which are not classified as maintenance expenditures.

The following table provides summary information related to our actual and expected capital expenditures, purchases of businesses, and contributions to equity-method investments for 2015. Included are gross increases to our property, plant, and equipment, including changes related to accounts payable and accrued liabilities:



	2015 Estimate		Six Months Ended June 30, 2015
	(Millions)
Maintenance	$	490	$	149
Expansion	3,785		2,000
Total	$	4,275	$	2,149

See Company Outlook - Expansion Projects for discussions describing the general nature of these expenditures.

Sources (Uses) of Cash



	Six Months Ended June 30,
	2015			2014
	(Millions)
Net cash provided (used) by:
Operating activities	$	1,483		$	759
Financing activities	483			7,356
Investing activities	(2,002		)	(7,936		)
Increase (decrease) in cash and cash equivalents	$	(36	)	$	179

Operating activities

The factors that determine operating activities are largely the same as those that affect Net income (loss), with the exception of noncash expenses such as Depreciation and amortization and Provision (benefit) for deferred income taxes. Our Net cash provided (used) by operating activities was also impacted by net favorable changes in operating working capital and the inclusion of contributions in 2015 from consolidating the businesses acquired in the ACMP Acquisition.

Financing activities

Significant transactions include:


•	$942 million in 2015 of net proceeds from WPZ’s commercial paper;


•	$226 million in 2014 net paid on WPZ’s commercial paper;

Management’s Discussion and Analysis (Continued)


•	$1.895 billion net received in 2014 from our debt offerings;


•	$2.992 billion in 2015 and $2.74 billion in 2014 net received from WPZ’s debt offerings;


•	$1.533 billion paid in 2015 on WPZ’s debt retirements;


•	$895 million received in 2015 and $300 million received in 2014 from our credit facility borrowings;


•	$915 million paid in 2015 on our credit facility borrowings;


•	$1.832 billion received in 2015 from WPZ’s credit facility borrowings;


•	$2.472 billion paid in 2015 on WPZ’s credit facility borrowings;


•	$3.378 billion received in 2014 from our equity offering;


•	$876 million in 2015 and $567 million in 2014 paid for quarterly dividends on common stock;


•	$462 million in 2015 and $296 million in 2014 paid for dividends and distributions to noncontrolling interests;


•	$57 million in 2015 and $122 million in 2014 received in contributions from noncontrolling interests.

Investing activities

Significant transactions include:


•	Capital expenditures of $1.654 billion in 2015 and $1.839 billion in 2014;


•	$112 million paid to purchase a gathering system comprised of approximately 140 miles of pipeline and a sour gas compression facility in the Eagle Ford shale;


•	Purchases of and contributions to our equity-method investments of $483 million in 2015 and $246 million in 2014;


•	Cash held for ACMP Acquisition of $5.995 billion in 2014.

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

We have various other guarantees and commitments which are disclosed in Note 3 – Variable Interest Entities, Note 11 – Fair Value Measurements and Guarantees, and Note 12 – Contingent Liabilities of Notes to Consolidated Financial Statements. We do not believe these guarantees or the possible fulfillment of them will prevent us from meeting our liquidity needs.

Item 3

Quantitative and Qualitative Disclosures About Market Risk

Interest Rate Risk

Our current interest rate risk exposure is related primarily to our debt portfolio and has not materially changed during the first six months of 2015.

Foreign Currency Risk

Our foreign operations, whose functional currency is the local currency, are located in Canada. Net assets of our foreign operations were approximately $1.3 billion at both June 30, 2015 and December 31, 2014. These investments have the potential to impact our financial position due to fluctuations in the local currency arising from the process of translating the local functional currency into the U.S. dollar. As an example, a 20 percent change in the functional currency against the U.S. dollar would have changed Total stockholders’ equity by approximately $168 million at June 30, 2015.

Item 4

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) or our internal control over financial reporting (Internal 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 Internal Controls and make modifications as necessary; our intent in this regard is that the Disclosure Controls and Internal 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 second quarter of 2015 that have materially affected, or are reasonably likely to materially affect, our Internal Control over Financial Reporting.

PART II. OTHER INFORMATION

Item 1. 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.

In November 2013, we became aware of deficiencies with the air permit for the Ft. Beeler gas processing facility located in West Virginia. We notified the EPA and the West Virginia Department of Environmental Protection and are working to bring the Ft. Beeler facility into full compliance. At June 30, 2015, we have accrued liabilities of $220,000 for potential penalties arising out of the deficiencies.

On November 7, 2014, the New Mexico Environment Department’s Air Quality Bureau (Bureau) issued a Notice of Violation (NOV) to Williams Four Corners LLC (Williams) for the El Cedro Gas Treating Plant alleging a failure by Williams to limit emissions to the allowable emission rates in violation of permit requirements, and for the failure to timely file initial and excess emission reports. The NOV followed an April 2014 inspection at the plant. Williams

has provided Corrective Action Verification information to the Bureau and has entered into a First Amended Tolling Agreement to allow for additional time—until November 30, 2015—for the parties to resolve the alleged violations.

Other

The additional information called for by this item is provided in Note 12 – Contingent Liabilities of the Notes to Consolidated Financial Statements included under Part I, Item 1. Financial Statements of this report, which information is incorporated by reference into this item.

Item 1A. Risk Factors

Part I, Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2014, includes certain risk factors that could materially affect our business, financial condition, or future results. Those Risk Factors have not materially changed, except as set forth below:

Our receipt of the Unsolicited Proposal and review of strategic alternatives may be disruptive to our business.

On June 21, 2015, we publicly announced in a press release that we had received the Unsolicited Proposal and rejected it. The Unsolicited Proposal was contingent upon the termination of our pending Acquisition of WPZ Public Units. Our Board of Directors has authorized a process to explore a range of strategic alternatives, which could include, among other things, a merger, a sale of us, or continuing to pursue our existing operating and growth plan. Exploring strategic alternatives may create a significant distraction for our management team and Board of Directors and require us to expend significant time and resources and incur expenses for advisors. Moreover, the review of strategic alternatives may disrupt our business by causing uncertainty among current and potential employees, suppliers, customers and investors. The selection and execution of a strategic alternative may lead to similar disruptions, and parties advocating for alternatives not selected may solicit support for such other alternatives, causing further disruption.

Additionally, certain of our officers are subject to change in control agreements, pursuant to which the officers may be entitled to severance payments and benefits upon a termination of their employment by us without cause or by them for good reason in connection with a change of control of Williams (each as defined in the applicable agreement). The change of control arrangements may not be adequate to allow us to retain critical employees during a time when a change of control is being proposed or is imminent.

These disruptions, alone or in combination, could negatively impact our business, financial condition, results of operations and our stock price.

The consummation of the Acquisition of WPZ Public Units could be delayed or may fail to occur, and could negatively affect our stock price.

Our Board of Directors has authorized a process to explore a range of strategic alternatives, which could include, among other things, a merger, a sale of us, or continuing to pursue our existing operating and growth plan. During the review of strategic alternatives process, we continue to work towards the completion of the Acquisition of WPZ Public Units. The announcement that we received the Unsolicited Proposal may make it more difficult to obtain the approval of our stockholders, which could prevent the consummation of the Acquisition of WPZ Public Units. The consummation of the Acquisition of WPZ Public Units is also subject to the satisfaction or waiver of conditions to closing contained in the merger agreement, including the approval of our stockholders. The satisfaction of such conditions to closing are not always within the parties’ control and, in some cases, are dependent on the actions of third parties including the SEC. In addition, the merger agreement provides certain termination rights that, in specified circumstances, give either or both of us and WPZ the ability to terminate the merger agreement. The failure to satisfy or waive a closing condition or the occurrence of an event giving rise to a termination right could delay or prevent the consummation of the Acquisition of WPZ Public Units. If the Acquisition of WPZ Public Units is not consummated, the market price of our common stock could decline. If the merger agreement is terminated under certain specified circumstances, we may be required to pay a termination fee of $410 million to WPZ, which would be settled through a reduction of quarterly incentive distributions we are entitled to receive from WPZ (such reduction not to exceed $102.5 million per quarter).

The Unsolicited Proposal is contingent upon the termination of the Acquisition of WPZ Public Units. If the Acquisition of WPZ Public Units is consummated, some third parties could be discouraged from considering or proposing an acquisition of us, including the third party that submitted the Unsolicited Proposal, which may cause the market price of our common stock to decline.

Item 6. Exhibits



Exhibit No.		Description

§Exhibit 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).
Exhibit 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).
Exhibit 3.2	—	By-Laws (filed on August 27, 2014, 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).
*Exhibit 12	—	Computation of Ratio of Earnings to Combined Fixed Charges.
*Exhibit 31.1	—	Certification of Chief Executive Officer pursuant to Rules 13a-14(a) and 15d-14(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.
*Exhibit 31.2	—	Certification of Chief Financial Officer pursuant to Rules 13a-14(a) and 15d-14(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.
**Exhibit 32	—	Certification of Chief Executive Officer and Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
*Exhibit 101.INS	—	XBRL Instance Document.
*Exhibit 101.SCH	—	XBRL Taxonomy Extension Schema.
*Exhibit 101.CAL	—	XBRL Taxonomy Extension Calculation Linkbase.
*Exhibit 101.DEF	—	XBRL Taxonomy Extension Definition Linkbase.
*Exhibit 101.LAB	—	XBRL Taxonomy Extension Label Linkbase.
*Exhibit 101.PRE	—	XBRL Taxonomy Extension Presentation Linkbase.

* Filed herewith.

** Furnished herewith.


§	Pursuant to Item 601(b)(2) of Regulation S-K, the registrant agrees to furnish supplementally a copy of any omitted exhibit or schedule to the SEC upon request.

SIGNATURE

Pursuant to the requirements 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)

	/s/ TED T. TIMMERMANS
	Ted T. Timmermans
	Vice President, Controller and Chief Accounting Officer (Duly Authorized Officer and Principal Accounting Officer)

July 30, 2015

EXHIBIT INDEX



Exhibit No.		Description

§Exhibit 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).
Exhibit 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).
Exhibit 3.2	—	By-Laws (filed on August 27, 2014, 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).
*Exhibit 12	—	Computation of Ratio of Earnings to Combined Fixed Charges.
*Exhibit 31.1	—	Certification of Chief Executive Officer pursuant to Rules 13a-14(a) and 15d-14(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.
*Exhibit 31.2	—	Certification of Chief Financial Officer pursuant to Rules 13a-14(a) and 15d-14(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.
**Exhibit 32	—	Certification of Chief Executive Officer and Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
*Exhibit 101.INS	—	XBRL Instance Document.
*Exhibit 101.SCH	—	XBRL Taxonomy Extension Schema.
*Exhibit 101.CAL	—	XBRL Taxonomy Extension Calculation Linkbase.
*Exhibit 101.DEF	—	XBRL Taxonomy Extension Definition Linkbase.
*Exhibit 101.LAB	—	XBRL Taxonomy Extension Label Linkbase.
*Exhibit 101.PRE	—	XBRL Taxonomy Extension Presentation Linkbase.

* Filed herewith.

** Furnished herewith.


§	Pursuant to Item 601(b)(2) of Regulation S-K, the registrant agrees to furnish supplementally a copy of any omitted exhibit or schedule to the SEC upon request.