10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

X  Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended September 30, 2015.

OR

___ Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from __________ to __________.

Commission file number   001-13643

ONEOK, Inc.

(Exact name of registrant as specified in its charter)

Oklahoma	73-1520922
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
100 West Fifth Street, Tulsa, OK	74103
(Address of principal executive offices)	(Zip Code)

Registrant’s telephone number, including area code   (918) 588-7000

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 X  No __

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).  

Yes X 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.

Large accelerated filer X             Accelerated filer __             Non-accelerated filer __             Smaller reporting company__

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes __ No X

On October 26, 2015, the Company had 209,277,589 shares of common stock outstanding.

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ONEOK, Inc.

TABLE OF CONTENTS

Part I.	Financial Information	Page No.
Item 1.	Financial Statements (Unaudited)	6
	Consolidated Statements of Income - Three and Nine Months Ended September 30, 2015 and 2014	6
	Consolidated Statements of Comprehensive Income - Three and Nine Months Ended September 30, 2015 and 2014	7
	Consolidated Balance Sheets - September 30, 2015 and December 31, 2014	8
	Consolidated Statements of Cash Flows - Nine Months Ended September 30, 2015 and 2014	11
	Consolidated Statement of Changes in Equity - Nine Months Ended September 30, 2015 and 2014	12
	Notes to Consolidated Financial Statements	14
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	38
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	70
Item 4.	Controls and Procedures	70
Part II.	Other Information	71
Item 1.	Legal Proceedings	71
Item 1A.	Risk Factors	71
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	71
Item 3.	Defaults Upon Senior Securities	71
Item 4.	Mine Safety Disclosures	71
Item 5.	Other Information	71
Item 6.	Exhibits	71
Signature		73

As used in this Quarterly Report, references to “we,” “our” or “us” refer to ONEOK, Inc., an Oklahoma corporation, and its predecessors, divisions and subsidiaries, unless the context indicates otherwise.

The statements in this Quarterly Report that are not historical information, including statements concerning plans and objectives of management for future operations, economic performance or related assumptions, are forward-looking statements.  Forward-looking statements may include words such as “anticipate,” “estimate,” “expect,” “project,” “intend,” “plan,” “believe,” “should,” “goal,” “forecast,” “guidance,” “could,” “may,” “continue,” “might,” “potential,” “scheduled” and other words and terms of similar meaning.  Although we believe that our expectations regarding future events are based on reasonable assumptions, we can give no assurance that such expectations or assumptions will be achieved. Important factors that could cause actual results to differ materially from those in the forward-looking statements are described under Part I, Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations “Forward-Looking Statements,” in this Quarterly Report and under Part I, Item IA, “Risk Factors,” in our Annual Report.

INFORMATION AVAILABLE ON OUR WEBSITE

We make available, free of charge, on our website (www.oneok.com) copies of our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K, amendments to those reports filed or furnished to the SEC pursuant to Section 13(a) or 15(d) of the Exchange Act and reports of holdings of our securities filed by our officers and directors under Section 16 of the Exchange Act as soon as reasonably practicable after filing such material electronically or otherwise furnishing it to the SEC. Copies of our Code of Business Conduct, Corporate Governance Guidelines and Director Independence Guidelines are also available on our website, and we will provide copies of these documents upon request. Our website and any contents thereof are not incorporated by reference into this report.

We also make available on our website the Interactive Data Files required to be submitted and posted pursuant to Rule 405 of Regulation S-T.

3

GLOSSARY

The abbreviations, acronyms and industry terminology used in this Quarterly Report are defined as follows:

AFUDC Allowance for funds used during construction

Annual Report Annual Report on Form 10-K for the year ended December 31, 2014

ASU Accounting Standards Update

Bbl Barrels, 1 barrel is equivalent to 42 United States gallons

BBtu/d Billion British thermal units per day

Bcf Billion cubic feet

Bcf/d Billion cubic feet per day

CFTC U.S. Commodity Futures Trading Commission

Clean Air Act Federal Clean Air Act, as amended

Clean Water Act Federal Water Pollution Control Act Amendments of 1972, as amended

DOT United States Department of Transportation

EBITDA Earnings before interest expense, income taxes, depreciation and amortization

EPA United States Environmental Protection Agency

Exchange Act Securities Exchange Act of 1934, as amended

FASB Financial Accounting Standards Board

FERC Federal Energy Regulatory Commission

GAAP Accounting principles generally accepted in the United States of America

GHG Greenhouse gas

Intermediate Partnership ONEOK Partners Intermediate Limited Partnership, a wholly owned subsidiary

of ONEOK Partners, L.P.

LIBOR London Interbank Offered Rate

MBbl/d Thousand barrels per day

MDth/d Thousand dekatherms per day

MMBbl Million barrels

MMBtu Million British thermal units

MMcf/d Million cubic feet per day

Moody’s Moody’s Investors Service, Inc.

Natural Gas Policy Act Natural Gas Policy Act of 1978, as amended

NGL(s) Natural gas liquid(s)

NGL products Marketable natural gas liquids purity products, such as ethane, ethane/propane

mix, propane, iso-butane, normal butane and natural gasoline

NYMEX New York Mercantile Exchange

NYSE New York Stock Exchange

ONE Gas ONE Gas, Inc.

ONEOK ONEOK, Inc.

ONEOK Credit Agreement ONEOK’s $300 million Amended and Restated Revolving Credit Agreement

dated January 31, 2014

ONEOK Partners ONEOK Partners, L.P.

ONEOK Partners Credit Agreement ONEOK Partners’ $2.4 billion Amended and Restated Revolving Credit

Agreement dated January 31, 2014, as amended

ONEOK Partners GP ONEOK Partners GP, L.L.C., a wholly owned subsidiary of ONEOK and the

sole general partner of ONEOK Partners

OPIS Oil Price Information Service

Partnership Agreement Third Amended and Restated Agreement of Limited Partnership of ONEOK

Partners, L.P., as amended

PHMSA United States Department of Transportation Pipeline and Hazardous Materials

Safety Administration

POP Percent of Proceeds

4

Quarterly Report(s) Quarterly Report(s) on Form 10-Q

S&P Standard & Poor’s Ratings Services

SCOOP South Central Oklahoma Oil Province

SEC Securities and Exchange Commission

West Texas LPG West Texas LPG Pipeline Limited Partnership and Mesquite Pipeline

WTI West Texas Intermediate

XBRL eXtensible Business Reporting Language

5

PART I - FINANCIAL INFORMATION

ITEM 1.  FINANCIAL STATEMENTS

ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF INCOME
	Three Months Ended						Nine Months Ended
	September 30,						September 30,
(Unaudited)	2015			2014			2015			2014
	(Thousands of dollars, except per share amounts)
Revenues
Commodity sales	$	1,484,350		$	2,754,495		$	4,642,320		$	8,276,333
Services	414,596			365,650			1,189,984			1,073,990
Total revenues	1,898,946			3,120,145			5,832,304			9,350,323
Cost of sales and fuel	1,360,809			2,583,204			4,307,766			7,807,275
Net margin	538,137			536,941			1,524,538			1,543,048
Operating expenses
Operations and maintenance	146,979			153,408			442,179			433,457
Depreciation and amortization	88,299			74,588			261,241			214,129
General taxes	17,198			19,087			66,366			60,171
Total operating expenses	252,476			247,083			769,786			707,757
Gain (loss) on sale of assets	(726		)	1,534			(610		)	1,533
Operating income	284,935			291,392			754,142			836,824
Equity in net earnings (loss) from investments (Note L)	32,244			(52,347		)	93,205			6,747
Allowance for equity funds used during construction	177			1,723			1,718			13,947
Other income	71			100			249			3,117
Other expense	(7,508		)	(2,506		)	(7,754		)	(27,827		)
Interest expense (net of capitalized interest of $8,851, $14,303, $26,008 and $41,446, respectively)	(106,923		)	(86,052		)	(306,057		)	(269,704		)
Income before income taxes	202,996			152,310			535,503			563,104
Income taxes	(38,298		)	(37,858		)	(123,948		)	(95,155		)
Income from continuing operations	164,698			114,452			411,555			467,949
Income (loss) from discontinued operations, net of tax (Note B)	(3,860		)	(171		)	(4,144		)	(6,406		)
Net income	160,838			114,281			407,411			461,543
Less: Net income attributable to noncontrolling interests	78,681			49,823			187,949			241,980
Net income attributable to ONEOK	$	82,157		$	64,458		$	219,462		$	219,563
Amounts attributable to ONEOK:
Income from continuing operations	$	86,017		$	64,629		$	223,606		$	225,969
Income (loss) from discontinued operations	(3,860		)	(171		)	(4,144		)	(6,406		)
Net income	$	82,157		$	64,458		$	219,462		$	219,563
Basic earnings per share:
Income from continuing operations (Note J)	$	0.41		$	0.31		$	1.06		$	1.08
Income (loss) from discontinued operations	(0.02		)	—			(0.02		)	(0.03		)
Net income	$	0.39		$	0.31		$	1.04		$	1.05
Diluted earnings per share:
Income from continuing operations (Note J)	$	0.41		$	0.31		$	1.06		$	1.07
Income (loss) from discontinued operations	(0.02		)	—			(0.02		)	(0.03		)
Net income	$	0.39		$	0.31		$	1.04		$	1.04
Average shares (thousands)
Basic	210,296			209,489			210,138			209,341
Diluted	210,524			210,759			210,509			210,482
Dividends declared per share of common stock	$	0.605		$	0.575		$	1.815		$	1.535

See accompanying Notes to Consolidated Financial Statements.

6

ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
	Three Months Ended					Nine Months Ended
	September 30,					September 30,
(Unaudited)	2015			2014		2015			2014
	(Thousands of dollars)
Net income	$	160,838		$	114,281	$	407,411		$	461,543
Other comprehensive income (loss), net of tax
Unrealized gains (losses) on energy marketing and risk-management assets/liabilities, net of taxof$(1,109),$(1,160), $(2,156) and $12,664, respectively	14,840			6,219		19,217			(72,627		)
Realized (gains) losses in net income, net of tax of $2,957, $(748), $5,621 and $(14,966), respectively	(15,259		)	3,132		(35,530		)	48,170
Unrealized holding gains (losses) on available-for-sale securities, net of tax of $0, $(73), $648 and $(36), respectively	—			107		(955		)	(6		)
Change in pension and postretirement benefit plan liability, net of tax of $(1,599), $(1,456), $(4,798) and $(5,379), respectively	2,441			2,185		7,320			8,069
Total other comprehensive income (loss), net of tax	2,022			11,643		(9,948		)	(16,394		)
Comprehensive income	162,860			125,924		397,463			445,149
Less: Comprehensive income attributable to noncontrolling interests	81,481			55,995		177,760			214,644
Comprehensive income attributable to ONEOK	$	81,379		$	69,929	$	219,703		$	230,505

See accompanying Notes to Consolidated Financial Statements.

7

ONEOK, Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS
	September 30,		December 31,
(Unaudited)	2015		2014
Assets	(Thousands of dollars)
Current assets
Cash and cash equivalents	$	38,371	$	172,812
Accounts receivable, net	586,157		745,494
Materials and supplies	62,604		55,833
Natural gas and natural gas liquids in storage	142,308		134,134
Commodity imbalances	30,602		64,788
Other current assets	76,129		117,466
Assets of discontinued operations (Note B)	16,619		16,717
Total current assets	952,790		1,307,244
Property, plant and equipment
Property, plant and equipment	14,457,280		13,602,647
Accumulated depreciation and amortization	2,178,687		1,940,210
Net property, plant and equipment	12,278,593		11,662,437
Investments and other assets
Investments in unconsolidated affiliates	1,137,059		1,132,653
Goodwill and intangible assets	1,020,233		1,014,740
Other assets	115,716		124,679
Assets of discontinued operations (Note B)	3,907		20,020
Total investments and other assets	2,276,915		2,292,092
Total assets	$	15,508,298	$	15,261,773

See accompanying Notes to Consolidated Financial Statements.

8

ONEOK, Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS
(Continued)
	September 30,			December 31,
(Unaudited)	2015			2014
Liabilities and equity	(Thousands of dollars)
Current liabilities
Current maturities of long-term debt	$	660,650		$	10,650
Notes payable (Note F)	287,272			1,055,296
Accounts payable	620,568			891,413
Commodity imbalances	96,192			104,650
Accrued interest	108,454			104,877
Other current liabilities	157,705			180,558
Liabilities of discontinued operations (Note B)	29,980			44,901
Total current liabilities	1,960,821			2,392,345
Long-term debt, excluding current maturities (Note G)	7,773,756			7,150,142
Deferred credits and other liabilities
Deferred income taxes	1,437,087			1,395,222
Other deferred credits	278,731			281,757
Liabilities of discontinued operations (Note B)	20,598			36,424
Total deferred credits and other liabilities	1,736,416			1,713,403
Commitments and contingencies (Note N)
Equity (Note H)
ONEOK shareholders’ equity:
Common stock, $0.01 par value: authorized 600,000,000 shares; issued 245,811,180 shares and outstanding 209,273,336 shares at September 30, 2015; issued 245,811,180 shares and outstanding 208,322,247 shares at December 31, 2014	2,458			2,458
Paid-in capital	1,477,631			1,541,583
Accumulated other comprehensive loss (Note I)	(136,112		)	(136,353		)
Retained earnings	—			138,128
Treasury stock, at cost: 36,537,844 shares at September 30, 2015, and 37,488,933 shares at December 31, 2014	(929,505		)	(953,701		)
Total ONEOK shareholders’ equity	414,472			592,115
Noncontrolling interests in consolidated subsidiaries	3,622,833			3,413,768
Total equity	4,037,305			4,005,883
Total liabilities and equity	$	15,508,298		$	15,261,773

See accompanying Notes to Consolidated Financial Statements.

9

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10

ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF CASH FLOWS
	Nine Months Ended
	September 30,
(Unaudited)	2015			2014
	(Thousands of dollars)
Operating activities
Net income	$	407,411		$	461,543
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	261,241			225,483
Charges attributable to exit activities	—			1,739
Equity in net earnings from investments	(93,205		)	(6,747		)
Distributions received from unconsolidated affiliates	92,042			84,298
Deferred income taxes	124,615			96,044
Share-based compensation expense	13,732			23,359
Pension and postretirement benefit expense, net of contributions	10,145			14,282
Allowance for equity funds used during construction	(1,718		)	(13,947		)
Loss (gain) on sale of assets	610			(1,533		)
Changes in assets and liabilities:
Accounts receivable	157,742			156,555
Natural gas and natural gas liquids in storage	(8,174		)	(43,351		)
Accounts payable	(191,542		)	(111,186		)
Commodity imbalances, net	25,728			(33,214		)
Settlement of exit activities liabilities	(31,207		)	(38,627		)
Energy marketing and risk management assets and liabilities	(45,240		)	27,924
Accrued interest	3,577			(6,390		)
Other assets and liabilities, net	(30,680		)	34,307
Cash provided by operating activities	695,077			870,539
Investing activities
Capital expenditures (less allowance for equity funds used during construction)	(930,316		)	(1,204,386		)
Cash paid for acquisitions	—			(14,000		)
Contributions to unconsolidated affiliates	(27,540		)	(1,063		)
Distributions received from unconsolidated affiliates in excess of cumulative earnings	25,111			24,925
Proceeds from sale of assets	3,171			2,388
Other	(12,607		)	—
Cash used in investing activities	(942,181		)	(1,192,136		)
Financing activities
Borrowing (repayment) of notes payable, net	(768,024		)	(564,462		)
Issuance of ONE Gas debt, net of discounts	—			1,199,994
Issuance of long-term debt, net of discounts	1,291,506			—
ONE Gas long-term debt financing costs	—			(9,663		)
Debt financing costs	(17,126		)	—
Repayment of long-term debt	(5,795		)	(555,768		)
Issuance of common stock	13,839			12,908
Issuance of common units, net of issuance costs	375,660			947,472
Dividends paid	(380,498		)	(321,051		)
Cash of ONE Gas at separation	—			(60,000		)
Distributions to noncontrolling interests	(396,847		)	(325,158		)
Cash provided by financing activities	112,715			324,272
Change in cash and cash equivalents	(134,389		)	2,675
Change in cash and cash equivalents included in discontinued operations	(52		)	3,163
Change in cash and cash equivalents included in continuing operations	(134,441		)	5,838
Cash and cash equivalents at beginning of period	172,812			145,565
Cash and cash equivalents at end of period	$	38,371		$	151,403

See accompanying Notes to Consolidated Financial Statements.

11

ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
	ONEOK Shareholders’ Equity
(Unaudited)	Common Stock Issued	Common Stock		Paid-in Capital			Accumulated Other Comprehensive Income (Loss)
	(Shares)	(Thousands of dollars)
January 1, 2015	245,811,180	$	2,458	$	1,541,583		$	(136,353	)
Net income	—	—		—			—
Other comprehensive income (loss) (Note I)	—	—		—			241
Common stock issued	—	—		(6,284		)	—
Common stock dividends - $1.815 per share (Note H)	—	—		(22,807		)	—
Issuance of common units of ONEOK Partners (Note M)	—	—		(34,446		)	—
Distributions to noncontrolling interests	—	—		—			—
Other	—	—		(415		)	—
September 30, 2015	245,811,180	$	2,458	$	1,477,631		$	(136,112	)

	ONEOK Shareholders’ Equity
(Unaudited)	Common Stock Issued	Common Stock		Paid-in Capital			Accumulated Other Comprehensive Income (Loss)
	(Shares)	(Thousands of dollars)
January 1, 2014	245,811,180	$	2,458	$	1,433,600		$	(121,987	)
Net income	—	—		—			—
Other comprehensive income (loss) (Note I)	—	—		—			10,942
Common stock issued	—	—		(20,397		)	—
Common stock dividends - $1.535 per share (Note H)	—	—		—			—
Issuance of common units of ONEOK Partners (Note M)	—	—		138,310			—
Distributions of ONE Gas to Shareholders	—	—		—			3,389
Distributions to noncontrolling interests	—	—		—			—
Other	—	—		(36,355		)	—
September 30, 2014	245,811,180	$	2,458	$	1,515,158		$	(107,656	)

12

ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
(Continued)
	ONEOK Shareholders’ Equity
(Unaudited)	Retained Earnings			Treasury Stock			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity
	(Thousands of dollars)
January 1, 2015	$	138,128		$	(953,701	)	$	3,413,768		$	4,005,883
Net income	219,462			—			187,949			407,411
Other comprehensive income (loss) (Note I)	—			—			(10,189		)	(9,948		)
Common stock issued	—			24,196			—			17,912
Common stock dividends - $1.815 per share (Note H)	(357,691		)	—			—			(380,498		)
Issuance of common units of ONEOK Partners (Note M)	—			—			428,590			394,144
Distributions to noncontrolling interests	—			—			(396,847		)	(396,847		)
Other	101			—			(438		)	(752		)
September 30, 2015	$	—		$	(929,505	)	$	3,622,833		$	4,037,305

	ONEOK Shareholders’ Equity
(Unaudited)	Retained Earnings			Treasury Stock			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity
	(Thousands of dollars)
January 1, 2014	$	2,020,815		$	(997,035	)	$	2,507,329		$	4,845,180
Net income	219,563			—			241,980			461,543
Other comprehensive income (loss) (Note I)	—			—			(27,336		)	(16,394		)
Common stock issued	—			40,058			—			19,661
Common stock dividends - $1.535 per share (Note H)	(321,051		)	—			—			(321,051		)
Issuance of common units of ONEOK Partners (Note M)	—			—			739,348			877,658
Distributions of ONE Gas to Shareholders	(1,749,078		)	—			—			(1,745,689		)
Distributions to noncontrolling interests	—			—			(325,158		)	(325,158		)
Other	—			—			—			(36,355		)
September 30, 2014	$	170,249		$	(956,977	)	$	3,136,163		$	3,759,395

See accompanying Notes to Consolidated Financial Statements.

13

ONEOK, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

A. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Our accompanying unaudited consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC. These statements have been prepared in accordance with GAAP and reflect all adjustments that, in our opinion, are necessary for a fair presentation of the results for the interim periods presented. All such adjustments are of a normal recurring nature. The 2014 year-end consolidated balance sheet data was derived from our audited financial statements but does not include all disclosures required by GAAP. These unaudited consolidated financial statements should be read in conjunction with our audited consolidated financial statements in our Annual Report.

Our significant accounting policies are consistent with those disclosed in Note A of the Notes to Consolidated Financial Statements in our Annual Report.

Organization and Nature of Operations - We are the sole general partner and own limited partner units of ONEOK Partners (NYSE: OKS), which together represent an aggregate 41.2 percent interest in ONEOK Partners at September 30, 2015. The results of operations for our former natural gas distribution and energy services businesses have been classified as discontinued operations for all periods presented. See Note B for additional information.

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

Goodwill Impairment Test - We assess our goodwill for impairment at least annually on July 1, unless events or changes in circumstances indicate an impairment may have occurred before that time.  At July 1, 2015, we assessed qualitative factors to determine whether it was more likely than not that the fair value of each of our reporting units was less than its carrying amount. Due to the current commodity price environment, we elected to perform a quantitative assessment, or Step 1 analysis, to test our goodwill for impairment. The assessment included our current commodity price assumptions, expected contractual terms, anticipated operating costs and volume estimates.  Our goodwill impairment analysis performed as of July 1, 2015, did not result in an impairment charge nor did our analysis reflect any reporting units at risk.  In each reporting unit, the fair value substantially exceeded its carrying value. Subsequent to that date, no event has occurred indicating that the implied fair value of each of the reporting units is less than the carrying value of its net assets. 

Recently Issued Accounting Standards Update - In March 2015, the FASB issued ASU 2015-03, “Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs,” which requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. In August 2015, the FASB issued ASU 2015-15, “Interest - Imputation of Interest (Subtopic 835-30): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements - Amendments to SEC Paragraphs Pursuant to Staff Announcement at June 18, 2015 EITF Meeting,” which amended the SEC paragraphs of ASC Subtopic 835-30 to include the language from the SEC Staff Announcement indicating that the SEC would not object to presenting deferred debt issuance costs related to line-of-credit agreements as assets and subsequently amortizing the deferred debt issuance costs ratably over the term of the agreement. This guidance is effective for public companies for fiscal years beginning after December 15, 2015, with early adoption permitted. We elected to adopt this guidance beginning in the second quarter 2015. Retrospective adjustment of prior periods presented was required. Therefore, the December 31, 2014, balance sheet was recast to reclassify $42.8 million of debt issuance costs from other assets to long-term debt. The impact of adopting this guidance was not material.

In April 2014, the FASB issued ASU 2014-08, “Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity,” which alters the definition of a discontinued operation to include only asset disposals that represent a strategic shift with a major effect on an entity’s operations and financial results. The amendment also requires more extensive disclosures about a discontinued operation’s assets, liabilities, income, expenses and cash flows. This guidance will be effective for interim and annual periods for all assets that are disposed of or classified as being held for sale in fiscal years that begin on or after December 15, 2014. We adopted this guidance beginning in the first quarter 2015, and it could impact us in the future if we dispose of any individually significant components.

In September 2015, the FASB issued ASU 2015-16, “Business Combinations (Topic 805) - Simplifying the Accounting for Measurement-Period Adjustments,” which requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. The amendment also requires the acquirer to record the income statement effects of changes to provisional amounts in the financial

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statements in the period in which the adjustments occurred. This guidance is effective for public companies for fiscal years beginning after December 15, 2015, with early adoption permitted. We expect to adopt this guidance in the first quarter 2016, and it could impact us in the future if we complete any acquisitions with subsequent measurement period adjustments.

In April 2015, the FASB issued ASU 2015-05, “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Fees Paid in a Cloud Computing Arrangement,” which clarifies whether a cloud computing arrangement includes a software license. If it does, the customer should account for the software license element of the arrangement consistent with the acquisition of other software licenses; if not, the customer should not account for the arrangement as a service contract. This guidance is effective for public companies for fiscal years beginning after December 15, 2015. Early adoption is permitted. We expect to adopt this guidance in the first quarter 2016, and we do not expect it to materially impact us.

In February 2015, the FASB issued ASU 2015-02, “Consolidation (Topic 810): Amendments to the Consolidation Analysis,” which eliminates the presumption that a general partner should consolidate a limited partnership. It also modifies the evaluation of whether limited partnerships are variable interest entities or voting interest entities and adds requirements that limited partnerships must meet to qualify as voting interest entities. This guidance is effective for public companies for fiscal years beginning after December 15, 2015. We expect to adopt this guidance in the first quarter 2016, and we are evaluating the impact on us.

In August 2014, the FASB issued ASU 2014-15, “Going Concern,” which provides guidance on determining when and how to disclose going-concern uncertainties in the financial statements. The new standard requires management to perform interim and annual assessments of an entity’s ability to continue as a going concern within one year of the date the financial statements are issued. An entity must provide certain disclosures if conditions or events raise substantial doubt about the entity’s ability to continue as a going concern. The standard applies to all entities and is effective for annual periods ending after December 15, 2016, and interim periods thereafter, with early adoption permitted. We expect to adopt this guidance beginning in the fourth quarter 2016, and we do not expect it to materially impact us.

In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers,” which outlines the principles an entity must apply to measure and recognize revenue for entities that enter into contracts to provide goods or services to their customers. The core principle is that an entity should recognize revenue at an amount that reflects the consideration to which the entity expects to be entitled in exchange for transferring goods or services to a customer. The amendment also requires more extensive disaggregated revenue disclosures in interim and annual financial statements. In August 2015, the FASB issued ASU 2015-14, “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date,” that deferred the effective date of ASU 2014-09 by one year. This update is now effective for interim and annual periods that begin after December 15, 2017, with either retrospective application for all periods presented or retrospective application with a cumulative effect adjustment. We expect to adopt this guidance beginning in the first quarter 2018, and we are evaluating the impact on us.

B. DISCONTINUED OPERATIONS

Separation of ONE Gas - On January 31, 2014, we completed the separation of ONE Gas, which consists of our former natural gas distribution business. ONEOK shareholders of record at the close of business on January 21, 2014, retained their shares of ONEOK stock and received one share of ONE Gas stock for every four shares of ONEOK stock owned in a transaction that was tax-free to ONEOK and its shareholders. We retained no ownership interest in ONE Gas. Excluding cash of ONE Gas at separation, the separation was accounted for as a noncash activity.

Wind Down of Energy Services Business - On March 31, 2014, we completed the wind down of our former energy services business. We executed agreements in 2013 and the first quarter 2014 to release a significant portion of our nonaffiliated natural gas transportation and storage contracts to third parties that resulted in noncash charges, which are included in income (loss) from discontinued operations, net of tax, in our Consolidated Statements of Income.

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The following table summarizes the change in our liability related to released capacity contracts for the periods indicated:

	Nine Months Ended
	September 30,
	2015			2014
	(Millions of dollars)
Beginning balance	$	73.8		$	122.0
Noncash charges	—			1.7
Settlements	(31.2		)	(38.6		)
Accretion	0.8			1.5
Ending balance	$	43.4		$	86.6

We expect future cash payments associated with released transportation and storage capacity contracts from the wind down of our former energy services business to total approximately $26 million on an after-tax basis, which consists of approximately $4 million to be paid in the remainder of 2015, $11 million in 2016, $6 million in 2017 and $5 million over the period 2018 through 2023.

Results of Operations of Discontinued Operations - The results of operations for our former natural gas distribution business and energy services business have been reported as discontinued operations for all periods presented. Income (loss) from discontinued operations, net of tax, in the Consolidated Statements of Income for the three and nine months ended September 30, 2015, consists of accretion expense, net of tax benefit, on the released contracts for our former energy services business and certain tax-related adjustments. The table below provides selected financial information reported in discontinued operations in the Consolidated Statements of Income for the three and nine months ended September 30, 2014:

	Three Months Ended									Nine Months Ended
	September 30, 2014									September 30, 2014
	Natural Gas Distribution		Energy Services				Total			Natural Gas Distribution				Energy Services			Total
	(Thousands of dollars)
Revenues	$	—	$	—			$	—		$	287,249			$	353,404		$	640,653
Cost of sales and fuel	—		—				—			190,893				364,648			555,541
Net margin	—		—				—			96,356				(11,244		)	85,112
Operating costs	—		142			(b)	142			60,847			(a)	4,664			65,511
Depreciation and amortization	—		—				—			11,035				319			11,354
Operating income (loss)	—		(142		)		(142		)	24,474				(16,227		)	8,247
Other income (expense), net	—		—				—			(888		)		(7		)	(895		)
Interest expense, net	—		—				—			(4,592		)		(413		)	(5,005		)
Income taxes	—		(29		)		(29		)	(16,415		)		7,662			(8,753		)
Income (loss) from discontinued operations, net	$	—	$	(171	)		$	(171	)	$	2,579			$	(8,985	)	$	(6,406	)

(a) - Includes approximately $23.0 million for the nine months ended September 30, 2014, of costs related to ONE Gas separation.

(b) - Represents primarily accretion expense.

Prior to the ONE Gas separation, natural gas sales and transportation and storage services provided to our former natural gas distribution business by ONEOK Partners were $7.5 million for the nine months ended September 30, 2014. Prior to February 1, 2014, these revenues and related costs were eliminated in consolidation. Beginning February 1, 2014, these revenues represent third-party transactions with ONE Gas and are not eliminated in consolidation for all periods presented, as such sales and services have continued subsequent to the separation and are expected to continue in future periods.

Prior to the completion of the energy services wind down, natural gas sales and transportation and storage services provided to our energy services business by ONEOK Partners were $46.0 million for the nine months ended September 30, 2014. While these transactions were eliminated in consolidation in previous periods, they are reflected now as affiliate transactions and are not eliminated in consolidation for all periods presented as these transactions have continued with third parties.

Statement of Financial Position of Discontinued Operations - At September 30, 2015, and December 31, 2014, assets and liabilities of discontinued operations in our Consolidated Balance Sheets relate primarily to deferred tax assets and capacity release obligations associated with our former energy services business.

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C. ACQUISITIONS

West Texas LPG Acquisition - In November 2014, ONEOK Partners completed the acquisition of an 80 percent interest in the West Texas LPG Pipeline Limited Partnership and a 100 percent interest in the Mesquite Pipeline for approximately $800 million from affiliates of Chevron Corporation. We accounted for this acquisition as a business combination which, among other things, requires assets acquired and liabilities assumed to be measured at their acquisition-date fair values. See Note C in the Notes to Consolidated Financial Statements in our Annual Report for additional information on this acquisition.

Our consolidated balance sheet as of September 30, 2015, reflects the final purchase price allocation. Adjustments to the preliminary purchase price allocation reported in Note C in the Notes to the Consolidated Financial Statements in our Annual Report were not material. Therefore, prior period financial statements have not been recast.

D. FAIR VALUE MEASUREMENTS

Determining Fair Value -We define fair value as the price that would be received from the sale of an asset or the transfer of a liability in an orderly transaction between market participants at the measurement date. We use market and income approaches to determine the fair value of our assets and liabilities and consider the markets in which the transactions are executed. We measure the fair value of a group of financial assets and liabilities consistent with how a market participant would price the net risk exposure at the measurement date.

While many of the contracts in ONEOK Partners’ portfolio are executed in liquid markets where price transparency exists, some contracts are executed in markets for which market prices may exist, but the market may be relatively inactive. This results in limited price transparency that requires management’s judgment and assumptions to estimate fair values.  For certain transactions, we utilize modeling techniques using NYMEX-settled pricing data and implied forward LIBOR curves. Inputs into our fair value estimates include commodity-exchange prices, over-the-counter quotes, historical correlations of pricing data, data obtained from third-party pricing services and LIBOR and other liquid money-market instrument rates. We validate our valuation inputs with third-party information and settlement prices from other sources, where available.

In addition, as prescribed by the income approach, we compute the fair value of our and ONEOK Partners’ derivative portfolio by discounting the projected future cash flows from our and ONEOK Partners’ derivative assets and liabilities to present value using interest-rate yields to calculate present-value discount factors derived from LIBOR, Eurodollar futures and interest-rate swaps. We also take into consideration the potential impact on market prices of liquidating positions in an orderly manner over a reasonable period of time under current market conditions. We consider current market data in evaluating counterparties’, as well as our own, nonperformance risk, net of collateral, by using specific and sector bond yields and monitoring the credit default swap markets. Although we use our best estimates to determine the fair value of the derivative contracts we and ONEOK Partners have executed, the ultimate market prices realized could differ from our estimates, and the differences could be material.

The fair value of our forward-starting interest-rate swaps are determined using financial models that incorporate the implied forward LIBOR yield curve for the same period as the future interest swap settlements.

Fair Value Hierarchy - At each balance sheet date, we utilize a fair value hierarchy to classify fair value amounts recognized or disclosed in our financial statements based on the observability of inputs used to estimate such fair value. The levels of the hierarchy are described below:

• Level 1 - fair value measurements are based on unadjusted quoted prices for identical securities in active markets, including NYMEX-settled prices. These balances are comprised predominantly of exchange-traded derivative contracts for natural gas and crude oil.

• Level 2 - fair value measurements are based on significant observable pricing inputs, such as NYMEX-settled prices for natural gas and crude oil, and financial models that utilize implied forward LIBOR yield curves for interest-rate swaps.

• Level 3 - fair value measurements are based on inputs that may include one or more unobservable inputs, including natural gas basis and NGL price curves that incorporate observable and unobservable market data from broker quotes, third-party pricing services, market volatilities derived from the most recent NYMEX close spot prices and forward LIBOR curves, and adjustments for the credit risk of our counterparties. We corroborate the data on which our fair value estimates are based using our market knowledge of recent transactions, analysis of historical correlations and validation with independent broker quotes. These balances categorized as Level 3 are comprised of derivatives for natural gas and NGLs. We do not believe that our Level 3 fair value estimates have a material impact on our results of

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operations, as the majority of our derivatives are accounted for as hedges for which ineffectiveness has not been material.

Determining the appropriate classification of our fair value measurements within the fair value hierarchy requires management’s judgment regarding the degree to which market data is observable or corroborated by observable market data. We categorize derivatives for which fair value is determined using multiple inputs within a single level, based on the lowest level input that is significant to the fair value measurement in its entirety.

Recurring Fair Value Measurements - The following tables set forth our recurring fair value measurements for our continuing operations for the periods indicated:

	September 30, 2015
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Derivative assets
Commodity contracts
Financial contracts	$	40,799		$	—		$	5,756		$	46,555		$	(29,319	)	$	17,236
Physical contracts	—			—			4,866			4,866			—			4,866
Total derivative assets	$	40,799		$	—		$	10,622		$	51,421		$	(29,319	)	$	22,102
Derivative liabilities
Commodity contracts
Financial contracts	$	(573	)	$	—		$	(5,326	)	$	(5,899	)	$	5,899		$	—
Interest-rate contracts	—			(13,648		)	—			(13,648		)	—			(13,648		)
Total derivative liabilities	$	(573	)	$	(13,648	)	$	(5,326	)	$	(19,547	)	$	5,899		$	(13,648	)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis. We net derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and ONEOK Partners. At September 30, 2015, ONEOK Partners held $23.4 million of cash from various counterparties and no cash collateral posted.

(b) - Included in other current assets, other assets or other current liabilities in our Consolidated Balance Sheets.

	December 31, 2014
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Assets
Derivatives
Commodity contracts
Financial contracts	$	42,880		$	—		$	354		$	43,234		$	(25,979	)	$	17,255
Physical contracts	—			—			9,922			9,922			—			9,922
Interest-rate contracts	—			2,288			—			2,288			—			2,288
Total derivative assets	42,880			2,288			10,276			55,444			(25,979		)	29,465
Available-for-sale investment securities	1,773			—			—			1,773			—			1,773
Total assets	$	44,653		$	2,288		$	10,276		$	57,217		$	(25,979	)	$	31,238
Liabilities
Derivatives
Commodity contracts
Financial contracts	$	(169	)	$	—		$	(968	)	$	(1,137	)	$	1,137		$	—
Physical contracts	—			—			(23		)	(23		)	—			(23		)
Interest-rate contracts	—			(44,843		)	—			(44,843		)	—			(44,843		)
Total derivative liabilities	$	(169	)	$	(44,843	)	$	(991	)	$	(46,003	)	$	1,137		$	(44,866	)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis. We net derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and ONEOK Partners. At December 31, 2014, ONEOK Partners held $24.8 million of cash from various counterparties and no cash collateral posted.

(b) - Included in other current assets, other assets or other current liabilities in our Consolidated Balance Sheets.

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The following table sets forth a reconciliation of our Level 3 fair value measurements for our continuing operations for the periods indicated:

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
Derivative Assets (Liabilities)	2015			2014			2015			2014
	(Thousands of dollars)
Net assets (liabilities) at beginning of period	$	10,387		$	(1,313	)	$	9,285		$	(782	)
Total realized/unrealized gains (losses):
Included in earnings (a)	(15		)	207			95			(688		)
Included in other comprehensive income (loss)	(5,076		)	402			(4,084		)	(2,968		)
Purchases, issuances and settlements	—			—			—			3,734
Net assets (liabilities) at end of period	$	5,296		$	(704	)	$	5,296		$	(704	)

(a) - Included in commodity sales revenues in our Consolidated Statements of Income.

Realized/unrealized gains (losses) include the realization of ONEOK Partners’ derivative contracts through maturity. During the three and nine months ended September 30, 2015 and 2014, gains or losses included in earnings attributable to the change in unrealized gains or losses relating to assets and liabilities still held at the end of each reporting period were not material.

We recognize transfers into and out of the levels in the fair value hierarchy as of the end of each reporting period. During the three and nine months ended September 30, 2015 and 2014, there were no transfers between levels.

Other Financial Instruments -The approximate fair value of cash and cash equivalents, accounts receivable, accounts payable and notes payable is equal to book value, due to the short-term nature of these items. Our cash and cash equivalents are comprised of bank and money market accounts and are classified as Level 1. Our notes payable are classified as Level 2 since the estimated fair value of the notes payable can be determined using information available in the commercial paper market.

The estimated fair value of our consolidated long-term debt, including current maturities, was $8.1 billion and $7.5 billion at September 30, 2015, and December 31, 2014, respectively. The book value of our consolidated long-term debt, including current maturities, was $8.4 billion and $7.2 billion at September 30, 2015, and December 31, 2014, respectively. The estimated fair value of the aggregate of ONEOK’s and ONEOK Partners’ senior notes outstanding was determined using quoted market prices for similar issues with similar terms and maturities. The estimated fair value of our consolidated long-term debt is classified as Level 2.

E. RISK-MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

Risk-Management Activities - ONEOK Partners is sensitive to changes in natural gas, crude oil and NGL prices, principally as a result of contractual terms under which these commodities are processed, purchased and sold. ONEOK Partners uses physical-forward purchases and sales and financial derivatives to secure a certain price for a portion of its natural gas, condensate and NGL products; to reduce its exposure to interest-rate fluctuations; and to achieve more predictable cash flows. ONEOK Partners follows established policies and procedures to assess risk and approve, monitor and report its risk-management activities. ONEOK Partners has not used these instruments for trading purposes. We and ONEOK Partners are also subject to the risk of interest-rate fluctuation in the normal course of business.

Commodity price risk - Commodity price risk refers to the risk of loss in cash flows and future earnings arising from adverse changes in the price of natural gas, NGLs and condensate. ONEOK Partners uses the following commodity derivative instruments to mitigate the near-term commodity price risk associated with a portion of the forecasted sales of these commodities:

• Futures contracts - Standardized contracts to purchase or sell natural gas and crude oil for future delivery or settlement under the provisions of exchange regulations;

• Forward contracts - Nonstandardized commitments between two parties to purchase or sell natural gas, crude oil or NGLs for future physical delivery. These contracts are typically nontransferable and can only be canceled with the consent of both parties; and

• Swaps - Exchange of one or more payments based on the value of one or more commodities. These instruments transfer the financial risk associated with a future change in value between the counterparties of the transaction, without also conveying ownership interest in the asset or liability.

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ONEOK Partners may also use other instruments including options or collars to mitigate commodity price risk. Options are contractual agreements that give the holder the right, but not the obligation, to buy or sell a fixed quantity of a commodity at a fixed price within a specified period of time. Options may either be standardized and exchange traded or customized and nonexchange traded. A collar is a combination of a purchased put option and a sold call option, which places a floor and a ceiling price for commodity sales being hedged.

The Natural Gas Gathering and Processing segment is exposed to commodity price risk as a result of receiving commodities in exchange for services associated with its POP contracts. ONEOK Partners also is exposed to basis risk between the various production and market locations where it receives and sells commodities. As part of ONEOK Partners’ hedging strategy, it uses the previously described commodity derivative financial instruments and physical-forward contracts to reduce the impact of price fluctuations related to natural gas, NGLs and condensate.

The Natural Gas Liquids segment is exposed to location price differential risk, primarily as a result of the relative value of NGL purchases at one location and sales at another location. ONEOK Partners is also exposed to commodity price risk resulting from the relative values of the various NGL products to each other, NGLs in storage and the relative value of NGLs to natural gas. ONEOK Partners utilizes physical-forward contracts and commodity derivative financial instruments to reduce the impact of price fluctuations related to NGLs.

The Natural Gas Pipelines segment is exposed to commodity price risk because its intrastate and interstate natural gas pipelines retain natural gas from its customers for operations or as part of its fee for services provided. When the amount of natural gas consumed in operations by these pipelines differs from the amount provided by its customers, ONEOK Partners’ pipelines must buy or sell natural gas, or store or use natural gas from inventory, which can expose it to commodity price risk depending on the regulatory treatment for this activity. To the extent that commodity price risk in the Natural Gas Pipelines segment is not mitigated by fuel cost-recovery mechanisms, ONEOK Partners uses physical-forward sales or purchases to reduce the impact of price fluctuations related to natural gas. At September 30, 2015, and December 31, 2014, there were no financial derivative instruments with respect to ONEOK Partners’ natural gas pipeline operations.

Interest-rate risk - We and ONEOK Partners manage interest-rate risk through the use of fixed-rate debt, floating-rate debt and interest-rate swaps. Interest-rate swaps are agreements to exchange interest payments at some future point based on specified notional amounts. At December 31, 2014, ONEOK Partners had forward-starting interest-rate swaps with notional amounts totaling $900 million that were designated as cash flow hedges of the variability of interest payments on a portion of forecasted debt issuances that may result from changes in the benchmark interest rate before the debt is issued. Upon ONEOK Partners’ debt issuance in March 2015, it settled $500 million of its interest-rate swaps and realized a loss of $55.1 million, which is included in accumulated other comprehensive loss and will be amortized to interest expense over the term of the related debt. At September 30, 2015, ONEOK Partners’ remaining interest-rate swaps with notional amounts totaling $400 million have settlement dates of less than 12 months.

Accounting Treatment -We and ONEOK Partners record all derivative instruments at fair value, with the exception of normal purchases and normal sales transactions that are expected to result in physical delivery. Commodity price and interest-rate volatility may have a significant impact on the fair value of derivative instruments as of a given date. The accounting for changes in the fair value of a derivative instrument depends on whether it has been designated and qualifies as part of a hedging relationship and, if so, the reason for holding it.

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The table below summarizes the various ways in which we account for our derivative instruments and the impact on our consolidated financial statements:

		Recognition and Measurement
Accounting Treatment		Balance Sheet		Income Statement
Normal purchases and normal sales	-	Fair value not recorded	-	Change in fair value not recognized in earnings
Mark-to-market	-	Recorded at fair value	-	Change in fair value recognized in earnings
Cash flow hedge	-	Recorded at fair value	-	Ineffective portion of the gain or loss on the derivative instrument is recognized in earnings
	-	Effective portion of the gain or loss on the derivative instrument is reported initially as a component of accumulated other comprehensive income (loss)	-	Effective portion of the gain or loss on the derivative instrument is reclassified out of accumulated other comprehensive income (loss) into earnings when the forecasted transaction affects earnings
Fair value hedge	-	Recorded at fair value	-	The gain or loss on the derivative instrument is recognized in earnings
	-	Change in fair value of the hedged item is recorded as an adjustment to book value	-	Change in fair value of the hedged item is recognized in earnings

To reduce its exposure to fluctuations in natural gas, NGLs and condensate prices, ONEOK Partners periodically enters into futures, forward purchases and sales, options or swap transactions in order to hedge anticipated purchases and sales of natural gas, NGLs and condensate. Interest-rate swaps are used from time to time to manage interest-rate risk. Under certain conditions, we designate these derivative instruments as a hedge of exposure to changes in fair values or cash flows. We formally document all relationships between hedging instruments and hedged items, as well as risk-management objectives and strategies for undertaking various hedge transactions, and methods for assessing and testing correlation and hedge ineffectiveness. We specifically identify the forecasted transaction that has been designated as the hedged item in a cash flow hedge relationship. We assess the effectiveness of hedging relationships quarterly by performing an effectiveness analysis on our fair value and cash flow hedging relationships to determine whether the hedge relationships are highly effective on a retrospective and prospective basis. ONEOK Partners also documents its normal purchases and normal sales transactions that are expected to result in physical delivery and that ONEOK Partners elects to exempt from derivative accounting treatment.

The realized revenues and purchase costs of our and ONEOK Partners’ derivative instruments not considered held for trading purposes and derivatives that qualify as normal purchases or normal sales that are expected to result in physical delivery are reported on a gross basis. Cash flows from futures, forwards and swaps that are accounted for as hedges are included in the same category as the cash flows from the related hedged items in our Consolidated Statements of Cash Flows.

Fair Values of Derivative Instruments - See Note D for a discussion of the inputs associated with our fair value measurements. The following table sets forth the fair values of derivative instruments for our continuing operations for the periods indicated:

	September 30, 2015					December 31, 2014
	Assets (a)		(Liabilities) (a)			Assets (a)		(Liabilities) (a)
	(Thousands of dollars)
Derivatives designated as hedging instruments
Commodity contracts
Financial contracts	$	45,534	$	(5,108	)	$	43,234	$	(1,137	)
Physical contracts	4,866		—			9,922		—
Interest-rate contracts	—		(13,648		)	2,288		(44,843		)
Total derivatives designated as hedging instruments	50,400		(18,756		)	55,444		(45,980		)
Derivatives not designated as hedging instruments
Commodity contracts
Financial contracts	1,021		(791		)	—		—
Physical contracts	—		—			—		(23		)
Total derivatives not designated as hedging instruments	1,021		(791		)	—		(23		)
Total derivatives	$	51,421	$	(19,547	)	$	55,444	$	(46,003	)

(a) - Included on a net basis in other current assets, other assets or other current liabilities in our Consolidated Balance Sheets.

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Notional Quantities for Derivative Instruments - The following table sets forth the notional quantities for derivative instruments for our continuing operations for the periods indicated:

		September 30, 2015					December 31, 2014
	Contract Type	Purchased/ Payor		Sold/ Receiver			Purchased/ Payor		Sold/ Receiver
Derivatives designated as hedging instruments:
Cash flow hedges
Fixed price
- Natural gas (Bcf)	Futures and swaps	—		(38.7		)	—		(41.2		)
- Crude oil and NGLs (MMBbl)	Futures, forwards and swaps	—		(3.5		)	—		(0.5		)
Basis
- Natural gas (Bcf)	Futures and swaps	—		(38.7		)	—		(41.2		)
Interest-rate contracts (Millions of dollars)	Forward-starting swaps	$	400.0	$	—		$	900.0	$	—
Derivatives not designated as hedging instruments:
Fixed price
- Crude oil and NGLs (MMBbl)	Futures, forwards and swaps	0.5		(0.5		)	—		—

These notional amounts are used to summarize the volume of financial instruments; however, they do not reflect the extent to which the positions offset one another and, consequently, do not reflect ONEOK Partners’ actual exposure to market or credit risk.

Cash Flow Hedges - ONEOK Partners uses derivative instruments to hedge the cash flows associated with anticipated purchases and sales of natural gas, NGLs and condensate and cost of fuel used in the transportation of natural gas. Accumulated other comprehensive loss at September 30, 2015, includes unrealized gains of approximately $12.0 million, net of tax, related to these hedges that will be realized within the next 15 months as the forecasted transactions affect earnings. If commodity prices remain at current levels, we will recognize $10.7 million in net gains over the next 12 months and net gains of $1.3 million thereafter. The amount deferred in accumulated other comprehensive loss attributable to our and ONEOK Partners’ settled interest-rate swaps is a loss of $50.6 million, net of tax, which will be recognized over the life of the long-term, fixed-rate debt, including losses of $6.2 million, net of tax, that will be reclassified into earnings during the next 12 months as the hedged items affect earnings. The remaining amounts in accumulated other comprehensive loss are attributable primarily to ONEOK Partners’ forward-starting interest-rate swaps with future settlement dates, which will be amortized to interest expense over the life of long-term, fixed-rate debt upon issuance of ONEOK Partners’ debt.

The following table sets forth the unrealized effect of cash flow hedges recognized in other comprehensive income (loss) for the periods indicated:

Derivatives in Cash Flow Hedging Relationships	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2015			2014			2015			2014
	(Thousands of dollars)
Continuing Operations
Commodity contracts	$	36,559		$	17,133		$	47,650		$	(24,743	)
Interest-rate contracts	(20,610		)	(9,755		)	(26,277		)	(56,849		)
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion) for continuing operations	$	15,949		$	7,378		$	21,373		$	(81,592	)

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The following table sets forth the effect of cash flow hedges in our Consolidated Statements of Income for the periods indicated:

Derivatives in Cash Flow Hedging Relationships	Location of Gain (Loss) Reclassified from  Accumulated Other Comprehensive Income (Loss) into Net Income (Effective Portion)	Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2015			2014			2015			2014
		(Thousands of dollars)
Continuing Operations
Commodity contracts	Commodity sales revenues	$	22,770		$	(355	)	$	54,020		$	(31,961	)
Interest-rate contracts	Interest expense	(4,554		)	(3,525		)	(12,869		)	(18,372		)
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income on derivatives (effective portion) for continuing operations		$	18,216		$	(3,880	)	$	41,151		$	(50,333	)

For the nine months ended September 30, 2014, an unrealized loss of $3.7 million was recognized in other comprehensive income (loss) and a realized loss of $12.8 million was reclassified from accumulated other comprehensive income (loss) related to cash flow hedges for our former energy services business.

Ineffectiveness related to cash flow hedges was not material for the three and nine months ended September 30, 2015 and 2014. In the event that it becomes probable that a forecasted transaction will not occur, we would discontinue cash flow hedge treatment, which would affect earnings. For the three and nine months ended September 30, 2015, and the three months ended September 30, 2014, there were no gains or losses due to the discontinuance of cash flow hedge treatment. For the nine months ended September 30, 2014, we reclassified losses of $4.6 million, net of taxes of $3.1 million, to interest expense from accumulated other comprehensive loss due to the discontinuance of cash flow hedge treatment related to the early retirement of long-term debt. See Note G for additional information.

Credit Risk - We and ONEOK Partners monitor the creditworthiness of counterparties and compliance with policies and limits established by our Risk Oversight and Strategy Committee. We and ONEOK Partners maintain credit policies with regard to counterparties that we believe minimize overall credit risk. These policies include an evaluation of potential counterparties’ financial condition (including credit ratings, bond yields and credit default swap rates), collateral requirements under certain circumstances and the use of standardized master-netting agreements that allow us to net the positive and negative exposures associated with a single counterparty. ONEOK Partners has counterparties whose credit is not rated, and for those customers, it uses internally developed credit ratings.

Some of ONEOK Partners’ financial derivative instruments contain provisions that require it to maintain an investment-grade credit rating from S&P and/or Moody’s. If ONEOK Partners’ credit ratings on its senior unsecured long-term debt were to decline below investment grade, the counterparties to the derivative instruments could request collateralization on derivative instruments in net liability positions. There were no financial derivative instruments with contingent features related to credit risk that were in a net liability position at September 30, 2015.

The counterparties to ONEOK Partners’ derivative contracts consist primarily of major energy companies, financial institutions and commercial and industrial end users. This concentration of counterparties may affect ONEOK Partners’ overall exposure to credit risk, either positively or negatively, in that the counterparties may be affected similarly by changes in economic, regulatory or other conditions. Based on ONEOK Partners’ policies, exposures, credit and other reserves, we do not anticipate a material adverse effect on our financial position or results of operations as a result of counterparty nonperformance.

At September 30, 2015, the net credit exposure from ONEOK Partners’ derivative assets is primarily with investment-grade companies in the financial services sector.

F. CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE

ONEOK Credit Agreement - The ONEOK Credit Agreement, which is scheduled to expire in January 2019, is a $300 million revolving credit facility and contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of indebtedness to Consolidated EBITDA (EBITDA, as defined in our ONEOK Credit Agreement) of no more than 4.0 to 1. Upon breach of certain covenants by us in the ONEOK Credit Agreement, amounts outstanding under the ONEOK Credit Agreement, if any, may become due and payable immediately. At September 30, 2015, ONEOK’s ratio of indebtedness to Consolidated EBITDA was 2.4 to 1, and ONEOK was in compliance with all covenants under the ONEOK Credit Agreement. As a result of a reduction in the borrowing capacity of the ONEOK Credit Agreement due to the ONE Gas

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separation, we wrote off approximately $2.9 million in interest expense of previously deferred credit agreement issuance costs in the first quarter 2014.

The ONEOK Credit Agreement also includes a $50 million sublimit for the issuance of standby letters of credit and a $50 million sublimit for swingline loans. Under the terms of the ONEOK Credit Agreement, ONEOK may request an increase in the size of the facility to an aggregate of $500 million from $300 million by either commitments from new lenders or increased commitments from existing lenders. The ONEOK Credit Agreement contains provisions for an applicable margin rate and an annual facility fee, both of which adjust with changes in our credit rating. Based on our current credit rating, borrowings, if any, will accrue at LIBOR plus 145 basis points, and the annual facility fee is 30 basis points.

At September 30, 2015, ONEOK had $1.1 million in letters of credit issued and no borrowings under the ONEOK Credit Agreement. In February 2014, we repaid all amounts outstanding under our commercial paper program, with a portion of the proceeds received from ONE Gas in connection with the separation, and terminated the program. See Note G for additional information.

ONEOK Partners Credit Agreement - At September 30, 2015, ONEOK Partners had $287.3 million of commercial paper outstanding, $14.0 million in letters of credit issued and no borrowings under the ONEOK Partners Credit Agreement.

The ONEOK Partners Credit Agreement, which is scheduled to expire in January 2019, is a $2.4 billion revolving credit facility and includes a $100 million sublimit for the issuance of standby letters of credit and a $150 million swingline sublimit. The ONEOK Partners Credit Agreement is available for general partnership purposes. During the first quarter 2015, ONEOK Partners increased the size of the ONEOK Partners Credit Agreement to $2.4 billion from $1.7 billion by exercising its option to increase the capacity of the facility through increased commitments from existing lenders and a commitment from one new lender. During the first quarter 2015, ONEOK Partners also increased the size of its commercial paper program to $2.4 billion from $1.7 billion. Amounts outstanding under ONEOK Partners’ commercial paper program reduce the borrowing capacity under the ONEOK Partners Credit Agreement.

The ONEOK Partners Credit Agreement contains provisions for an applicable margin rate and an annual facility fee, both of which adjust with changes in its credit rating. Under the terms of the ONEOK Partners Credit Agreement, based on ONEOK Partners’ current credit ratings, borrowings, if any, will accrue at LIBOR plus 117.5 basis points, and the annual facility fee is 20 basis points. The ONEOK Partners Credit Agreement is guaranteed fully and unconditionally by the Intermediate Partnership. Borrowings under the ONEOK Partners Credit Agreement are nonrecourse to ONEOK.

The ONEOK Partners Credit Agreement contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of indebtedness to adjusted EBITDA (EBITDA, as defined in the ONEOK Partners Credit Agreement, adjusted for all noncash charges and increased for projected EBITDA from certain lender-approved capital expansion projects) of no more than 5.0 to 1. If ONEOK Partners consummates one or more acquisitions in which the aggregate purchase price is $25 million or more, the allowable ratio of indebtedness to adjusted EBITDA will increase to 5.5 to 1 for the quarter in which the acquisition was completed and the two following quarters. As a result of the West Texas LPG acquisition ONEOK Partners completed in the fourth quarter 2014, the allowable ratio of indebtedness to adjusted EBITDA increased to 5.5 to 1 through the second quarter 2015. If ONEOK Partners were to breach certain covenants in the ONEOK Partners Credit Agreement, amounts outstanding under the ONEOK Partners Credit Agreement, if any, may become due and payable immediately. At September 30, 2015, ONEOK Partners’ ratio of indebtedness to adjusted EBITDA was 4.3 to 1, and it was in compliance with all covenants under the ONEOK Partners Credit Agreement.

Neither ONEOK nor ONEOK Partners guarantees the debt or other similar commitments of unaffiliated parties. ONEOK does not guarantee the debt, commercial paper or other similar commitments of ONEOK Partners, and ONEOK Partners does not guarantee the debt or other similar commitments of ONEOK.

G. LONG-TERM DEBT

ONEOK Debt Issuance - In August 2015, we completed an underwritten public offering of $500 million, 7.5 percent senior notes due 2023. The net proceeds, after deducting underwriting discounts, commissions and other expenses, were approximately $487.1 million. We used the proceeds together with cash on hand to purchase $650 million of additional common units from ONEOK Partners.

The indenture governing ONEOK’s senior notes due 2023 includes an event of default upon the acceleration of other indebtedness of $100 million or more. Such an event of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of the outstanding senior notes due 2023 to declare those senior notes immediately due and payable

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in full. The indenture also contains a provision that allows the holders of the notes to require ONEOK to offer to repurchase all or any part of their notes if a change of control and a credit rating downgrade occur at a purchase price of 101 percent of the principal amount, plus accrued and unpaid interest, if any.

ONEOK may redeem the remaining balance of its senior notes due 2023 at a redemption price equal to the principal amount, plus accrued and unpaid interest, starting three months before the maturity date.  Prior to this date, ONEOK may redeem these senior notes in whole or in part, at any time prior to their maturity at a redemption price equal to the principal amount, plus accrued and unpaid interest and a make-whole premium.  The redemption price will never be less than 100 percent of the principal amount of the respective note plus accrued and unpaid interest to the redemption date.  ONEOK’s senior notes due 2023 are senior unsecured obligations, ranking equally in right of payment with all of ONEOK’s existing and future unsecured senior indebtedness.

ONEOK Partners Debt Issuance - In March 2015, ONEOK Partners completed an underwritten public offering of $800 million of senior notes, consisting of $300 million, 3.8 percent senior notes due 2020, and $500 million, 4.9 percent senior notes due 2025. The net proceeds, after deducting underwriting discounts, commissions and other expenses, were approximately $792.3 million. ONEOK Partners used the proceeds to repay amounts outstanding under its commercial paper program and for general partnership purposes.

These notes are governed by an indenture, dated September 25, 2006, between ONEOK Partners and Wells Fargo Bank, N.A., the trustee, as supplemented. The indenture does not limit the aggregate principal amount of debt securities that may be issued and provides that debt securities may be issued from time to time in one or more additional series. The indenture contains covenants including, among other provisions, limitations on ONEOK Partners’ ability to place liens on its property or assets and to sell and lease back its property. The indenture includes an event of default upon acceleration of other indebtedness of $100 million or more. Such events of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of any of ONEOK Partners’ outstanding senior notes to declare those notes immediately due and payable in full.

ONEOK Partners may redeem its 3.8 percent senior notes due 2020 and its 4.9 percent senior notes due 2025 from the March 2015 offering at par, plus accrued and unpaid interest to the redemption date, starting one month and three months, respectively, before their maturity dates. Prior to these dates, ONEOK Partners may redeem these notes, in whole or in part, at a redemption price equal to the principal amount, plus accrued and unpaid interest and a make-whole premium. The redemption price will never be less than 100 percent of the principal amount of the respective note plus accrued and unpaid interest to the redemption date. ONEOK Partners’ senior notes are senior unsecured obligations, ranking equally in right of payment with all of ONEOK Partners’ existing and future unsecured senior indebtedness, and structurally subordinate to any of the existing and future debt and other liabilities of any ONEOK Partners’ nonguarantor subsidiaries.

ONEOK Partners Debt Maturity - ONEOK Partners’ $650 million, 3.25 percent senior notes mature on February 1, 2016. The carrying amount of these notes is reflected in current portion of long-term debt in our Consolidated Balance Sheet as of September 30, 2015.

ONE Gas Debt Issuance - In January 2014, ONE Gas, which at the time was our wholly owned subsidiary, completed a private placement of three series of senior notes aggregating $1.2 billion, consisting of $300 million of five-year senior notes at 2.07 percent; $300 million of 10-year senior notes at 3.61 percent; and $600 million of 30-year senior notes at 4.658 percent. ONE Gas received approximately $1.19 billion from the offering, net of issuance costs. Our obligations related to the ONE Gas Senior Notes terminated in connection with the completion of the separation of ONE Gas.

ONEOK Debt Repayment - ONE Gas made a cash payment to us of approximately $1.13 billion from the proceeds of the ONE Gas senior notes offering. In February 2014, we retired approximately $152.5 million of the 4.25 percent senior notes due in 2022 through a tender offer. The total amount paid was approximately $150 million.

In February 2014, we called our $400 million, 5.2 percent senior notes due in 2015. The full repayment occurred in March 2014 and totaled $430.1 million, including accrued but unpaid interest to the redemption date. We recorded a loss on extinguishment of $24.8 million related to the debt retirements, which is included in other expense in our Consolidated Statements of Income.

H. EQUITY

Dividends - Dividends paid on our common stock to shareholders of record at the close of business on January 30, 2015, April 30, 2015, and August 3, 2015, were $0.605 per share in each instance.  A dividend of $0.615 per share was declared for shareholders of record at the close of business on November 2, 2015, payable November 13, 2015.

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See Note M for a discussion of ONEOK Partners’ issuance of common units and distributions to noncontrolling interests.

I. ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

The following table sets forth the balance in accumulated other comprehensive income (loss) for the period indicated:

	Unrealized Gains (Losses) on Risk- Management Assets/Liabilities (a)			Unrealized Holding Gains (Losses) on Investment Securities (a)			Pension and Postretirement Benefit Plan Obligations (a) (b)			Accumulated Other Comprehensive Income (Loss) (a)
	(Thousands of dollars)
January 1, 2015	$	(37,349	)	$	955		$	(99,959	)	$	(136,353	)
Other comprehensive income (loss) before reclassifications	3,661			(955		)	65			2,771
Amounts reclassified from accumulated other comprehensive income (loss)	(9,785		)	—			7,255			(2,530		)
Net current period other comprehensive income (loss) attributable to ONEOK	(6,124		)	(955		)	7,320			241
September 30, 2015	$	(43,473	)	$	—		$	(92,639	)	$	(136,112	)

(a) All amounts are presented net of tax.

(b) Includes amounts related to supplemental executive retirement plan.

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The following table sets forth the effect of reclassifications from accumulated other comprehensive income (loss) in our Consolidated Statements of Income for the periods indicated:

Details about Accumulated Other Comprehensive Income (Loss) Components	Three Months Ended						Nine Months Ended						Affected Line Item in the Consolidated Statements of Income
	September 30,						September 30,
	2015			2014			2015			2014
	(Thousands of dollars)
Unrealized (gains) losses on risk-management assets/liabilities
Commodity contracts	$	(22,770	)	$	355		$	(54,020	)	$	31,961		Commodity sales revenues
Interest-rate contracts	4,554			3,525			12,869			18,372			Interest expense
	(18,216		)	3,880			(41,151		)	50,333			Income before income taxes
	2,957			(748		)	5,621			(9,845		)	Income tax expense
	(15,259		)	3,132			(35,530		)	40,488			Income from continuing operations
	—			—			—			7,682			Income (loss) from discontinued operations
	(15,259		)	3,132			(35,530		)	48,170			Net income
Noncontrolling interests	(10,150		)	1,928			(25,745		)	24,574			Less: Net income attributable to noncontrolling interests
	$	(5,109	)	$	1,204		$	(9,785	)	$	23,596		Net income attributable to ONEOK
Pension and postretirement benefit plan obligations (a)
Amortization of net loss	$	4,422		$	4,009		$	13,268		$	11,936
Amortization of unrecognized prior service cost	(392		)	(368		)	(1,176		)	(1,102		)
	4,030			3,641			12,092			10,834			Income before income taxes
	(1,612		)	(1,456		)	(4,837		)	(4,334		)	Income tax expense
	2,418			2,185			7,255			6,500			Income from continuing operations
	—			—			—			1,648			Income from discontinued operations
	$	2,418		$	2,185		$	7,255		$	8,148		Net income attributable to ONEOK
Total reclassifications for the period attributable to ONEOK	$	(2,691	)	$	3,389		$	(2,530	)	$	31,744		Net income attributable to ONEOK

(a) These components of accumulated other comprehensive income (loss) are included in the computation of net periodic benefit cost. See Note K for additional detail of our net periodic benefit cost.

J. EARNINGS PER SHARE

The following tables set forth the computation of basic and diluted EPS from continuing operations for the periods indicated:

	Three Months Ended September 30, 2015
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	86,017	210,296	$	0.41
Diluted EPS from continuing operations
Effect of dilutive securities	—		228
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	86,017	210,524	$	0.41

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	Three Months Ended September 30, 2014
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	64,629	209,489	$	0.31
Diluted EPS from continuing operations
Effect of dilutive securities	—		1,270
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	64,629	210,759	$	0.31

	Nine Months Ended September 30, 2015
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	223,606	210,138	$	1.06
Diluted EPS from continuing operations
Effect of dilutive securities	—		371
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	223,606	210,509	$	1.06

	Nine Months Ended September 30, 2014
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	225,969	209,341	$	1.08
Diluted EPS from continuing operations
Effect of dilutive securities	—		1,141
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	225,969	210,482	$	1.07

K. EMPLOYEE BENEFIT PLANS

The following tables set forth the components of net periodic benefit cost for our pension and postretirement benefit plans for our continuing operations for the periods indicated:

	Pension Benefits
	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2015			2014			2015			2014
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	1,887		$	1,784		$	5,661		$	5,429
Interest cost	4,546			4,488			13,638			13,744
Expected return on assets	(5,213		)	(4,775		)	(15,639		)	(14,644		)
Amortization of unrecognized prior service cost	23			48			69			144
Amortization of net loss	3,987			3,798			11,961			11,309
Other	—			16			—			136
Net periodic benefit cost	$	5,230		$	5,359		$	15,690		$	16,118

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	Postretirement Benefits
	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2015			2014			2015			2014
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	186		$	175		$	558		$	533
Interest cost	587			603			1,760			1,825
Expected return on assets	(564		)	(513		)	(1,692		)	(1,623		)
Amortization of unrecognized prior service cost	(415		)	(416		)	(1,245		)	(1,246		)
Amortization of net loss	435			211			1,307			627
Other	—			—			—			(2		)
Net periodic benefit cost	$	229		$	60		$	688		$	114

L. UNCONSOLIDATED AFFILIATES

Equity in Net Earnings from Investments -The following table sets forth ONEOK Partners’ equity in net earnings from investments for the periods indicated:

	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2015		2014			2015		2014
	(Thousands of dollars)
Share of investee earnings
Northern Border Pipeline	$	16,156	$	14,371		$	51,131	$	53,657
Overland Pass Pipeline Company	10,538		3,856			27,048		12,708
Other (a)	5,550		(17,153		)	15,026		(6,197		)
Total share of investee earnings	32,244		1,074			93,205		60,168
Impairment of investment in Bighorn Gas Gathering	—		(53,421		)	—		(53,421		)
Equity in net earnings (loss) from investments	$	32,244	$	(52,347	)	$	93,205	$	6,747

(a) - Includes proportionate share of investee impairment of long-lived assets charge on Bighorn Gas Gathering of $23.0 million for the three and nine months ended September 30, 2014.

Unconsolidated Affiliates Financial Information - The following table sets forth summarized combined financial information of ONEOK Partners’ unconsolidated affiliates for the periods indicated:

	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2015		2014			2015		2014
	(Thousands of dollars)
Income Statement
Operating revenues	$	135,474	$	126,218		$	390,793	$	403,006
Operating expenses (a)	$	64,786	$	123,620		$	178,324	$	247,169
Net income (loss) (a)	$	67,121	$	(5,119	)	$	196,123	$	134,432
Distributions paid to ONEOK Partners	$	36,370	$	31,574		$	117,153	$	109,223

(a) - Includes long-lived asset impairment charge on Bighorn Gas Gathering for the three and nine months ended September 30, 2014.

ONEOK Partners incurred expenses in transactions with unconsolidated affiliates of $28.4 million and $15.0 million for the three months ended September 30, 2015 and 2014, respectively, and $74.2 million and $43.5 million for the nine months ended September 30, 2015 and 2014, respectively, primarily related to Overland Pass Pipeline Company and Northern Border Pipeline Company. Accounts payable to ONEOK Partners’ equity method investees at September 30, 2015, and December 31, 2014, were $9.4 million and $20.5 million, respectively.

Roadrunner Gas Transmission - In March 2015, ONEOK Partners entered into a 50-50 joint venture named Roadrunner Gas Transmission (Roadrunner) with a subsidiary of Fermaca Infrastructure B.V. (Fermaca), a Mexico City-based natural gas

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infrastructure company, to construct a pipeline to transport natural gas from the Permian Basin in West Texas to the Mexican border near El Paso, Texas. During the nine months ended September 30, 2015, ONEOK Partners contributed approximately $30 million to Roadrunner.

Powder River Basin Equity Method Investments - Crude oil and natural gas producers have primarily focused their development efforts on crude oil and NGL-rich supply basins rather than areas with dry natural gas production, such as the coal-bed methane areas in the Powder River Basin. The reduced coal-bed methane development activities and natural production declines in the dry natural gas formations of the Powder River Basin have resulted in lower natural gas volumes available to be gathered. While the reserve potential in the dry natural gas formations of the Powder River Basin still exists, future drilling and development in this area will be affected by commodity prices and producers’ alternative prospects.

The current commodity price environment has caused natural gas producers to reduce drilling for natural gas, which we expect will slow volume growth or reduce volumes of natural gas delivered to systems owned by ONEOK Partners’ Powder River Basin equity method investments. A continued decline in volumes gathered in the coal-bed methane area of the Powder River Basin may reduce ONEOK Partners’ ability to recover the carrying value of its equity investments in this area and could result in noncash charges to earnings. The net book value of ONEOK Partners’ equity method investments in this dry natural gas area is $214.2 million, which includes $130.5 million of equity method goodwill.

M. ONEOK PARTNERS

Ownership Interestin ONEOK Partners - Our ownership interest in ONEOK Partners is shown in the table below at September 30, 2015:

General partner interest	2.0	%
Limited partner interest (a)	39.2	%
Total ownership interest	41.2	%

(a) - Represents 41.3 million common units and approximately 73.0 million Class B units, which are convertible, at our option, into common units.

Equity Issuances - In August 2015, ONEOK Partners completed the sale to us in a private placement of approximately 21.5 million common units at a price of $30.17 per unit. Additionally, ONEOK Partners completed a concurrent sale of approximately 3.3 million common units at a price of $30.17 per unit to funds managed by Kayne Anderson Capital Advisors in a registered direct offering, which were issued through ONEOK Partners’ existing “at-the-market” equity program. The combined offerings generated net cash proceeds of approximately $749 million to ONEOK Partners. In conjunction with these issuances, ONEOK Partners GP contributed approximately $15.3 million in order to maintain our 2 percent general partner interest in ONEOK Partners. ONEOK Partners used the proceeds for general partnership purposes, including capital expenditures and repayment of commercial paper borrowings. No other units were sold through the “at-the-market” program during the three months ended September 30, 2015.

ONEOK Partners has an “at-the-market” equity program for the offer and sale from time to time of its common units, up to an aggregate amount of $650 million. The program allows ONEOK Partners to offer and sell its common units at prices it deems appropriate through a sales agent. Sales of common units are made by means of ordinary brokers’ transactions on the NYSE, in block transactions or as otherwise agreed to between ONEOK Partners and the sales agent. ONEOK Partners is under no obligation to offer and sell common units under the program. At September 30, 2015, ONEOK Partners had approximately $138 million of registered common units available for issuance through its “at-the-market” equity program.

During the nine months ended September 30, 2015, ONEOK Partners sold approximately 10.5 million common units through its “at-the-market” equity program, including the units sold to funds managed by Kayne Anderson Capital Advisors in the registered direct offering discussed above. The net proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, were approximately $381.6 million, which were used for general partnership purposes, including repayment of commercial paper borrowings.

In May 2014, ONEOK Partners completed an underwritten public offering of approximately 13.9 million common units at a public offering price of $52.94 per common unit, generating net proceeds of approximately $714.5 million. In conjunction with this issuance, ONEOK Partners GP contributed approximately $15.0 million in order to maintain our 2 percent general partner interest in ONEOK Partners. ONEOK Partners used the proceeds for general partnership purposes, including capital expenditures and repayment of commercial paper borrowings.

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During the three months ended September 30, 2014, ONEOK Partners sold approximately 1.4 million common units through its “at-the-market” equity program. The net proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, were approximately $81.3 million, which were used for general partnership purposes.

During the nine months ended September 30, 2014, ONEOK Partners sold 4.4 million common units through the “at-the-market” program that resulted in net proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, of approximately $245.4 million and used the proceeds for general partnership purposes.

We account for the difference between the carrying amount of our investment in ONEOK Partners and the underlying book value arising from issuance of common units by ONEOK Partners as an equity transaction. If ONEOK Partners issues common units at a price different than our carrying value per unit, we account for the premium or deficiency as an adjustment to paid-in capital. As a result of ONEOK Partners’ issuance of common units, we recognized a decrease to paid-in capital of approximately $34.4 million, net of taxes, for the nine months ended September 30, 2015.

Cash Distributions - We receive distributions from ONEOK Partners on the common and Class B units we own and the 2 percent general partner interest, which includes our incentive distribution rights. Under the Partnership Agreement, distributions are made to the partners with respect to each calendar quarter in an amount equal to 100 percent of available cash as defined in the Partnership Agreement. Available cash generally will be distributed 98 percent to limited partners and 2 percent to the general partner. The general partner’s percentage interest in quarterly distributions is increased after certain specified target levels are met during the quarter. Under the incentive distribution provisions, as set forth in the Partnership Agreement the general partner receives:

• 15 percent of amounts distributed in excess of $0.3025 per unit;

• 25 percent of amounts distributed in excess of $0.3575 per unit; and

• 50 percent of amounts distributed in excess of $0.4675 per unit.

In October 2015, a cash distribution of $0.79 per unit ($3.16 per unit on an annualized basis) was declared for the third quarter 2015 and will be paid on November 13, 2015, to unitholders of record at the close of business on November 2, 2015.

The following table shows ONEOK Partners’ distributions paid in the periods indicated:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2015		2014		2015		2014
	(Thousands, except per unit amounts)
Distribution per unit	$	0.79	$	0.76	$	2.37	$	2.235
General partner distributions	$	6,081	$	5,501	$	17,950	$	15,361
Incentive distributions	91,794		80,381		270,962		220,547
Distributions to general partner	97,875		85,882		288,912		235,908
Limited partner distributions to ONEOK	73,302		70,519		219,907		207,381
Limited partner distributions to noncontrolling interest	132,862		118,644		388,655		324,805
Total distributions paid	$	304,039	$	275,045	$	897,474	$	768,094

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The following table shows ONEOK Partners’ distributions declared for the periods indicated and paid within 45 days of the end of the period:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2015		2014		2015		2014
	(Thousands, except per unit amounts)
Distribution per unit	$	0.79	$	0.775	$	2.37	$	2.280
General partner distributions	$	6,660	$	5,683	$	18,696	$	16,195
Incentive distributions	100,538		84,452		282,221		236,744
Distributions to general partner	107,198		90,135		300,917		252,939
Limited partner distributions to ONEOK	90,323		71,911		236,927		211,557
Limited partner distributions to noncontrolling interest	135,480		122,105		396,925		345,255
Total distributions declared	$	333,001	$	284,151	$	934,769	$	809,751

Relationship - We consolidate ONEOK Partners in our consolidated financial statements; however, we are restricted from the assets and cash flows of ONEOK Partners except for the distributions we receive. Distributions are declared quarterly by ONEOK Partners GP based on the terms of the Partnership Agreement. See Note O for more information on ONEOK Partners’ results.

Affiliate Transactions - We provide a variety of services to our affiliates, including cash management and financial services, employee benefits, legal and administrative services by our employees and management, insurance and office space leased in our headquarters building and other field locations. Where costs are incurred specifically on behalf of an affiliate, the costs are billed directly to the affiliate by us. In other situations, the costs may be allocated to the affiliates through a variety of methods, depending upon the nature of the expenses and the activities of the affiliates. Beginning in the second quarter 2014, we allocate substantially all of our general overhead costs to ONEOK Partners as a result of the separation of our natural gas distribution business and the wind down of our energy services business in the first quarter 2014. For the first quarter 2014, it is not practicable to determine what these general overhead costs would have been on a stand-alone basis.

The following table shows ONEOK Partners’ transactions with us for the periods indicated:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2015		2014		2015		2014
	(Thousands of dollars)
Revenues	$	—	$	—	$	—	$	53,526
Expenses
Cost of sales and fuel	$	—	$	—	$	—	$	10,835
Operating expenses	89,342		84,221		265,611		240,172
Total expenses	$	89,342	$	84,221	$	265,611	$	251,007

Prior to the ONE Gas separation, ONEOK Partners provided natural gas sales and transportation and storage services to our former natural gas distribution business. Prior to February 1, 2014, these revenues and related costs were eliminated in consolidation. Beginning February 1, 2014, these revenues represent third-party transactions with ONE Gas and are not eliminated in consolidation, as such sales and services have continued subsequent to the separation and are expected to continue in future periods. Prior to the completion of the energy services wind down, ONEOK Partners provided natural gas and natural gas liquids sales and transportation and storage services to our energy services business. While these transactions were eliminated in consolidation in previous periods, they are now reflected as affiliate transactions and not eliminated in consolidation as these transactions have continued with third parties. See Note B for additional detail on these revenues.

N. COMMITMENTS AND CONTINGENCIES

Environmental Matters - ONEOK Partners is subject to multiple historical preservation, wildlife preservation and environmental laws and/or regulations that affect many aspects of our present and future operations. Regulated activities include, but are not limited to, those involving air emissions, storm water and wastewater discharges, handling and disposal of

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solid and hazardous wastes, wetlands preservation, hazardous materials transportation, and pipeline and facility construction. These laws and regulations require ONEOK Partners to obtain and/or comply with a wide variety of environmental clearances, registrations, licenses, permits and other approvals. Failure to comply with these laws, regulations, licenses and permits may expose ONEOK Partners to fines, penalties and/or interruptions in its operations that could be material to our results of operations. For example, if a leak or spill of hazardous substances or petroleum products occurs from pipelines or facilities that ONEOK Partners owns, operates or otherwise uses, ONEOK Partners could be held jointly and severally liable for all resulting liabilities, including response, investigation and cleanup costs, which could affect materially our results of operations and cash flows. In addition, emissions controls and/or other regulatory or permitting mandates under the Clean Air Act and other similar federal and state laws could require unexpected capital expenditures at ONEOK Partners’ facilities. We cannot assure that existing environmental statutes and regulations will not be revised or that new regulations will not be adopted or become applicable to ONEOK Partners.

In June 2013, the Executive Office of the President of the United States (the President) issued the President’s Climate Action Plan, which includes, among other things, plans for further regulatory actions to reduce carbon emissions from various sources. On March 28, 2014, the President released the Climate Action Plan - Strategy to Reduce Methane Emissions (Methane Strategy) that lists a number of actions the federal agencies will undertake to continue to reduce above-ground methane emissions from several industries, including the oil and natural gas sectors. The proposed measures outlined in the Methane Strategy include, without limitation, the following: collaboration with the states to encourage emission reductions; standards to minimize natural gas venting and flaring on public lands; policy recommendations for reducing emissions from energy infrastructure to increase the performance of the nation’s energy transmission, storage and distribution systems; and continued efforts by PHMSA to require pipeline operators to take steps to eliminate leaks and prevent accidental methane releases and evaluate the progress of states in replacing cast-iron pipelines. The impact of any such regulatory actions on ONEOK Partners’ facilities and operations is unknown. ONEOK Partners continues to monitor these developments and the impact they may have on its businesses. Revised or additional statutes or regulations that result in increased compliance costs or additional operating restrictions could have a significant impact on our business, financial position, results of operations and cash flows.

ONEOK Partners’ expenditures for environmental assessment, mitigation, remediation and compliance to date have not been significant in relation to our financial position, results of operations or cash flows, and its expenditures related to environmental matters have had no material effects on earnings or cash flows during the three and nine months ended September 30, 2015 and 2014.

In April 2014, the EPA and the United States Army Corps of Engineers proposed a joint rule-making to redefine the definition of “Waters of the United States” under the Clean Water Act. The final rule was published on June 29, 2015, and became effective on August 28, 2015. The final rule is not expected to result in material impacts on ONEOK Partners’ projects, facilities and operations.

The EPA’s “Triggering and Tailoring Rules” regulate GHG emissions at new or modified facilities that meet certain criteria. Affected facilities are required to review best available control technology (BACT), conduct air-quality analysis, impact analysis and public reviews with respect to such emissions. At current emission threshold levels, this rule has had a minimal impact on ONEOK Partners’ existing facilities. In addition, on June 23, 2014, the Supreme Court of the United States (Supreme Court), in a case styled, Utility Air Regulatory Group v. EPA, 530 U.S. (2014), held that an industrial facility’s potential to emit GHG emissions alone cannot subject a facility to the permitting requirements for major stationary source provisions of the Clean Air Act. The decision invalidated the EPA’s current Triggering and Tailoring Rule for GHG Prevention of Significant Deterioration (PSD) and Title V requirements as applied to facilities considered major sources only for GHGs (referred to as Step 2 sources). However, the Supreme Court also ruled that to the extent a source pursues a capital project (new construction or expansion of existing facility), which otherwise subjects the source to major source PSD permitting for conventional criteria pollutants, the permitting authorities may impose BACT analysis and emission limits for GHGs from those sources.

In April 2015, the United States Court of Appeals for the District of Columbia Circuit (D.C. Circuit), on remand from the Supreme Court, issued its further Order following the Supreme Court’s decision in Utility Air Regulatory Group v. EPA. The D.C. Circuit’s Order included the following: (1) it formally vacated EPA regulations implementing the Tailoring Rule to the extent that they require a stationary source to obtain a PSD or Title V permit based solely on the source’s GHG emissions; and (2) ordered the EPA to consider whether any further revisions to its regulations are appropriate in light of the Supreme Court’s decision.On April 30, 2015, the EPA issued a direct final rule to allow for the rescission of Clean Air Act PSD permits issued by the EPA or delegated state and local permitting authorities under Step 2 of the GHG Tailoring Rule. The direct final rule was to become effective unless adverse comments were received by the EPA. On August 19, 2015, the EPA published the direct final rule in the Federal Register to confirm that no adverse comments were received and that the rule was now in effect.

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We do not expect the direct final rule to have a material impact on ONEOK Partners’ existing operations or design decisions for new project applications.

In July 2011, the EPA issued a proposed rule that would change the air emissions New Source Performance Standards, also known as NSPS, and Maximum Achievable Control Technology requirements applicable to the oil and natural gas industry, including natural gas production, processing, transmission and underground storage sectors. In April 2012, the EPA released the final rule, which includes new NSPS and air toxic standards for a variety of sources within natural gas processing plants, oil and natural gas production facilities and natural gas transmission stations. The rule also regulates emissions from the hydraulic fracturing of wells for the first time. The NSPS final rule became effective in October 2012, but the dates for compliance vary and depend in part upon the type of affected facility and the date of construction, reconstruction or modification.

In September 2015, the EPA published several proposed rule-makings in the Federal Register that affect the oil and gas industry. The rule-makings included, but were not limited to, proposed amendments to the NSPS rule. The proposed amendments to the NSPS rule included, in part, the proposed direct regulation of methane emissions for the first time as an individual air pollutant from oil and gas sources, as part of the President’s Methane Strategy. Comments on the proposed rule-makings remain ongoing.

In October 2015, the EPA issued a prepublication version of a final rule-making to amend downward the National Ambient Air Quality Standards (NAAQS) for ground level ozone. The final rule requires revised designations of the areas in the various states for classification as in attainment or nonattainment for the new ozone NAAQS. Any areas determined to not attain the ozone NAAQS will implicate more strict air permitting requirements for new or modified sources that emit pollutants that contribute to ground level ozone.

At this time we do not anticipate a material impact to ONEOK Partners’ planned capital, operations and maintenance costs resulting from compliance with the current or pending regulations outlined above. However, the EPA may issue additional responses, amendments and/or policy guidance on the final rules, which could alter our present expectations. Generally, the EPA rule-makings will require expenditures for updated emissions controls, monitoring and record-keeping requirements at affected facilities. We do not expect these expenditures will have a material impact on our results of operations, financial position or cash flows.

Pipeline Safety - ONEOK Partners is subject to PHMSA regulations, including pipeline asset integrity-management regulations. The Pipeline Safety Improvement Act of 2002 requires pipeline companies operating high-pressure pipelines to perform integrity assessments on pipeline segments that pass through densely populated areas or near specifically designated high-consequence areas. In January 2012, The Pipeline Safety, Regulatory Certainty and Job Creation Act of 2011 was signed into law. The law increased maximum penalties for violating federal pipeline safety regulations and directs the DOT and Secretary of Transportation to conduct further review or studies on issues that may or may not be material to ONEOK Partners. These issues include, but are not limited to, the following:

• an evaluation on whether hazardous natural gas liquids and natural gas pipeline integrity-management requirements should be expanded beyond current high-consequence areas;

• a review of all natural gas and hazardous natural gas liquids gathering pipeline exemptions;

• a verification of records for pipelines in Class 3 and 4 locations and high-consequence areas to confirm maximum allowable operating pressures; and

• a requirement to test previously untested pipelines operating above 30 percent yield strength in high-consequence areas.

In October 2015, PHMSA issued a notice of proposed rule-making to its hazardous liquid pipeline safety regulations.  Among other things, the proposed regulations would expand the current leak-detection requirements, apply new, more conservative repair criteria and establish timelines for inspecting pipeline facilities potentially affected by an extreme weather event or natural disaster.  The proposal would also increase the stringency of integrity management program requirements and set deadlines for the use of internal inspection tools on certain systems.  Comments on the proposed rule-making are currently due by January 2016.  The potential capital and operating expenditures related to the referenced legislation and regulations are unknown, but we do not anticipate a material impact to ONEOK Partners’ planned capital, operations and maintenance costs resulting from compliance with the current or pending regulations.

Legal Proceedings - Gas Index Pricing Litigation - As previously reported, ONEOK and its subsidiary, ONEOK Energy Services Company, L.P. (OESC), along with several other energy companies, are defending multiple lawsuits arising from alleged market manipulation or false reporting of natural gas prices to natural gas-index publications alleged to have occurred prior to 2003. On April 10, 2013, the United States Court of Appeals for the Ninth Circuit reversed the summary judgments that had been granted in favor of ONEOK, OESC and other unaffiliated defendants in the following cases: Reorganized FLI,

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Learjet, Arandell, Heartland and NewPage. The Ninth Circuit also reversed the summary judgment that had been granted in favor of OESC on all state law claims asserted in the Sinclair case. On April 21, 2015, the United States Supreme Court affirmed the decision of the Ninth Circuit. The cases have now been remanded back to the trial court (the United States District Court for the District of Nevada) for further proceedings.

Because of the uncertainty surrounding the Gas Index Pricing Litigation, including an insufficient description of the purported classes and other related matters, we cannot reasonably estimate a range of potential exposures at this time. However, it is reasonably possible that the ultimate resolution of these matters could result in future charges that may be material to our results of operations.

Other Legal Proceedings - We and ONEOK Partners are party to various other litigation matters and claims that have arisen in the normal course of our operations. While the results of these various other litigation matters and claims cannot be predicted with certainty, we believe the reasonably possible losses from such matters, individually and in the aggregate, are not material. Additionally, we believe the probable final outcome of such matters will not have a material adverse effect on our consolidated results of operations, financial position or cash flows.

O. SEGMENTS

Segment Descriptions - Our reportable business segments are based upon the following segments of ONEOK Partners:

• the Natural Gas Gathering and Processing segment gathers, treats and processes natural gas;

• the Natural Gas Liquids segment gathers, treats, fractionates and transports NGLs and stores, markets and distributes NGL products; and

• the Natural Gas Pipelines segment operates regulated interstate and intrastate natural gas transmission pipelines and natural gas storage facilities.

Other and eliminations consist of the operating and leasing operations of our headquarters building and related parking facility and other amounts needed to reconcile our reportable segments to our consolidated financial statements.

Accounting Policies - We evaluate performance based principally on each segment’s operating income and equity earnings. The accounting policies of the segments are described in Note A of the Notes to Consolidated Financial Statements in our Annual Report. Intersegment and affiliate sales are recorded on the same basis as sales to unaffiliated customers and are discussed further in Note M. Net margin is comprised of total revenues less cost of sales and fuel. Cost of sales and fuel includes commodity purchases, fuel, storage and transportation costs. Revenues from sales and services provided by ONEOK Partners to our former natural gas distribution business prior to the separation and to our former energy services business prior to the completion of the wind down, which were previously eliminated in consolidation, are now reported as sales to affiliated customers for the nine months ended September 30, 2014, and are no longer eliminated in consolidation. Revenues from sales and services provided by ONEOK Partners to our former natural gas distribution business after the separation are reported as sales to unaffiliated customers as these now represent third-party transactions.

Customers - The primary customers of the Natural Gas Gathering and Processing segment are major and independent crude oil and natural gas production companies. The Natural Gas Liquids segment’s customers are primarily NGL and natural gas gathering and processing companies, major and independent crude oil and natural gas production companies, propane distributors, ethanol producers and petrochemical, refining and NGL marketing companies. The Natural Gas Pipelines segment’s customers include natural gas distribution, electric-generation, natural gas marketing, industrial and major and independent crude oil and natural gas production companies.

For the three and nine months ended September 30, 2015 and 2014, ONEOK Partners had no single customer from which it received 10 percent or more of consolidated revenues.

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Operating Segment Information - The following tables set forth certain selected financial information for our operating segments for the periods indicated:

Three Months Ended September 30, 2015	Natural Gas Gathering and Processing		Natural Gas Liquids (a)			Natural Gas Pipelines (b)			Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	294,948	$	1,522,224		$	81,246		$	528		$	1,898,946
Intersegment revenues	139,388		89,230			1,751			(230,369		)	—
Total revenues	$	434,336	$	1,611,454		$	82,997		$	(229,841	)	$	1,898,946
Net margin	$	140,655	$	321,772		$	75,369		$	341		$	538,137
Operating costs	61,162		74,464			26,674			1,877			164,177
Depreciation and amortization	37,286		39,317			10,914			782			88,299
Gain (loss) on sale of assets	132		(498		)	(77		)	(283		)	(726		)
Operating income	$	42,339	$	207,493		$	37,704		$	(2,601	)	$	284,935
Equity in net earnings from investments	$	4,350	$	10,912		$	16,982		$	—		$	32,244
Capital expenditures	$	231,835	$	52,807		$	14,718		$	1,508		$	300,868

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $252.8 million, of which $204.7 million was related to sales within the segment, net margin of $140.1 million and operating income of $80.3 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $65.1 million, net margin of $57.9 million and operating income of $24.7 million.

Three Months Ended September 30, 2014	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)		Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	374,403		$	2,667,939		$	77,027	$	776		$	3,120,145
Intersegment revenues	403,399			66,581			2,133		(472,113		)	—
Total revenues	$	777,802		$	2,734,520		$	79,160	$	(471,337	)	$	3,120,145
Net margin	$	178,171		$	282,963		$	73,399	$	2,408		$	536,941
Operating costs	64,279			76,946			27,998		3,272			172,495
Depreciation and amortization	31,327			31,661			10,913		687			74,588
Gain (loss) on sale of assets	324			(535		)	1,746		(1		)	1,534
Operating income	$	82,889		$	173,821		$	36,234	$	(1,552	)	$	291,392
Equity in net earnings (loss) from investments	$	(71,069	)	$	4,351		$	14,371	$	—		$	(52,347	)
Capital expenditures	$	214,917		$	153,785		$	10,650	$	2,833		$	382,185

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $190.3 million, of which $170.1 million related to sales within the segment, net margin of $94.3 million and operating income of $46.4 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $65.2 million, net margin of $57.4 million and operating income of $23.4 million.

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Nine Months Ended September 30, 2015	Natural Gas Gathering and Processing		Natural Gas Liquids (a)			Natural Gas Pipelines (b)			Other and Eliminations (c)			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	862,462	$	4,726,617		$	241,605		$	1,620		$	5,832,304
Intersegment revenues	487,559		229,804			5,053			(722,416		)	—
Total revenues	$	1,350,021	$	4,956,421		$	246,658		$	(720,796	)	$	5,832,304
Net margin	$	402,482	$	902,382		$	218,599		$	1,075		$	1,524,538
Operating costs	193,922		234,120			79,156			1,347			508,545
Depreciation and amortization	109,035		118,044			32,484			1,678			261,241
Gain (loss) on sale of assets	328		(579		)	(76		)	(283		)	(610		)
Operating income	$	99,853	$	549,639		$	106,883		$	(2,233	)	$	754,142
Equity in net earnings from investments	$	13,511	$	27,585		$	52,109		$	—		$	93,205
Investments in unconsolidated affiliates	$	253,548	$	484,403		$	399,108		$	—		$	1,137,059
Total assets	$	5,206,987	$	8,041,064		$	1,837,776		$	422,471		$	15,508,298
Noncontrolling interests in consolidated subsidiaries	$	4,066	$	161,210		$	—		$	3,457,557		$	3,622,833
Capital expenditures	$	692,570	$	185,360		$	39,923		$	12,463		$	930,316

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $690.1 million, of which $556.4 million was related to sales within the segment, net margin of $392.7 million and operating income of $218.8 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $198.5 million, net margin of $175.9 million and operating income of $77.8 million.

(c) - Other and Eliminations includes assets of discontinued operations of $20.5 million.

Nine Months Ended September 30, 2014	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)		Other and Eliminations (c)			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	1,095,531		$	7,950,930		$	247,420	$	2,916		$	9,296,797
Sales to affiliated customers	41,214			—			12,312		—			53,526
Intersegment revenues	1,126,547			160,712			6,206		(1,293,465		)	—
Total revenues	$	2,263,292		$	8,111,642		$	265,938	$	(1,290,549	)	$	9,350,323
Net margin	$	486,695		$	818,086		$	242,359	$	(4,092	)	$	1,543,048
Operating costs	188,489			218,129			82,747		4,263			493,628
Depreciation and amortization	89,612			89,848			32,623		2,046			214,129
Gain (loss) on sale of assets	277			(572		)	1,663		165			1,533
Operating income	$	208,871		$	509,537		$	128,652	$	(10,236	)	$	836,824
Equity in net earnings (loss) from investments	$	(60,484	)	$	13,574		$	53,657	$	—		$	6,747
Investments in unconsolidated affiliates	$	253,930		$	484,238		$	390,341	$	—		$	1,128,509
Total assets	$	4,415,814		$	7,337,688		$	1,832,368	$	726,326		$	14,312,196
Noncontrolling interests in consolidated subsidiaries	$	4,394		$	—		$	—	$	3,131,769		$	3,136,163
Capital expenditures	$	506,016		$	637,524		$	25,987	$	34,859		$	1,204,386

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $479.4 million, of which $417.0 million related to sales within the segment, net margin of $263.4 million and operating income of $126.0 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $214.8 million, net margin of $185.5 million and operating income of $84.6 million.

(c) - Other and Eliminations includes assets and capital expenditures of discontinued operations of $84.2 million and $23.9 million, respectively.

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion and analysis should be read in conjunction with our unaudited consolidated financial statements and the Notes to Consolidated Financial Statements in this Quarterly Report, as well as our Annual Report.

RECENT DEVELOPMENTS

Ownership of ONEOK Partners - ONEOK and its subsidiaries own all of the general partner interest and a portion of the limited partner interests, which, together, represent a 41.2 percent ownership interest at September 30, 2015, in ONEOK Partners (NYSE: OKS), one of the largest publicly traded master limited partnerships.

Market Conditions - Due in part to the rapid growth in crude oil production in the United States through 2014, the global supply of crude oil exceeded demand and led to a dramatic fall in crude oil prices in the fourth quarter 2014. Lower prices continued into 2015. The production growth and decline in crude oil prices have also contributed to lower NGL product prices, as well as narrow NGL product price differentials. Similarly, the rapid growth in domestic natural gas production has led to a decline in natural gas prices. This weakened commodity price environment, which is due to factors beyond our control, is creating challenges for ONEOK Partners’ crude oil and natural gas producer customers and has resulted in decreased drilling activity in the first nine months of 2015, compared with the same period in 2014. Despite the decrease in overall drilling activity, producers are focusing their drilling in high-return areas and are using more efficient drilling and completion techniques that are contributing to an increase in natural gas and NGL volumes, particularly in the Williston and Permian Basins. The energy industry has periodically experienced similar down cycles in the past. We expect this lower commodity price environment to continue through the remainder of 2015, with a modest recovery in 2016, which will impact ONEOK Partners’ net realized prices for natural gas, NGLs and condensate, as well as our financial results.

As a result of lower commodity prices, crude oil and natural gas producers have significantly decreased their capital investments, which, combined with production declines, has begun to slow natural gas and NGL supply growth. Lower commodity prices and slower volume growth have significantly impacted our 2015 results of operations and cash flows, particularly in the Natural Gas Gathering and Processing segment where revenues have been historically derived from primarily POP commodity-based contracts with fee components. Many contracts in the Natural Gas Gathering and Processing and Natural Gas Liquids segments include fixed fee, minimum volume or firm demand charge agreements that ensure a minimum level of revenues regardless of commodity prices. Additionally, ONEOK Partners has renegotiated many Natural Gas Gathering and Processing segment contracts to significantly increase its fee-based earnings and continues to actively work with its producer customers to similarly restructure additional contracts. ONEOK Partners expects to substantially complete its negotiations on Williston Basin contracts in 2015 and receive the full benefit of the improved margins in 2016.

We also expect relatively narrow NGL location price differentials to continue, with periods of volatility for certain NGL products, between the Conway, Kansas, and Mont Belvieu, Texas, market centers. We expect this to persist as NGL production continues to increase and new fractionators and pipelines from various NGL-rich shale areas throughout the country, including ONEOK Partners’ growth projects discussed below, alleviate constraints affecting NGL prices and location price differentials between the two market centers.

Supply growth has resulted in available ethane supplies that are greater than the petrochemical industry’s current demand. As a result, low or unprofitable price differentials between ethane and natural gas have resulted in ethane rejection at most of ONEOK Partners’ and its customers’ natural gas processing plants connected to its natural gas liquids gathering system in the Mid-Continent, Permian and Rocky Mountain regions during 2014 and the first nine months of 2015. Through ethane rejection, natural gas processors leave much of the ethane component in the natural gas stream sold at the tailgate of natural gas processing plants. We expect ethane rejection to persist at current levels until ethylene producers increase their capacity to consume additional ethane feedstock volumes through plant modifications, plant expansions and the completion of announced new world-scale ethylene production projects beginning in 2017. Ethane rejection is expected to continue to have a significant impact on our financial results through 2017. However, beginning in June 2015, the Natural Gas Gathering and Processing segment reduced its level of ethane rejection in the Rocky Mountain region to alleviate downstream NGL product specification issues, which offsets partially this financial impact. We expect this decreased ethane rejection to continue into 2016. In addition, the Natural Gas Liquids segment’s integrated assets enable ONEOK Partners to mitigate partially the impact of ethane rejection through minimum volume commitments, contract modifications that vary fees for ethane and other NGL products, and ONEOK Partners’ ability to utilize the transportation capacity made available due to ethane rejection to capture additional NGL location price differentials, when they exist, in its optimization activities. See additional discussion in the “Financial Results and Operating Information” section.

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Commodity Prices - Sharp declines in commodity prices negatively affected our financial results for the three and nine months ended September 30, 2015, compared with the same periods in 2014. WTI crude oil prices declined to below $50.00 per barrel in the first nine months of 2015, compared with prices averaging approximately $100.00 in the first nine months of 2014. NYMEX natural gas prices also declined to less than $3.00 per MMBtu in the first nine months of 2015, compared with prices averaging approximately $4.50 per MMBtu in the first nine months of 2014. OPIS Conway propane prices averaged less than $0.50 per gallon in the first nine months of 2015, compared with prices averaging more than $1.00 per gallon in the first nine months of 2014. We expect lower commodity prices to persist throughout the remainder of 2015, with a modest recovery in 2016.

ONEOK Partners experienced significantly higher prices in the first quarter 2014 due to severely cold weather, compared with the first quarter 2015. In response to increased heating demand, propane prices increased significantly at the Mid-Continent market center at Conway, Kansas, compared with the Gulf Coast market center at Mont Belvieu, Texas, in the first quarter 2014. The price of propane in the Mid-Continent market and the wider location price differentials between the Mid-Continent and Gulf Coast market centers peaked in late January 2014 and returned to historical levels by the end of February 2014 as supply and demand balanced.

Financial Outlook - ONEOK Partners has substantial fee-based businesses in the Natural Gas Liquids and Natural Gas Pipelines segments. However, our results of operations, primarily in the Natural Gas Gathering and Processing segment, are impacted significantly by the commodity price environment. To mitigate partially the impact of lower commodities prices, ONEOK Partners has hedged a significant portion of the Natural Gas Gathering and Processing segment’s equity volumes for the remainder of 2015 and in 2016. Also, many contracts in the Natural Gas Gathering and Processing and Natural Gas Liquids segments include fixed fee, minimum volume or firm demand charge agreements that ensure a minimum level of revenues regardless of commodity prices or volumetric throughput. ONEOK Partners continues to seek opportunities to increase the fee-based component in its POP contracts. ONEOK Partners expects to renegotiate contracts associated with a significant amount of its gathered volume in the Williston Basin by the end of 2015. We expect these contracts to favorably impact ONEOK Partners’ fourth quarter 2015 and full year 2016 financial results. The Natural Gas Pipelines segment also provides primarily fee-based firm natural gas transportation and storage services primarily to natural gas and electric utilities.

Despite the decline in commodity prices, we expect the growth of ONEOK Partners’ operations to continue, which we expect to favorably impact our financial results in the fourth quarter 2015, compared with the first nine months of 2015, due to a number of factors. ONEOK Partners completed a significant number of capital-growth projects in 2014 that we expect will continue to increase volumes in the Natural Gas Gathering and Processing and Natural Gas Liquids segments in the fourth quarter 2015. ONEOK Partners is also constructing additional natural gas gathering pipelines, compression and processing plants, and natural gas liquids pipeline capacity in the Rocky Mountain region that are expected to help alleviate current capacity constraints primarily existing in the Williston Basin. In the Williston Basin, we expect ONEOK Partners to capture a substantial amount of natural gas currently being flared by producers, production from wells that have been drilled but not yet completed or connected to its system, and production from new wells that are expected to be drilled. We expect additional volume from new wells focused in high-return areas of the basin, which remain economical even at current prices and typically produce at higher initial production rates compared with other areas. We also expect additional wells to be completed and connected to ONEOK Partners’ system in the Mid-Continent region. We expect supply growth to continue in 2016 and 2017, although not as rapidly as the growth experienced in 2014. We also expect ONEOK Partners’ fee-based business to continue to increase as it completes its capital-growth projects and completes additional contract renegotiations.

ONEOK Partners’ Growth Projects - Through the first nine months of 2015, crude oil and natural gas producers continued to drill for crude oil and NGL-rich natural gas in many regions where ONEOK Partners has operations, including in the Bakken Shale and Three Forks formations in the Williston Basin; in the Powder River Basin; in the Cana-Woodford Shale, Woodford Shale, Springer Shale, Stack and SCOOP areas in the Mid-Continent region and in the Permian Basin. In response to this continued production of crude oil, natural gas and NGLs, and higher demand for NGL products from the petrochemical industry, ONEOK Partners has completed growth projects and acquisitions and also has projects in various stages of construction to meet the needs of crude oil and natural gas producers and processors in these regions. In addition, ONEOK Partners’ projects are expected to enhance its natural gas liquids fractionation, distribution and storage infrastructure in the Gulf Coast region and expand its natural gas pipeline services in the Permian Basin. The execution of these capital investments aligns with ONEOK Partners’ strategy to generate consistent growth and sustainable earnings. ONEOK Partners’ contractual commitments from crude oil and natural gas producers, natural gas processors and electric generators in regions associated with its growth projects are expected to provide incremental cash flows and long-term fee-based earnings.

While reduced crude oil and natural gas producer drilling activity is slowing supply growth, we expect ONEOK Partners to complete its previously announced projects to meet crude oil and natural gas producers’ demand for its gathering, processing, fractionation and transportation services. However, ONEOK Partners has suspended capital expenditures for certain natural

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gas processing plants and related infrastructure to align with the needs of its customers. We expect ONEOK Partners to resume its suspended capital-growth projects as soon as market conditions improve. If the current commodity price environment persists for a prolonged period, it may further impact the timing or demand for additional ONEOK Partners infrastructure projects or growth opportunities in the future.

WesTex Transmission Pipeline Expansion - In July 2015, ONEOK Partners announced plans to invest $70 million to $100 million to expand its ONEOK WesTex Transmission (WesTex) intrastate natural gas pipeline system in the Permian Basin in the Natural Gas Pipelines segment. WesTex, which had qualifying open season bids in excess of 500 MMcf/d, plans to utilize 240 MMcf/d of existing capacity and create additional capacity by expanding its system by 260 MMcf/d by the first quarter 2017. This expansion project is supported by firm demand charge transportation agreements and is complementary to ONEOK Partners’ recently announced Roadrunner Gas Transmission (Roadrunner) joint venture pipeline project discussed below.

See additional discussion of ONEOK Partners’ other growth projects in the “Financial Results and Operating Information” section in the Natural Gas Gathering and Processing and Natural Gas Liquids segments.

Roadrunner - In March 2015, ONEOK Partners entered into a 50-50 joint venture with a subsidiary of Fermaca, a Mexico City-based natural gas infrastructure company, to construct a pipeline to transport natural gas from the Permian Basin in West Texas to the Mexican border near El Paso, Texas. The pipeline will connect with ONEOK Partners’ existing natural gas pipeline and storage infrastructure in Texas and is expected to create a platform for future cross-border development opportunities. These integrated assets are also expected to provide markets in Mexico access to upstream supply basins in West Texas and the Mid-Continent region, which adds location and price diversity to their supply mix and supports the plan of Mexico’s national electric utility, Comisión Federal de Electricidad, to replace fuel oil-based power plants with natural gas-fueled power plants, which are more economical and produce fewer GHG emissions. The estimated total cost of the project is approximately $450 million to $500 million. ONEOK Partners contributed approximately $30 million to Roadrunner in the nine months ended September 30, 2015, and does not expect to make any further contributions in 2015. ONEOK Partners expects to contribute approximately $65 million to Roadrunner during 2016. The FERC approved Roadrunner’s request for a Presidential Permit and authorization in October 2015, and construction has commenced.

Roadrunner entered into a $230 million senior secured credit facility for the construction and operation of the pipeline. The senior secured credit facility expires 7 years after the Roadrunner in-service date of Phase II, which is expected to be completed in the first quarter 2017. In addition, Roadrunner executed interest-rate swaps to hedge the variability of its interest payments during the term of the credit facility.

See additional discussion in the “Financial Results and Operating Information” section in the Natural Gas Pipelines segment.

Dividends/Distributions - We declared a quarterly dividend of $0.615 per share ($2.46 per share on an annualized basis) in October 2015. ONEOK Partners declared a cash distribution of $0.79 per unit ($3.16 per unit on an annualized basis) in October 2015 for the third quarter 2015. The quarterly dividend and distribution will be paid November 13, 2015, to shareholders and unitholders of record at the close of business on November 2, 2015.

ONEOK Debt Issuance - In August 2015, we completed an underwritten public offering of $500 million of senior notes, 7.5 percent senior notes due 2023. The net proceeds, after deducting underwriting discounts, commissions and other expenses, were approximately $487.1 million. We used the proceeds together with cash on hand to purchase $650 million of additional common units from ONEOK Partners.

ONEOK Partners Debt Issuance - In March 2015, ONEOK Partners completed an underwritten public offering of $800 million of senior notes, generating net proceeds of approximately $792.3 million. ONEOK Partners used the proceeds to repay amounts outstanding under its commercial paper program and for general partnership purposes.

ONEOK Partners Equity Issuances - In August 2015, ONEOK Partners completed a private placement of approximately 21.5 million common units at a price of $30.17 per unit with us. Additionally, ONEOK Partners completed a concurrent sale of approximately 3.3 million common units at a price of $30.17 per unit to funds managed by Kayne Anderson Capital Advisors in a registered direct offering. The combined offerings generated net cash proceeds of approximately $749 million to ONEOK Partners. In conjunction with these issuances, ONEOK Partners GP contributed approximately $15.3 million in order to maintain our 2 percent general partner interest in ONEOK Partners. ONEOK Partners used the proceeds for general partnership purposes, including capital expenditures and repayment of commercial paper borrowings.

During the nine months ended September 30, 2015, ONEOK Partners sold approximately 10.5 million common units through its “at-the-market” equity program, which includes the units sold to funds managed by Kayne Anderson Capital Advisors in the

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registered direct offering discussed above. The net proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, were approximately $381.6 million, which were used for general partnership purposes, including repayment of commercial paper borrowings.

Goodwill Impairment Test - We assess our goodwill for impairment at least annually on July 1, unless events or changes in circumstances indicate an impairment may have occurred before that time.  While there have been sharp declines in commodity prices over the past year, ONEOK Partners is responding to the low commodity price environment by suspending certain capital-growth projects, aligning operating costs with the needs of its crude oil and natural gas producer customers, utilizing hedging to partially mitigate the low commodity prices and actively working to increase the fee-based component in the POP contracts in the Natural Gas Gathering and Processing segment, which is the segment with the most commodity price exposure.  Each reporting period, we assess these qualitative factors to determine whether it is more likely than not that the fair value of each of the reporting units is less than its carrying amount.  At July 1, 2015, we assessed qualitative factors to determine whether it was more likely than not that the fair value of each of the reporting units was less than its carrying amount. Due to the current commodity price environment, we elected to perform a quantitative assessment, or Step 1 analysis, to test our goodwill for impairment.  The assessment included the current commodity price assumptions, expected contractual terms, anticipated operating costs and volume estimates.  Our goodwill impairment analysis performed as of July 1, 2015, did not result in an impairment charge nor did our analysis reflect any reporting units at risk.  In each reporting unit, the fair value substantially exceeded its carrying value. Subsequent to that date, no event has occurred indicating that the implied fair value of each of the reporting units is less than the carrying value of its net assets.

FINANCIAL RESULTS AND OPERATING INFORMATION

Consolidated Operations

Selected Financial Results - The following table sets forth certain selected financial results for the periods indicated:

	Three Months Ended						Nine Months Ended						Three Months					Nine Months
	September 30,						September 30,						2015 vs. 2014					2015 vs. 2014
Financial Results	2015			2014			2015			2014			Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
Revenues
Commodity sales	$	1,484.3		$	2,754.5		$	4,642.3		$	8,276.3		$	(1,270.2	)	(46	%)	$	(3,634.0	)	(44	%)
Services	414.6			365.6			1,190.0			1,074.0			49.0			13	%	116.0			11	%
Total revenues	1,898.9			3,120.1			5,832.3			9,350.3			(1,221.2		)	(39	%)	(3,518.0		)	(38	%)
Cost of sales and fuel	1,360.8			2,583.2			4,307.8			7,807.3			(1,222.4		)	(47	%)	(3,499.5		)	(45	%)
Net margin	538.1			536.9			1,524.5			1,543.0			1.2			—	%	(18.5		)	(1	%)
Operating costs	164.2			172.4			508.6			493.6			(8.2		)	(5	%)	15.0			3	%
Depreciation and amortization	88.3			74.6			261.2			214.1			13.7			18	%	47.1			22	%
Gain (loss) on sale of assets	(0.7		)	1.5			(0.6		)	1.5			(2.2		)	*		(2.1		)	*
Operating income	$	284.9		$	291.4		$	754.1		$	836.8		$	(6.5	)	(2	%)	$	(82.7	)	(10	%)
Equity in net earnings (loss) from investments	$	32.2		$	(52.3	)	$	93.2		$	6.7		$	84.5		*		$	86.5		*
Interest expense	$	(106.9	)	$	(86.1	)	$	(306.1	)	$	(269.7	)	$	20.8		24	%	$	36.4		13	%
Income from continuing operations	$	164.7		$	114.5		$	411.6		$	467.9		$	50.2		44	%	$	(56.3	)	(12	)%
Net income attributable to noncontrolling interests	$	78.7		$	49.8		$	187.9		$	242.0		$	28.9		58	%	$	(54.1	)	(22	)%
Net income attributable to ONEOK	$	82.2		$	64.5		$	219.5		$	219.6		$	17.7		27	%	$	(0.1	)	—	%
Capital expenditures (a)	$	300.9		$	382.2		$	930.3		$	1,204.4		$	(81.3	)	(21	)%	$	(274.1	)	(23	)%

* Percentage change is greater than 100 percent.

(a) - Includes capital expenditures of discontinued operations of $23.9 million for the nine months ended September 30, 2014.

Commodity sales revenues and costs of sales and fuel decreased for the three and nine months ended September 30, 2015, compared with the same periods in 2014, due to higher propane and natural gas prices as well as wider NGL location and product price differentials experienced in the first quarter 2014 as a result of unusually high weather-related seasonal demand and a sharp decline in commodity prices that began in the fourth quarter 2014 and continued into 2015. The impact from the price decrease was offset partially by higher gathered and processed volumes and an improved contract mix in the Natural Gas

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Gathering and Processing segment and higher NGL volumes transported on gathering lines and fractionated in the Natural Gas Liquids segment for the three and nine months ended September 30, 2015, compared with the same periods in 2014.

Services revenues increased for the three and nine months ended September 30, 2015, compared with the same periods in 2014, due to higher natural gas and NGL volumes from ONEOK Partners’ recently completed capital projects, including acquisitions, in the Natural Gas Gathering and Processing and Natural Gas Liquids segments and higher fees resulting from contract restructuring efforts in our Natural Gas Gathering and Processing segment.

Operating costs decreased for the three months ended September 30, 2015, compared with the same period in 2014, due primarily to higher scheduled maintenance and chemicals costs in the prior year, offset partially by increased employee costs from the growth of ONEOK Partners’ operations related to its completed capital projects and acquisitions. Operating costs increased for the nine months ended September 30, 2015, compared with the same period in 2014, due primarily to increased employee costs from the growth of ONEOK Partners’ operations related to its completed capital projects and acquisitions.

Depreciation and amortization expense increased for the three and nine months ended September 30, 2015, compared with the same periods in 2014, due primarily to the growth of ONEOK Partners’ operations related to its completed capital projects and acquisitions.

Equity in net earnings from investments increased for the three and nine months ended September 30, 2015, compared with the same periods in 2014, due to an impairment charge in September 2014 of $76.4 million related to ONEOK Partners’ equity method investment in Bighorn Gas Gathering in the Natural Gas Gathering and Processing segment and due to higher volumes in 2015 delivered to Overland Pass Pipeline from ONEOK Partners’ Bakken NGL Pipeline in the Natural Gas Liquids segment.

Interest expense increased for the three and nine months ended September 30, 2015, compared with the same periods in 2014, due primarily to higher short-term borrowings and rates, lower capitalized interest due to capital-growth projects completed and placed in service in 2014, and interest costs for ONEOK Partners due to an $800 million debt issuance in March 2015. Additionally, our interest expense increased for the three months ended September 30, 2015, compared with the same period in 2014, due to interest costs on our $500 million debt issuance in August 2015. This increase was offset partially for the nine months ended September 30, 2015, by write-offs in the first quarter 2014 of approximately $7.7 million due to the discontinuance of cash flow hedge treatment for interest-rate swaps related to early retirement of long-term debt, $2.9 million related to write-offs of previously deferred credit agreement issuance costs as a result of reducing the borrowing capacity of the credit agreement, and decreased interest expense from the early retirement of approximately $553 million of ONEOK’s long-term debt in the first quarter 2014.

Income from continuing operations decreased for the nine months ended September 30, 2015, compared with the same period in 2014, due primarily to the factors discussed above and a $26.4 million net reduction in deferred income tax expense in the first quarter 2014 as a result of the separation of our former natural gas distribution business and the wind down of the energy services business.

Net income attributable to noncontrolling interests, which reflects primarily the portion of ONEOK Partners that we do not own, increased for the three months ended September 30, 2015, compared with the same period in 2014 primarily due to a $76.4 million impairment charge in the third quarter 2014 on ONEOK Partners’ investment in Bighorn Gas Gathering. Net income attributable to noncontrolling interests decreased for the nine months ended September 30, 2015, compared with the same period in 2014, due primarily to lower earnings at ONEOK Partners.

Capital expenditures decreased for the three and nine months ended September 30, 2015, compared with the same periods in 2014, due to the completion of several large projects in 2014 and the timing of expenditures for ONEOK Partners’ growth projects. Additionally, the three months ended March 31, 2014, include one month of capital expenditures from our former natural gas distribution business prior to the separation on January 31, 2014.

Additional information regarding our financial results and operating information is provided in the following discussion for each of the segments.

Natural Gas Gathering and Processing

Overview -The Natural Gas Gathering and Processing segment provides nondiscretionary services to crude oil and natural gas producers that include gathering and processing of natural gas produced from crude oil and natural gas wells. Unprocessed natural gas is compressed and gathered through pipelines and transported to processing facilities where volumes are aggregated, treated and processed to remove water vapor, solids and other contaminants, and to extract NGLs in order to

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provide marketable natural gas, commonly referred to as residue natural gas. The residue natural gas, which consists primarily of methane, is compressed and delivered to natural gas pipelines for transportation to end users. When the NGLs are separated from the unprocessed natural gas at the processing plants, the NGLs are typically in the form of a mixed, unfractionated NGL stream that is delivered to natural gas liquids gathering pipelines for transportation to natural gas liquids fractionators.

This segment gathers and processes natural gas in the Mid-Continent region, which includes the NGL-rich Cana-Woodford Shale, Woodford Shale, Stack, SCOOP, Springer Shale and the Mississippian Lime formation of Oklahoma and Kansas, and the Hugoton and Central Kansas Uplift Basins of Kansas. It also gathers and/or processes natural gas in two producing basins in the Rocky Mountain region: the Williston Basin, which spans portions of Montana and North Dakota and includes the oil-producing, NGL-rich Bakken Shale and Three Forks formations; and the Powder River Basin of Wyoming, which includes the NGL-rich Frontier, Turner, Sussex and Niobrara Shale formations. Coal-bed methane, or dry natural gas, in the Powder River Basin does not require processing or NGL extraction in order to be marketable; dry natural gas is gathered, compressed and delivered into a downstream pipeline or marketed for a fee.

Revenues for this segment are derived primarily from POP contracts with fee-based components and fee-based contracts. Under a POP contract with fee-based components, ONEOK Partners charges fees for gathering, treating, compressing and processing the producer’s natural gas, and retains a percentage of the proceeds from the sale of residue natural gas, condensate and/or NGLs. With a fee-based contract, ONEOK Partners is paid a fee for the services it provides, based on volumes gathered, processed, treated and/or compressed. Many of ONEOK Partners’ contracts contain provisions such as a minimum margin or fixed fees that ensures a minimum level of revenues regardless of commodity prices or volumetric throughput.

We expect ONEOK Partners’ capital projects will continue to generate additional revenues, earnings and cash flows as they are completed. ONEOK Partners uses commodity derivative instruments and physical-forward contracts to reduce its near-term sensitivity to fluctuations in the natural gas, crude oil and NGL prices received for its share of volumes. ONEOK Partners has renegotiated many Natural Gas Gathering and Processing segment contracts to significantly increase its fee-based earnings and continues to actively work with its producer customers to similarly restructure additional contracts. ONEOK Partners expects to substantially complete its negotiations on Williston Basin contracts in 2015 and receive the full benefit of the improved margins in 2016. NGLs, natural gas and crude oil commodity price sensitivity in this segment is expected to decrease in 2016 as contracts are renegotiated.

The significant growth in the development of crude oil and NGL-rich natural gas in the Williston Basin has caused natural gas production to exceed the capacity of existing natural gas gathering and processing infrastructure, which results in the flaring of natural gas (the controlled burning of natural gas at the wellhead) by many crude oil and natural gas producers. In July 2014, the North Dakota Industrial Commission (NDIC) approved a policy designed to limit flaring at existing and future crude oil wells in the Williston Basin. The policy establishes crude oil production limits that will take effect if a producer fails to meet requirements to capture natural gas at the wellhead. We continue to actively participate on the Flaring Task Force, which provides recommendations to the NDIC on policies and targets. The NDIC recently passed updated natural gas capture percentages associated timelines. None of these changes are expected to have a material impact on volume. ONEOK Partners is constructing additional natural gas gathering pipelines, compression and processing plants, and natural gas liquids pipeline capacity that are expected to help alleviate capacity constraints. ONEOK Partners has completed three of six compressor stations expected to be constructed in 2015. Together, the six compression stations will add 300 MMcf/d of natural gas gathering capacity to its system in the Williston Basin.

We expect ONEOK Partners’ natural gas gathered and processed volumes to continue to grow in 2016, despite reductions in crude oil and natural gas producer drilling activity. Volumes are expected to increase in the Williston Basin due to the following:

• ONEOK Partners’ opportunity to capture additional natural gas currently being flared by producers as it adds additional natural gas compression and processing capacity on its systems;

• the connection of wells that have been drilled but not yet completed or connected to its systems;

• producers focusing their drilling in high-return areas, in which ONEOK Partners has significant gathering and processing assets, which typically produce at higher initial production rates compared with other areas;

• the use by producers of more efficient rigs, which are capable of drilling faster; and

• continued improvements in production results by producers due to enhanced completion techniques.

In the Mid-Continent region, a large customer drilled wells in the first half of 2015 with well completions beginning in the third quarter 2015 and expected to continue through the fourth quarter 2015. The additional volumes from these new wells are expected to offset the natural declines of existing production in this region.

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Growth Projects - The Natural Gas Gathering and Processing segment is investing in growth projects in NGL-rich areas in the Williston Basin, the Powder River Basin, the Cana-Woodford Shale, the Springer Shale, the Stack and the SCOOP areas that we expect will enable it to meet the growing needs of crude oil and natural gas producers in those areas. Nearly all of the new natural gas production is from horizontally drilled and completed wells in unconventional resource areas. These wells tend to produce volumes at higher initial production rates resulting generally in higher initial decline rates than conventional vertical wells; however, the decline rates flatten out over time. These wells are expected to have long productive lives.

In 2014 and through the third quarter 2015, ONEOK Partners has completed the following projects:

Completed Projects	Location	Capacity	Approximate Costs (a)	Completion Date
			(In millions)
Rocky Mountain Region
Garden Creek II processing plant and infrastructure	Williston Basin	100 MMcf/d	$310	August 2014
Garden Creek III processing plant and infrastructure	Williston Basin	100 MMcf/d	$310	October 2014
Mid-Continent Region
Canadian Valley processing plant and infrastructure	Cana-Woodford Shale	200 MMcf/d	$255	March 2014

(a) - Excludes AFUDC.

ONEOK Partners has the following natural gas processing plants and related infrastructure in various stages of construction:

Projects in Progress	Location	Capacity	Approximate Costs (a)	Expected Completion Date
			(In millions)
Rocky Mountain Region
Sage Creek infrastructure	Powder River Basin	Various	$35	Fourth quarter 2015
Natural gas compression	Williston Basin	100 MMcf/d	$80-$90	Fourth quarter 2015
Lonesome Creek processing plant and infrastructure	Williston Basin	200 MMcf/d	$550-$680	Fourth quarter 2015
Stateline de-ethanizers	Williston Basin	26 MBbl/d	$60-$80	Third quarter 2016
Bear Creek processing plant and infrastructure	Williston Basin	80 MMcf/d	$230-$330	Third quarter 2016
Bronco processing plant and infrastructure	Powder River Basin	50 MMcf/d	$130-$200	Suspended
Demicks Lake processing plant and infrastructure	Williston Basin	200 MMcf/d	$475-$670	Suspended
Mid-Continent Region
Knox processing plant and infrastructure	SCOOP	200 MMcf/d	$240-$470	Suspended
Total			$1,800-$2,555

(a) - Excludes AFUDC.

As a result of reductions in crude oil and natural gas drilling activities by producers due to the decline in crude oil, natural gas and NGL prices and the expectation of continued slower supply growth, ONEOK Partners has suspended capital expenditures for certain natural gas processing plants and field infrastructure. ONEOK Partners is in a position to quickly resume its suspended capital-growth projects as soon as market conditions improve and its customers’ needs change. If the current commodity price environment persists for a prolonged period, it may further impact the timing or demand for these projects and additional infrastructure projects or growth opportunities in the future.

Rocky Mountain Region:

Williston Basin Processing Plants and related projects - ONEOK Partners is constructing natural gas gathering and processing assets in the Williston Basin to meet the growing needs of crude oil and natural gas producers. When its announced projects are completed, it will have natural gas processing capacity of approximately 1.2 Bcf/d in the basin. ONEOK Partners has acreage dedications of approximately 3 million net acres supporting these projects.

Natural Gas Compression - In July 2014, ONEOK Partners announced it will construct additional natural gas compressor stations across its Williston Basin system to take advantage of additional natural gas processing capacity at its Garden Creek and Stateline facilities by a total of 100 MMcf/d.

Lonesome Creek Plant - In November 2013, ONEOK Partners announced it will construct the Lonesome Creek natural gas processing plant and related infrastructure, which will be located in McKenzie County, North Dakota. The plant and infrastructure will help address natural gas gathering and processing constraints in the region.

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Stateline De-ethanizers - In December 2014, ONEOK Partners announced plans to construct de-ethanizers at its Stateline natural gas processing plants, which are located in Williams County, North Dakota. Once completed, the de-ethanizers will remove ethane from the natural gas liquids stream, which we expect to then be sold under a long-term contract to a customer who plans to transport the ethane on a third-party pipeline.

Bear Creek Plant - In September 2014, ONEOK Partners announced it will construct the Bear Creek natural gas processing plant and related infrastructure, which will be located in Dunn County, North Dakota. The plant and infrastructure will help alleviate pipeline inefficiencies in an area challenged by geographical constraints and severe terrain.

Demicks Lake Plant - In July 2014, ONEOK Partners announced the Demicks Lake natural gas processing plant and related infrastructure, which will be located in northeast McKenzie County, North Dakota, to help further address natural gas gathering and processing constraints in the region. The Demicks Lake Plant is currently suspended but can be quickly resumed as market conditions improve.

Powder River Basin - ONEOK Partners has announced natural gas gathering and processing projects in the NGL-rich areas of the Powder River Basin, a region with the potential for significant growth in natural gas and NGL production volumes. ONEOK Partners has acreage dedications of approximately 130,000 net acres supporting these projects.

Sage Creek Infrastructure - ONEOK Partners plans to construct new natural gas gathering infrastructure at its Sage Creek plant to meet the growing production of NGL-rich natural gas in this area. ONEOK Partners has supply contracts providing for long-term acreage dedications from crude oil and natural gas producers in the area supporting this project.

Bronco Plant - In September 2014, ONEOK Partners announced the Bronco natural gas processing plant and related natural gas gathering and natural gas liquids infrastructure in Campbell and Converse counties, Wyoming. The plant was originally announced as a 100 MMcf/d facility, but was reduced to 50 MMcf/d due to slower growth in the current low commodity price environment. The Bronco Plant is currently suspended but can be quickly resumed as market conditions improve.

Mid-Continent Region:

Cana-Woodford Shale, Woodford Shale, Springer Shale, Stack and SCOOP areas - ONEOK Partners has announced natural gas gathering and processing projects to meet the growing production of NGL-rich natural gas in the Cana-Woodford Shale, Woodford Shale, Springer Shale, Stack and SCOOP areas. When ONEOK Partners’ announced projects are completed, its Oklahoma natural gas processing capacity will be approximately 900 MMcf/d. ONEOK Partners has substantial acreage dedications from crude oil and natural gas producers supporting these projects.

Knox Plant - In July 2014, ONEOK Partners announced the Knox natural gas processing plant and related infrastructure, which will be located in Grady and Stephens Counties, Oklahoma. The plant and related infrastructure will gather and process liquids-rich natural gas from the Cana-Woodford Shale and the emerging SCOOP area and will be located in close proximity to ONEOK Partners’ existing natural gas gathering and processing assets and natural gas and natural gas liquids pipelines. The Knox Plant is currently suspended but can be quickly resumed as market conditions improve.

For a discussion of ONEOK Partners’ capital expenditure financing, see “Capital Expenditures” in “Liquidity and Capital Resources.”

Selected Financial Results - The Natural Gas Gathering and Processing segment’s financial results for the three and nine months ended September 30, 2015, reflect the benefits from additional natural gas compression projects completed in 2015; the Garden Creek III natural gas processing plant, which was completed in October 2014; and the Garden Creek II natural gas processing plant, which was completed in August 2014. Additionally, financial results for the nine months ended September 30, 2015, reflect the benefits of the Canadian Valley natural gas processing plant, which was completed in March 2014.

The completion of the natural gas compression projects and Garden Creek II and Garden Creek III natural gas processing plants resulted in increased natural gas volumes gathered and processed in the Williston Basin, and completion of the Canadian Valley natural gas processing plant resulted in increased natural gas volumes gathered in Oklahoma.

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The following table sets forth certain selected financial results for the Natural Gas Gathering and Processing segment for the periods indicated:

	Three Months Ended					Nine Months Ended					Three Months					Nine Months
	September 30,					September 30,					2015 vs. 2014					2015 vs. 2014
Financial Results	2015		2014			2015		2014			Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
NGL sales	$	118.7	$	394.1		$	423.1	$	1,128.8		$	(275.4	)	(70	%)	$	(705.7	)	(63	%)
Condensate sales	12.3		24.5			39.9		82.0			(12.2		)	(50	%)	(42.1		)	(51	%)
Residue natural gas sales	211.2		284.0			635.6		849.4			(72.8		)	(26	%)	(213.8		)	(25	%)
Gathering, compression, dehydration and processing fees and other revenue	92.1		75.2			251.4		203.1			16.9			22	%	48.3			24	%
Cost of sales and fuel	293.6		599.6			947.5		1,776.6			(306.0		)	(51	%)	(829.1		)	(47	%)
Net margin	140.7		178.2			402.5		486.7			(37.5		)	(21	%)	(84.2		)	(17	%)
Operating costs	61.2		64.3			193.9		188.5			(3.1		)	(5	%)	5.4			3	%
Depreciation and amortization	37.3		31.3			109.0		89.6			6.0			19	%	19.4			22	%
Gain (loss) on sale of assets	0.1		0.3			0.3		0.3			(0.2		)	(67	%)	—			—	%
Operating income	$	42.3	$	82.9		$	99.9	$	208.9		$	(40.6	)	(49	%)	$	(109.0	)	(52	%)
Equity in net earnings (loss) from investments	$	4.4	$	(71.1	)	$	13.5	$	(60.5	)	$	75.5		*		$	74.0		*
Capital expenditures	$	231.8	$	214.9		$	692.6	$	506.0		$	16.9		8	%	$	186.6		37	%

* Percentage change is greater than 100 percent.

Commodity prices declined sharply in the fourth quarter 2014 and remained at relatively lower levels throughout the first nine months of 2015. We expect lower commodity prices to persist throughout the remainder of 2015, with a modest recovery in 2016. Therefore, we expect crude oil, natural gas and NGL supply growth to continue to slow. As crude oil and natural gas exploration and production capital investment has decreased due to market conditions, crude oil and natural gas producers are focusing their drilling activities in high-return areas that are most economical to develop and have higher production volumes, which offsets partially the reduction in drilling. The lower commodity price environment is having a significant impact on the Natural Gas Gathering and Processing segment’s financial results in 2015 compared with 2014.

Net margin decreased for the three months ended September 30, 2015, compared with the same period in 2014, primarily as a result of the following:

• a decrease of $53.9 million due primarily to lower net realized NGL, natural gas and condensate prices;

• a decrease of $7.0 million due primarily to unplanned operational outages in the Williston Basin and decreased natural gas processed volumes in the Cana-Woodford Shale, offset partially by natural gas volume growth in the Williston Basin; and

• a decrease of $3.7 million due primarily to decreased ethane rejection to maintain downstream NGL product specifications; offset partially by

• an increase of $27.1 million due primarily to changes in contract mix resulting from higher fee rates.

Net margin decreased for the nine months ended September 30, 2015, compared with the same period in 2014, primarily as a result of the following:

• a decrease of $153.3 million due primarily to lower net realized NGL, natural gas and condensate prices; and

• a decrease of $4.6 million due primarily to decreased ethane rejection to maintain downstream NGL product specifications; offset partially by

• an increase of $47.9 million due primarily to changes in contract mix resulting from higher fee rates; and

• an increase of $25.8 million due primarily to natural gas volume growth in the Williston Basin, offset partially by unplanned operational outages in the Williston Basin and decreased natural gas volumes in the Cana-Woodford Shale.

Operating costs decreased for the three months ended September 30, 2015, compared with the same period in 2014, primarily as a result of the following:

• a decrease of $4.1 million in materials and supplies due primarily to higher chemicals costs in the prior year; and

• a decrease of $2.4 million in ad valorem taxes due to the timing of ad valorem tax estimates; offset partially by

• an increase of $2.3 million in employee-related costs due to higher labor and employee benefit costs resulting from the completion of ONEOK Partners’ growth projects; and

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• an increase of $1.1 million in outside services expense due primarily to the completion of ONEOK Partners’ growth projects.

Operating costs increased for the nine months ended September 30, 2015, compared with the same period in 2014, primarily as a result of the completion of ONEOK Partners’ growth projects, which include the following:

• an increase of $7.9 million in employee-related costs due to higher labor and employee benefit costs; and

• an increase of $6.3 million in outside services expense; offset partially by

• a decrease of $8.4 million in materials and supplies due primarily to higher chemicals costs in the prior year.

Depreciation and amortization expense increased for the three and nine months ended September 30, 2015, compared with the same periods in 2014, due to the completion of ONEOK Partners’ growth projects.

Equity in net earnings from investments increased for the three and nine months ended September 30, 2015, compared with the same periods in 2014, due to $76.4 million in impairment charges in the third quarter 2014 on ONEOK Partners’ investment in Bighorn Gas Gathering.

Capital expenditures increased for the three and nine months ended September 30, 2015, compared with the same periods in 2014, due primarily to the timing of expenditures for ONEOK Partners’ growth projects discussed above.

Selected Operating Information - The following tables set forth selected operating information for the Natural Gas Gathering and Processing segment for the periods indicated:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
Operating Information (a)	2015		2014		2015		2014
Natural gas gathered (BBtu/d)	1,897		1,847		1,877		1,665
Natural gas processed (BBtu/d) (b)	1,617		1,666		1,640		1,462
NGL sales (MBbl/d)	134		111		123		100
Residue natural gas sales (BBtu/d)	837		792		828		682
Realized composite NGL net sales price ($/gallon) (c) (d)	$	0.31	$	0.93	$	0.35	$	0.97
Realized condensate net sales price ($/Bbl) (c) (e)	$	42.32	$	81.02	$	35.80	$	78.00
Realized residue natural gas net sales price ($/MMBtu) (c) (e)	$	3.62	$	3.92	$	3.64	$	3.91
Average fee rate ($/MMBtu)	$	0.43	$	0.36	$	0.39	$	0.36

(a) - Includes volumes for consolidated entities only.

(b) - Includes volumes at company-owned and third-party facilities.

(c) - Includes the impact of hedging activities on ONEOK Partners’ equity volumes.

(d) - Net of transportation and fractionation costs.

(e) - Net of transportation costs.

Natural gas gathered volumes, NGL sales volumes and residue natural gas sales volumes increased during the three months ended September 30, 2015, compared with the same period in 2014, due to the completion of growth projects in the Williston Basin. Natural gas processed volumes decreased during the three months ended September 2015, compared with the same period in 2014, due to unplanned operational outages in the Williston Basin, natural declines in the Cana-Woodford Shale and minor timing delays in well connections in the Mid-Continent. We expect volumes to increase in the fourth quarter 2015 as unplanned operational outages from the third quarter in the Williston Basin have been resolved, a large producer continues to complete wells in the Cana-Woodford Shale that were drilled earlier in 2015, and the remaining compression projects are completed.

Natural gas gathered and processed volumes, NGL sales volumes and residue natural gas sales volumes increased during the nine months ended September 30, 2015, compared with the same period in 2014, due to the completion of growth projects in the Williston Basin and in the Mid-Continent area.

In March 2014, ONEOK Partners’ Canadian Valley plant in Oklahoma was completed, which has better ethane rejection capabilities than its other processing plants in the Mid-Continent region. Beginning in June 2015, ONEOK Partners reduced the level of ethane rejection in the Rocky Mountain region to address downstream NGL product specifications. We expect the decreased level of ethane rejection to continue into 2016. We expect the quantity and composition of NGLs and natural gas will continue to change as ONEOK Partners’ new natural gas processing plants in the Williston Basin are placed in service.

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	Three Months Ended		Nine Months Ended
	September 30,		September 30,
Equity Volume Information (a)	2015	2014	2015	2014
NGL sales (MBbl/d)	24.9	16.0	21.0	16.6
Condensate sales (MBbl/d)	2.7	2.6	3.0	3.1
Residue natural gas sales (BBtu/d)	136.3	134.5	141.6	109.6

(a) - Includes volumes for consolidated entities only.

Commodity Price Risk - The following tables set forth the Natural Gas Gathering and Processing segment’s hedging information. The tables below reflect the NGLs for propane, normal butane, iso-butane and natural gasoline only since the ethane component of the equity NGL volume is not hedged and is not expected to be material to our results of operations. The segment’s hedging information as of October 2015 for its equity volumes is as follows for the periods indicated:

	Three Months Ending December 31, 2015
	Volumes Hedged	Average Price			Percentage Hedged
NGLs - excluding ethane (MBbl/d) - Conway/Mont Belvieu	13.6	$	0.64	/ gallon	84%
Condensate (MBbl/d) - WTI-NYMEX	2.6	$	54.69	/ Bbl	96%
Natural gas (BBtu/d) - NYMEX and basis	122.8	$	3.64	/ MMBtu	97%

	Year Ending December 31, 2016
	Volumes Hedged	Average Price			Percentage Hedged
NGLs - excluding ethane (MBbl/d) - Conway/Mont Belvieu	4.9	$	0.54	/ gallon	49%
Condensate (MBbl/d) - WTI-NYMEX	1.5	$	62.65	/ Bbl	48%
Natural gas (BBtu/d) - NYMEX and basis	74.1	$	2.96	/ MMBtu	83%

ONEOK Partners has renegotiated many Natural Gas Gathering and Processing segment contracts to significantly increase its fee-based earnings and continues to actively work with its producer customers to similarly restructure additional contracts. ONEOK Partners’ NGLs, natural gas and crude oil commodity price sensitivity in this segment is expected to decrease in 2016 as contracts are renegotiated. The Natural Gas Gathering and Processing segment’s commodity price sensitivity is estimated as a hypothetical change in the price of NGLs, crude oil and natural gas at September 30, 2015, excluding the effects of hedging and assuming normal operating conditions. Condensate sales are based on the price of crude oil. We estimate the following for the three months ending December 31, 2015:

• a $0.01 per-gallon change in the composite price of NGLs would change three-month net margin by approximately $0.8 million;

• a $1.00 per-barrel change in the price of crude oil would change three-month net margin by approximately $0.3 million; and

• a $0.10 per-MMBtu change in the price of residue natural gas would change three-month net margin by approximately $1.2 million.

We estimate the following for the year ending December 31, 2016:

• a $0.01 per-gallon change in the composite price of NGLs would change 12-month net margin by approximately $1.8 million;

• a $1.00 per-barrel change in the price of crude oil would change 12-month net margin by approximately $1.3 million; and

• a $0.10 per-MMBtu change in the price of residue natural gas would change 12-month net margin by approximately $3.3 million.

These estimates do not include any effects on demand for ONEOK Partners’ services or processing plant operations that might be caused by, or arise in conjunction with, commodity price fluctuations. For example, a change in the gross processing spread may cause a change in the amount of ethane extracted from the natural gas stream, affecting natural gas gathering and processing margins for certain contracts.

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See Note E of the Notes to Consolidated Financial Statements in this Quarterly Report for more information on our hedging activities.

Powder River Basin - Crude oil and natural gas producers have primarily focused their development efforts on crude oil and NGL-rich supply basins rather than in areas with dry natural gas production, such as the coal-bed methane production areas in the Powder River Basin. The reduced coal-bed methane development activities and production declines in the dry natural gas formations of the Powder River Basin have resulted in lower natural gas volumes available to be gathered. While the reserve potential in the dry natural gas formations of the Powder River Basin still exists, future drilling and development in this area will be affected by commodity prices and producers’ alternative prospects.

The current commodity price environment has caused natural gas producers to reduce drilling for natural gas, which we expect will slow volume growth or reduce volumes of natural gas delivered to systems owned by ONEOK Partners’ Powder River Basin equity method investments. A continued decline in volumes gathered in the coal-bed methane area of the Powder River Basin may reduce ONEOK Partners’ ability to recover the carrying value of its equity investments in this area and could result in noncash charges to earnings. The net book value of ONEOK Partners’ equity method investments in this dry natural gas area is $214.2 million, which includes $130.5 million of equity method goodwill.

Natural Gas Liquids

Overview - The Natural Gas Liquids segment owns and operates facilities that gather, fractionate, treat and distribute NGLs and store NGL products, primarily in Oklahoma, Kansas, Texas, New Mexico and the Rocky Mountain region where it provides nondiscretionary services to producers of NGLs. ONEOK Partners owns or has an ownership interest in FERC-regulated natural gas liquids gathering and distribution pipelines in Oklahoma, Kansas, Texas, New Mexico, Montana, North Dakota, Wyoming and Colorado, and terminal and storage facilities in Missouri, Nebraska, Iowa and Illinois. ONEOK Partners also owns FERC-regulated natural gas liquids distribution and refined petroleum products pipelines in Kansas, Missouri, Nebraska, Iowa, Illinois and Indiana that connect its Mid-Continent assets with Midwest markets, including Chicago, Illinois. The majority of the pipeline-connected natural gas processing plants in Oklahoma, Kansas and the Texas Panhandle, which extract unfractionated NGLs from unprocessed natural gas, are connected to its gathering systems. ONEOK Partners owns and operates truck- and rail-loading and -unloading facilities connected with its natural gas liquids fractionation and pipeline assets and utilized in its NGL marketing activities. In November 2014, ONEOK Partners began transporting unfractionated NGLs from natural gas processing plants in the Permian Basin after completion of the West Texas LPG acquisition.

Most natural gas produced at the wellhead contains a mixture of NGL components, such as ethane, propane, iso-butane, normal butane and natural gasoline. The NGLs that are separated from the natural gas stream at the natural gas processing plants remain in a mixed, unfractionated form until they are gathered, primarily by pipeline, and delivered to fractionators where the NGLs are separated into NGL products. These NGL products are then stored or distributed to ONEOK Partners’ customers, such as petrochemical manufacturers, heating fuel users, ethanol producers, refineries and propane distributors. The Natural Gas Liquids segment also purchases NGLs and condensate from third parties, as well as from the Natural Gas Gathering and Processing segment.

Revenues for the Natural Gas Liquids segment are derived primarily from nondiscretionary fee-based services that ONEOK Partners provides to its customers and from the physical optimization of its assets. The segment’s fee-based services have increased due primarily to new supply connections; expansion of existing connections; its previously completed capital projects, including the Bakken NGL Pipeline and Sterling III Pipeline; the West Texas LPG acquisition; and expansion of its NGL fractionation capacity, including the completion of its MB-2 and MB-3 fractionators. The segment’s sources of revenue are categorized as exchange services, optimization and marketing, pipeline transportation, and isomerization and storage, which are defined as follows:

• ONEOK Partners’ exchange-services activities utilize its assets to gather, fractionate and/or treat unfractionated NGLs for a fee, thereby converting them into marketable NGL products that are stored and shipped to a market center or customer-designated location. Many of these exchange volumes are under contracts with minimum volume commitments.

• ONEOK Partners’ optimization and marketing activities utilize its assets, contract portfolio and market knowledge to capture location, product and seasonal price differentials.  It transports NGL products between Conway, Kansas, and Mont Belvieu, Texas, to capture the location price differentials between the two market centers.  Its natural gas liquids storage facilities also are utilized to capture seasonal price variances. A growing portion of its marketing activities serves truck and rail markets.

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• ONEOK Partners’ pipeline transportation services transport unfractionated NGLs, NGL products and refined petroleum products, primarily under FERC-regulated tariffs.  Tariffs specify the maximum rates it charges customers and the general terms and conditions for NGL transportation service on its pipelines.

• ONEOK Partners’ isomerization activities capture the price differential when normal butane is converted into the more valuable iso-butane at its isomerization unit in Conway, Kansas.  Iso-butane is used in the refining industry to increase the octane of motor gasoline.

• ONEOK Partners’ storage activities consist primarily of fee-based NGL storage services at its Mid-Continent and Gulf Coast storage facilities.

NGL location price differentials have generally remained narrow between the Mid-Continent and Gulf Coast market centers. We expect these narrow NGL price differentials, with periods of volatility for certain NGL products, to continue as new fractionators and pipelines, including ONEOK Partners’ growth projects discussed below, help alleviate constraints that have historically existed between the Conway, Kansas, and Mont Belvieu, Texas, natural gas liquids market centers. In addition, new natural gas liquids pipeline projects constructed by third parties have started to bring incremental NGL supply from the Rocky Mountain, Marcellus and Utica regions to the Mont Belvieu, Texas, market center that may affect NGL prices, as well as compete with or displace NGL supply volumes from the Mid-Continent and Rocky Mountain regions where ONEOK Partners’ assets are located. The Natural Gas Liquids segment’s capital-growth projects are supported by fee-based contractual commitments that we expect will fill much of its optimization capacity used historically to capture NGL location price differentials between the two market centers.

Supply growth has resulted in available ethane supplies that are greater than the petrochemical industry’s current demand. As a result, low or unprofitable price differentials between ethane and natural gas have resulted in ethane rejection at most of ONEOK Partners’ and its customers’ natural gas processing plants connected to its natural gas liquids gathering system in the Mid-Continent, Permian and Rocky Mountain regions during 2014 and the first nine months of 2015. Through ethane rejection, natural gas processors leave much of the ethane component in the natural gas stream sold at the tailgate of natural gas processing plants. We expect ethane rejection to persist at current levels until ethylene producers increase their capacity to consume additional ethane feedstock volumes through plant modifications, plant expansions and the completion of announced new world-scale ethylene production projects beginning in 2017. Ethane rejection is expected to continue to have a significant impact on our financial results through 2017. However, beginning in June 2015, the Natural Gas Gathering and Processing segment reduced its level of ethane rejection in the Rocky Mountain region to alleviate downstream NGL product specification issues, which offsets partially this financial impact. We expect this decreased ethane rejection to continue into 2016. In addition, the Natural Gas Liquids segment’s integrated assets enable ONEOK Partners to mitigate partially the impact of ethane rejection through minimum volume commitments, contract modifications that vary fees for ethane and other NGL products, and ONEOK Partners’ ability to utilize the transportation capacity made available due to ethane rejection to capture additional NGL location price differentials, when they exist, in its optimization activities. See additional discussion in the “Financial Results and Operating Information” section.

Growth Projects - ONEOK Partners’ growth strategy in the Natural Gas Liquids segment is focused around the crude oil and NGL-rich natural gas drilling activity in shale and other nonconventional resource areas from the Rocky Mountain region through the Mid-Continent region into Texas and New Mexico. Crude oil, natural gas and NGL production from this activity; higher petrochemical industry demand for NGL products; and increased exports have resulted in ONEOK Partners making additional capital investments to expand its infrastructure to bring these commodities from supply basins to market. Expansion of the petrochemical industry in the United States is expected to increase ethane demand significantly beginning in 2017, and international demand for NGLs, particularly propane, also is increasing and is expected to continue to do so in the future.

The Natural Gas Liquids segment is investing in NGL-related projects to accommodate the transportation and fractionation of NGL supply from shale and other resource development areas across ONEOK Partners’ asset base and alleviate expected infrastructure constraints between the Mid-Continent and Gulf Coast market centers to meet increasing petrochemical industry and NGL export demand in the Gulf Coast. Over time, these growing fee-based NGL volumes are expected to fill much of ONEOK Partners’ natural gas liquids pipeline capacity used historically to capture the NGL location price differentials between the two market centers.

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ONEOK Partners has completed the following growth projects in this segment in 2014 and through the third quarter 2015:

Completed Projects	Location	Capacity	Approximate Costs (a)	Completion Date
			(In millions)
Ethane/Propane Splitter	Texas Gulf Coast	40 MBbl/d	$46	March 2014
Sterling III Pipeline and reconfigure Sterling I and II	Mid-Continent Region	193 MBbl/d	$808	March 2014
Bakken NGL Pipeline expansion - Phase I	Rocky Mountain Region	75 MBbl/d	$90	September 2014
Niobrara NGL Lateral	Powder River Basin	90 miles	$65	September 2014
West Texas LPG (b)	Permian Basin	2,600 miles	$800	November 2014
MB-3 Fractionator	Texas Gulf Coast	75 MBbl/d	$520-$540	December 2014
NGL Pipeline and Hutchinson Fractionator infrastructure	Mid Continent Region	95 miles	$115-$120	April 2015

(a) - Excludes AFUDC.

(b) - Acquisition.

ONEOK Partners has the following projects in various stages of construction:

Projects in Progress	Location	Capacity	Approximate Costs (a)	Expected Completion Date
			(In millions)
Bakken NGL Pipeline expansion - Phase II	Rocky Mountain Region	25 MBbl/d	$100	Third quarter 2016
Bear Creek NGL infrastructure	Williston Basin	40 miles	$35-$45	Third quarter 2016
Bronco NGL infrastructure	Powder River Basin	65 miles	$45-$60	Suspended
Demicks Lake NGL infrastructure	Williston Basin	12 miles	$10-$15	Suspended
Total			$190-$220

(a) - Excludes AFUDC.

As a result of reductions in crude oil and natural gas drilling activities and our expectation of continued slower supply growth due to the declines in crude oil, natural gas and NGL prices, ONEOK Partners has suspended capital expenditures for certain natural gas liquids infrastructure projects related to planned natural gas processing plants. We expect ONEOK Partners to resume its suspended capital-growth projects as soon as market conditions improve. If the current commodity price environment persists for a prolonged period, it may further impact the timing or demand for these projects and additional infrastructure projects or growth opportunities in the future.

Natural gas liquids pipeline and modification of Hutchinson fractionation infrastructure - In April 2015, ONEOK Partners completed a new 95-mile natural gas liquids pipeline that connects its existing natural gas liquids fractionation and storage facilities in Hutchinson, Kansas, to similar facilities in Medford, Oklahoma. The project also included modifications to existing natural gas liquids fractionation infrastructure at Hutchinson, Kansas, increasing fractionation capacity by 20 MBbl/d to accommodate additional unfractionated NGLs produced in the Williston Basin.

Bakken NGL Pipeline expansion, Phase II- The second expansion will increase the pipeline’s capacity to 160 MBbl/d from the current capacity of 135 MBbl/d.

Bear Creek natural gas liquids infrastructure - ONEOK Partners announced in September 2014 its plan to build new natural gas liquids pipeline infrastructure to connect the Bear Creek natural gas processing plant to its Bakken NGL Pipeline.

Bronco natural gas liquids infrastructure - ONEOK Partners announced in September 2014 its plan to build new natural gas liquids pipeline infrastructure to connect the Bronco natural gas processing plant to its Bakken NGL Pipeline. Due to the suspension of the Bronco Plant, the Bronco natural gas liquids infrastructure is currently suspended but can be quickly resumed as market conditions improve.

Demicks Lake natural gas liquids infrastructure - ONEOK Partners announced in July 2014 its plan to build new natural gas liquids pipeline infrastructure to connect the Demicks Lake natural gas processing plant to its Bakken NGL Pipeline. Due to the suspension of the Demicks Lake Plant, the Demicks Lake natural gas liquids infrastructure is currently suspended but can be quickly resumed as market conditions improve.

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For a discussion of ONEOK Partners’ capital expenditure financing, see “Capital Expenditures” in “Liquidity and Capital Resources.”

Selected Financial Results - The Natural Gas Liquids segment’s financial results for the three and nine months ended September 30, 2015, reflect the benefits from the following projects and acquisition:

• the NGL Pipeline and Hutchinson Fractionator infrastructure, which was completed in April 2015;

• the MB-3 Fractionator, which was completed in December 2014;

• the West Texas LPG acquisition, which was completed in November 2014;

• the Bakken NGL Pipeline expansion Phase I, which was completed in September 2014; and

• the Niobrara NGL Lateral, which was completed in September 2014.

Additionally, the financial results for the nine months ended September 30, 2015, reflect the benefits from the following projects:

• the Ethane/propane splitter, which was completed in March 2014; and

• the Sterling III Pipeline and reconfiguration of the Sterling II Pipeline, which were completed in March 2014.

The following table sets forth certain selected financial results for the Natural Gas Liquids segment for the periods indicated:

	Three Months Ended						Nine Months Ended						Three Months					Nine Months
	September 30,						September 30,						2015 vs. 2014					2015 vs. 2014
Financial Results	2015			2014			2015			2014			Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
NGL and condensate sales	$	1,253.1		$	2,450.2		$	3,965.2		$	7,341.0		$	(1,197.1	)	(49	%)	$	(3,375.8	)	(46	%)
Exchange service and storage revenues	313.2			265.0			861.8			710.9			48.2			18	%	150.9			21	%
Transportation revenues	45.1			19.3			129.4			59.7			25.8			*		69.7			*
Cost of sales and fuel	1,289.6			2,451.5			4,054.0			7,293.5			(1,161.9		)	(47	%)	(3,239.5		)	(44	%)
Net margin	321.8			283.0			902.4			818.1			38.8			14	%	84.3			10	%
Operating costs	74.5			77.0			234.1			218.2			(2.5		)	(3	%)	15.9			7	%
Depreciation and amortization	39.3			31.7			118.1			89.8			7.6			24	%	28.3			32	%
Gain (loss) on sale of assets	(0.5		)	(0.5		)	(0.6		)	(0.6		)	—			—	%	—			—	%
Operating income	$	207.5		$	173.8		$	549.6		$	509.5		$	33.7		19	%	$	40.1		8	%
Equity in net earnings from investments	$	10.9		$	4.4		$	27.6		$	13.6		$	6.5		*		$	14.0		*
Capital expenditures	$	52.8		$	153.8		$	185.4		$	637.5		$	(101.0	)	(66	%)	$	(452.1	)	(71	%)

* Percentage change is greater than 100 percent.

Crude prices declined sharply in the fourth quarter 2014 and remained relatively low during the first nine months of 2015, which impacted NGL prices as NGL prices generally are linked to crude oil prices. These price decreases affected NGL and condensate sales revenue and cost of sales and fuel in our Consolidated Statements of Income.

In the first quarter 2014, ONEOK Partners experienced increased propane demand and prices, which impacted our results of operations for the three and nine months ended September 30, 2014, due to colder than normal weather. The price of propane in the Mid-Continent market and the wider location price differentials between the Mid-Continent and Gulf Coast market centers peaked in late January 2014 and returned to historical levels by the end of February 2014 as supply and demand balanced.

Net margin increased for the three months ended September 30, 2015, compared with the same period in 2014, primarily as a result of the following:

• an increase of $27.5 million in exchange-services margins, which resulted primarily from increased volumes from new plantconnections in the Williston Basin, Powder River Basin and Mid-Continent region, offset partially by unplanned operational outages at ONEOK Partners’ natural gas processing plants in the Williston Basin;

• an increase of $26.1 million in transportation margins due primarily to volumes from the Permian Basin from the West Texas LPG system, which was acquired in November 2014;

• an increase of $12.5 million resulting from decreased ethane rejection in the Williston Basin, offset partially by higher ethane rejection in the Mid-Continent region; and

• an increase of $1.1 million in higher storage margin; offset partially by

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• a decrease of $17.2 million in optimization and marketing margins, which resulted from an $18.4 million decrease due primarily to narrower NGL product price differentials and a $3.6 million decrease in marketing margins, offset partially by a $4.8 million increase due primarily to wider NGL location price differentials;

• a decrease of $6.2 million related to lower isomerization volumes, resulting from the narrower NGL product price differentials between normal butane and iso-butane; and

• a decrease of $5.0 million due to the impact of operational measurement gains in 2014 and operational measurement losses in 2015.

Net margin increased for the nine months ended September 30, 2015, compared with the same period in 2014, primarily as a result of the following:

• an increase of $149.7 million in exchange-services margins, which resulted primarily from increased volumes from new plant connections in the Williston Basin, Powder River Basin and Mid-Continent region, higher fees for exchange-services activities resulting from contract negotiations, and higher revenues from customers with minimum volume obligations, offset partially by unplanned operational outages at ONEOK Partners’ natural gas processing plants in the Williston Basin during the third quarter 2015;

• an increase of $67.1 million in transportation margins due primarily to volumes from the Permian Basin from the West Texas LPG system, which was acquired in November 2014; and

• an increase of $2.0 million resulting from decreased ethane rejection in the Williston Basin, offset partially by higher ethane rejection in the Mid-Continent region; offset partially by

• a decrease of $100.2 million in optimization and marketing margins, which resulted from a $55.7 million decrease due primarily to narrower NGL product price differentials, a $25.8 million decrease due primarily to significantly narrower NGL location price differentials and an $18.7 million decrease in marketing margins. These decreases relate primarily to the increased demand for propane we experienced during the first quarter 2014;

• a decrease of $26.6 million related to lower isomerization volumes, resulting from the narrower NGL product price differential between normal butane and iso-butane; and

• a decrease of $8.8 million due to the impact of operational measurement gains in 2014 and operational measurement losses in 2015.

Operating costs decreased for the three months ended September 30, 2015, compared with the same period in 2014, primarily as a result of the following:

• a decrease of $3.9 million due to lower outside services expense and miscellaneous supplies and expenses due primarily to scheduled maintenance in the prior year; offset partially by

• an increase of $1.4 million due to higher employee-related costs due primarily to higher labor and employee benefit costs as a result of the completion of ONEOK Partners’ growth projects and acquisitions.

Operating costs increased for the nine months ended September 30, 2015, compared with the same period in 2014, primarily as a result of the completion of ONEOK Partners’ growth projects and acquisitions, and include the following:

• an increase of $8.6 million due to higher employee-related costs due primarily to higher labor and employee benefit costs; and

• an increase of $6.9 million due to higher ad valorem taxes.

Depreciation and amortization expense increased for the three and nine months ended September 30, 2015, compared with the same periods in 2014, due to depreciation associated with completed capital projects, including acquisitions.

Equity in net earnings from investments increased for the three and nine months ended September 30, 2015, compared with the same periods in 2014, due primarily to higher volumes delivered to Overland Pass Pipeline from the Bakken NGL Pipeline.

Capital expenditures decreased for the three and nine months ended September 30, 2015, compared with the same periods in 2014, due primarily to the timing of expenditures for ONEOK Partners’ growth projects discussed above.

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Selected Operating Information - The following table sets forth selected operating information for the Natural Gas Liquids segment for the periods indicated:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
Operating Information	2015		2014		2015		2014
NGL sales (MBbl/d)	683		626		657		598
NGLs transported-gathering lines (MBbl/d) (a)	786		529		759		508
NGLs fractionated (MBbl/d) (b)	591		553		540		515
NGLs transported-distribution lines (MBbl/d) (a)	456		377		422		412
Average Conway-to-Mont Belvieu OPIS price differential - ethane in ethane/propane mix ($/gallon)	$	0.02	$	0.03	$	0.02	$	0.06

(a) - Includes volumes for consolidated entities only.

(b) - Includes volumes at company-owned and third-party facilities.

NGLs transported on gathering lines and NGLs fractionated increased for the three and nine months ended September 30, 2015, compared with the same periods in 2014, due to increased volumes from new plant connections in the Williston Basin, Powder River Basin and Mid-Continent region, and decreased ethane rejection in the Rocky Mountain region beginning in June 2015 due to downstream NGL product specifications, offset partially by increased ethane rejection in the Mid-Continent region and unplanned operational outages at ONEOK Partners’ natural gas processing plants in the Williston Basin during the third quarter 2015. Gathered volumes increased approximately 20 MBbl/d in the Rocky Mountain region due to decreased ethane rejection in the third quarter 2015, and we expect this decreased level of rejection to continue into 2016. NGLs transported on gathering lines also increased significantly for the three and nine months ended September 30, 2015, compared with the same periods in 2014, due to volumes from the Permian Basin transported on the West Texas LPG system, which was acquired in November 2014.

NGLs transported on distribution lines increased for the three and nine months ended September 30, 2015, compared with the same periods in 2014, due primarily to higher gathered and fractionated volumes as discussed above.

Natural Gas Pipelines

Overview - The Natural Gas Pipelines segment owns and operates regulated natural gas transmission pipelines and natural gas storage facilities. It also provides interstate natural gas transportation and storage service in accordance with Section 311(a) of the Natural Gas Policy Act.

The segment’s FERC-regulated interstate natural gas pipeline assets transport natural gas through pipelines in North Dakota, Minnesota, Wisconsin, Illinois, Indiana, Kentucky, Tennessee, Oklahoma, Texas and New Mexico. Its interstate pipeline companies include:

• Midwestern Gas Transmission, which is a bi-directional system that interconnects with Tennessee Gas Transmission Company’s pipeline near Portland, Tennessee, and with several interstate pipelines at the Chicago Hub near Joliet, Illinois;

• Viking Gas Transmission, which is a bi-directional system, interconnects with a TransCanada Corporation pipeline near Emerson, Manitoba, and ANR Pipeline Company near Marshfield, Wisconsin;

• Guardian Pipeline, which interconnects with several pipelines at the Chicago Hub near Joliet, Illinois, and with local natural gas distribution companies in Wisconsin; and

• OkTex Pipeline, which has interconnects in Oklahoma, Texas and New Mexico.

This segment’s intrastate natural gas pipeline assets in Oklahoma transport natural gas through the state and have access to the major natural gas producing formations, including the Cana-Woodford Shale, Woodford Shale, Springer Shale, Granite Wash, Stack, SCOOP and Mississippian Lime. In Texas, its intrastate natural gas pipelines are connected to the major natural gas producing formations in the Texas Panhandle, including the Granite Wash formation and Delaware and Cline producing formations in the Permian Basin; and transport natural gas throughout the western portion of Texas, including the Waha Hub where other pipelines may be accessed for transportation to western markets, the Houston Ship Channel market to the east and the Mid-Continent market to the north. ONEOK Partners also has access to the natural gas producing formations in south central Kansas.

The segment owns underground natural gas storage facilities in Oklahoma and Texas that are connected to its intrastate natural gas pipeline assets. It also has underground natural gas storage facilities in Kansas.

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The segment’s transportation contracts for its regulated natural gas activities are based upon rates stated in its tariffs. Tariffs specify the maximum rates that customers may be charged, which may be discounted to meet competition if necessary, and the general terms and conditions for pipeline transportation service, which are established at FERC or appropriate state jurisdictional agency proceedings known as rate cases. In Texas and Kansas, natural gas storage service is a fee business that may be regulated by the state in which the facility operates and by the FERC for certain types of services. In Oklahoma, natural gas storage operations are also a fee business but are not subject to rate regulation by the state and have market-based rate authority from the FERC for certain types of services.

The Natural Gas Pipelines segment’s revenues are derived primarily from fee-based services. Revenues are generated from the following types of fee-based contracts:

• Firm service - Customers can reserve a fixed quantity of pipeline or storage capacity for the term of their contract. Under this type of contract, the customer pays a fixed fee for a specified quantity regardless of their actual usage. The customer then typically pays incremental fees, known as commodity charges, that are based upon the actual volume of natural gas they transport or store, and/or ONEOK Partners may retain a specified volume of natural gas in-kind for fuel. Under the firm-service contract, the customer generally is guaranteed access to the capacity they reserve; and

• Interruptible service - Customers with interruptible service transportation and storage agreements may utilize available capacity after firm-service requests are satisfied or on an as-available basis. Interruptible service customers typically are assessed fees, such as a commodity charge, based on their actual usage, and/or ONEOK Partners may retain a specified volume of natural gas in-kind for fuel. Under the interruptible service contract, the customer is not guaranteed use of ONEOK Partners’ pipelines and storage facilities unless excess capacity is available.

Growth Projects - The following projects are in various stages of construction. Roadrunner is a 50 percent-owned joint venture equity method investment project. WesTex is a wholly owned project.

Projects in Progress	Location	Capacity	Approximate Costs (a)	Expected Completion Date
			(In millions)
WesTex Transmission Pipeline Expansion	Permian Basin	260 MMcf/d	$70-$100	First quarter 2017
Roadrunner Gas Transmission Pipeline - Equity Method Investment
Phase I (b)	Permian Basin	170 MMcf/d	$200-$220	First quarter 2016
Phase II (b)	Permian Basin	400 MMcf/d	$220-$240	First quarter 2017
Phase III (b)	Permian Basin	70 MMcf/d	$30-$40	2019
Roadrunner Gas Transmission Pipeline Total			$450-$500

(a) - Excludes AFUDC.

(b) - 50-50 joint venture equity method investment. Approximate costs represents total project costs, which are expected to be financed with approximately 50 percent equity contributions and 50 percent debt issued by Roadrunner. ONEOK Partners expects to make equity contributions for approximately 25 percent of the total project costs.

Roadrunner - In March 2015, ONEOK Partners entered into a 50-50 joint venture with a subsidiary of Fermaca, a Mexico City-based natural gas infrastructure company, to construct a pipeline to transport natural gas from the Permian Basin in West Texas to the Mexican border near El Paso, Texas. The pipeline will connect with ONEOK Partners’ existing natural gas pipeline and storage infrastructure in Texas and is expected to create a platform for future cross-border development opportunities. These integrated assets also are expected to provide markets in Mexico access to upstream supply basins in West Texas and the Mid-Continent region, which adds location and price diversity to their supply mix and supports the plan of Mexico’s national electric utility, Comisión Federal de Electricidad, to replace fuel oil-based power plants with natural gas-fueled power plants, which are more economical and produce fewer GHG emissions.

Roadrunner was fully subscribed for its initial design through an open season process held in December 2014. Precedent agreements representing the initial design capacity have been executed with the Comisión Federal de Electricidad and a Fermaca subsidiary. All transportation agreements will be firm demand charge and will have a term of 25 years. Additional capacity could become available through future expansions depending on the demands of the market.

ONEOK Partners will manage the construction of the project and will be the operator of the pipeline upon its completion. The estimated total cost of the project is approximately $450 million to $500 million. ONEOK Partners contributed approximately $30 million to Roadrunner in the nine months ended September 30, 2015, and does not expect to make any further

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contributions in 2015. These contributions are generally being used for acquisition of right of way, pipe and materials. ONEOK Partners expects to contribute approximately $65 million to Roadrunner during 2016. Roadrunner entered into a $230 million senior secured credit facility for the construction and operation of the pipeline. The senior secured credit facility expires 7 years after the Roadrunner in-service date of Phase II, which is expected to be completed in the first quarter 2017. In addition, Roadrunner executed interest-rate swaps to hedge the variability of its interest payments during the term of the credit facility.

The FERC approved Roadrunner’s request for a Presidential Permit and authorization in October 2015, and construction has commenced.

WesTex Pipeline Expansion - In July 2015, ONEOK Partners announced it plans to expand the capacity of the WesTex intrastate natural gas pipeline by constructing two new compressor stations and upgrading or expanding three existing compressor stations. The expansion project is approximately 90 percent subscribed with long-term firm demand charge transportation contracts and will complement the Roadrunner pipeline project. Together, these projects provide markets in Mexico access to upstream supply basins in West Texas and the Mid-Continent region.

Selected Financial Results - The following table sets forth certain selected financial results for the Natural Gas Pipelines segment for the periods indicated:

	Three Months Ended					Nine Months Ended					Three Months					Nine Months
	September 30,					September 30,					2015 vs. 2014					2015 vs. 2014
Financial Results	2015			2014		2015			2014		Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
Transportation revenues	$	63.7		$	64.3	$	193.5		$	204.7	$	(0.6	)	(1	%)	$	(11.2	)	(5	%)
Storage revenues	14.2			12.6		42.4			48.6		1.6			13	%	(6.2		)	(13	%)
Natural gas sales and other revenues	5.1			2.2		10.8			12.6		2.9			*		(1.8		)	(14	%)
Cost of sales and fuel	7.6			5.7		28.1			23.5		1.9			33	%	4.6			20	%
Net margin	75.4			73.4		218.6			242.4		2.0			3	%	(23.8		)	(10	%)
Operating costs	26.7			28.0		79.1			82.8		(1.3		)	(5	%)	(3.7		)	(4	%)
Depreciation and amortization	10.9			10.9		32.5			32.6		—			—	%	(0.1		)	—	%
Gain (loss) on sale of assets	(0.1		)	1.7		(0.1		)	1.7		(1.8		)	*		(1.8		)	*
Operating income	$	37.7		$	36.2	$	106.9		$	128.7	$	1.5		4	%	$	(21.8	)	(17	%)
Equity in net earnings from investments	$	17.0		$	14.4	$	52.1		$	53.7	$	2.6		18	%	$	(1.6	)	(3	%)
Capital expenditures	$	14.7		$	10.7	$	39.9		$	26.0	$	4.0		37	%	$	13.9		53	%
Cash paid for acquisitions	$	—		$	—	$	—		$	14.0	$	—		—	%	$	(14.0	)	(100	%)

* Percentage change is greater than 100 percent.

Net margin increased for the three months ended September 30, 2015, compared with the same period in 2014, primarily as a result of the following:

• an increase of $1.3 million due to higher storage revenues from increased rates; and

• an increase of $1.2 million due to higher transportation revenues, primarily from higher rates on Viking Gas Transmission Company.

Net margin decreased for the nine months ended September 30, 2015, compared with the same period in 2014, primarily as a result of the following:

• a decrease of $12.6 million from lower short-term natural gas storage services due primarily to increased weather-related seasonal demand associated with severely cold weather in the first quarter 2014;

• a decrease of $9.4 million from lower net retained fuel due to lower natural gas prices and lower natural gas volumes retained;

• a decrease of $4.8 million due to decreased park-and-loan services on ONEOK Partners’ interstate pipelines as a result of increased weather-related seasonal demand due to severely cold weather in the first quarter 2014; and

• a decrease of $1.9 million due to lower storage revenues from lower contracted firm capacity, offset partially by increased rates; offset partially by

• an increase of $5.8 million due to higher transportation revenues, primarily from increased rates on intrastate pipelines and higher rates on Viking Gas Transmission Company.

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Operating costs decreased for the three and nine months ended September 30, 2015, compared with the same periods in 2014, primarily as a result of lower materials and supplies expense.

Gain on sale of assets decreased for the three and nine months ended September 30, 2015, compared with the same period in 2014, as a result of an excess pad gas sale in 2014.

Equity in net earnings from investments increased for the three months ended September 30, 2015, compared with the same period in 2014, due primarily to an increase in firm transportation on Northern Border Pipeline.

Equity in net earnings from investments decreased for the nine months ended September 30, 2015, compared with the same period in 2014, due primarily to decreased park-and-loan services on Northern Border Pipeline resulting from increased weather-related seasonal demand due to severely cold weather in the first quarter 2014, offset partially by an increase in firm transportation.

Capital expenditures increased for the three and nine months ended September 30, 2015, compared with the same periods in 2014, due primarily to an increase in routine growth projects.

Selected Operating Information - The following table sets forth selected operating information for the Natural Gas Pipelines segment for the periods indicated:

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
Operating Information (a)	2015			2014			2015			2014
Natural gas transportation capacity contracted (MDth/d)	5,739			5,725			5,797			5,760
Transportation capacity contracted	90		%	90		%	91		%	91		%
Average natural gas price
Mid-Continent region ($/MMBtu)	$	2.59		$	3.77		$	2.56		$	4.58

(a) - Includes volumes for consolidated entities only.

ONEOK Partners’ natural gas pipelines primarily serve end users, such as natural gas distribution and electric-generation companies that require natural gas to operate their businesses regardless of location price differentials. The development of shale and other resource areas has continued to increase available natural gas supply resulting in narrower location and seasonal price differentials. As additional supply is developed, we expect crude oil and natural gas producers to demand incremental services in the future to transport their production to market. The abundance of shale gas supply and new regulations on emissions from coal-fired electric-generation plants may also increase the demand for ONEOK Partners’ services from electric-generation companies as they convert to a natural gas fuel source. Conversely, contracted capacity by certain customers that are focused on capturing location or seasonal price differentials may decrease in the future due to narrowing price differentials. Overall, we expect fee-based earnings to remain relatively stable with growth in certain market areas as the development of shale and other resource areas continues.

In August 2014, Viking Gas Transmission Company filed a “Stipulation and Agreement in Resolutions of All Issues Concerning Adjustment in Rates of Viking Gas Transmission Company” (settlement) with the FERC. The settlement was approved on October 1, 2014, and became final on October 31, 2014. Rates under the settlement became effective January 1, 2015.

Northern Border Pipeline, in which ONEOK Partners has a 50 percent ownership interest, has contracted substantially all of its long-haul transportation capacity through September 2016.

CONTINGENCIES

Gas Index Pricing Litigation - As previously reported, ONEOK and its subsidiary, OESC, along with several other energy companies, are defending multiple lawsuits arising from alleged market manipulation or false reporting of natural gas prices to natural gas-index publications alleged to have occurred prior to 2003. On April 10, 2013, the United States Court of Appeals for the Ninth Circuit reversed the summary judgments that had been granted in favor of ONEOK, OESC and other unaffiliated defendants in the following cases: Reorganized FLI, Learjet, Arandell, Heartland and NewPage. The Ninth Circuit also reversed the summary judgment that had been granted in favor of OESC on all state law claims asserted in the Sinclair case. On April 21, 2015, the United States Supreme Court affirmed the decision of the Ninth Circuit. The cases have now been remanded back to the trial court (the United States District Court for the District of Nevada) for further proceedings.

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Because of the uncertainty surrounding the Gas Index Pricing Litigation, including an insufficient description of the purported classes and other related matters, we cannot reasonably estimate a range of potential exposures at this time. However, it is reasonably possible that the ultimate resolution of these matters could result in future charges that may be material to our results of operations.

Other Legal Proceedings - We and ONEOK Partners are party to various other litigation matters and claims that have arisen in the normal course of our operations. While the results of these various other litigation matters and claims cannot be predicted with certainty, we believe the reasonably possible losses from such matters, individually and in the aggregate, are not material. Additionally, we believe the probable final outcome of such matters will not have a material adverse effect on our consolidated results of operations, financial position or cash flows. Additional information about legal proceedings is included under Part I, Item 3, Legal Proceedings, in our Annual Report.

LIQUIDITY AND CAPITAL RESOURCES

General - We fund operating expenses, debt service and dividends to shareholders primarily from cash distributions received from ONEOK Partners.

Neither ONEOK nor ONEOK Partners guarantees the debt or other similar commitments of unaffiliated parties. ONEOK does not guarantee the debt or other similar commitments of ONEOK Partners, and ONEOK Partners does not guarantee the debt or other similar commitments of ONEOK.

ONEOK - ONEOK’s primary source of cash inflows are distributions to us from our general partner and limited partnership interests in ONEOK Partners. The cash distributions that we expect to receive from ONEOK Partners are expected to provide sufficient resources to finance our operations and quarterly cash dividends. Our next long-term debt maturity is in 2022.

In March 2014, we completed the wind down of our energy services business. We expect future cash expenditures associated with the released transportation and storage capacity from the wind down of our energy services business on an after-tax basis to be approximately $26 million, with approximately $4 million to be paid in the remainder of 2015, $11 million in 2016, $6 million in 2017 and $5 million over the period 2018 through 2023.

ONEOK Partners - Part of ONEOK Partners’ strategy is to grow through internally generated growth projects and acquisitions that strengthen and complement its existing assets. It relies primarily on operating cash flows, commercial paper, bank credit facilities, debt issuances and the issuance of common units for its liquidity and capital resources requirements. It funds its operating expenses, debt service and cash distributions to its limited partners and general partner primarily with operating cash flows. To the extent operating cash flows are not sufficient to fund its cash distributions, ONEOK Partners may utilize short- and long-term debt and issuances of common units, as necessary. Capital expenditures are funded by operating cash flows, short- and long-term debt and issuances of equity. We expect it will continue to use these sources for liquidity and capital resource needs on both a short- and long-term basis. ONEOK Partners has no guarantees of debt or other similar commitments to unaffiliated parties.

While ONEOK Partners’ net margin is primarily derived from fee-based contracts, a portion of its net margin is dependent upon the prevailing and future prices for NGLs, crude oil and natural gas. Commodity prices are dependent on numerous factors beyond its control, such as overall crude oil and natural gas supply and demand, and inventories in relevant markets, economic conditions, the domestic and global political environments, regulatory developments and competition from other energy sources. Commodity prices historically have been volatile and may be subject to significant fluctuations in the future.

ONEOK Partners uses hedges to partially mitigate its near-term sensitivity to fluctuations in the natural gas, crude oil and NGL prices received for its equity volumes. See further discussion of ONEOK Partners’ hedged volumes in the “Commodity Price Risk” section in the Natural Gas Gathering and Processing segment.

We expect the energy commodity price environment to remain depressed for at least the near term, including through the remainder of 2015, with a modest recovery in 2016. The current commodity price environment has caused crude oil and natural gas producers to reduce drilling for crude oil and natural gas, which we expect will continue to slow volume growth, or reduce the volumes of natural gas and NGLs delivered on to ONEOK Partners’ systems. These conditions are expected to significantly impact our results of operations and cash flows. ONEOK Partners has minimum volume or firm demand charge agreements that mitigate partially its volumetric risk; however, if the current energy commodity price environment persists for a prolonged period or declines further, it could have a material adverse effect on our financial position, results of operations and cash flows.

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ONEOK Partners continues to have access to its commercial paper program and the ONEOK Partners Credit Agreement, which we expect to be adequate to fund short-term liquidity needs. In the first quarter 2015, ONEOK Partners increased the capacity of the ONEOK Partners Credit Agreement to an aggregate of $2.4 billion from $1.7 billion. ONEOK Partners also increased the size of its commercial paper program to $2.4 billion from $1.7 billion during the first quarter 2015. The facility is available to provide liquidity for working capital, capital expenditures and other general partnership purposes.

We expect the low commodity prices to continue to impact ONEOK Partners’ volumes and margins in the fourth quarter 2015 and into 2016, and ONEOK Partners is responding by aligning its operating costs and capital-growth projects with the needs of crude oil and natural gas producers, which includes suspending, reducing or eliminating certain capital-growth projects, limiting increases of distributions to its limited partners and negotiating various contract enhancements. Many contracts in the Natural Gas Gathering and Processing and Natural Gas Liquids segments include fixed fee, minimum volume or firm demand charge agreements that ensure a minimum level of revenues regardless of commodity prices. Additionally, ONEOK Partners has renegotiated many Natural Gas Gathering and Processing segment contracts to significantly increase its fee-based earnings and continues to actively work with its producer customers to similarly restructure additional contracts. ONEOK Partners expects to substantially complete its negotiations on Williston Basin contracts in 2015 and receive the full benefit of the improved margins in 2016.

ONEOK Partners’ ability to continue to access capital markets for debt and equity financing under reasonable terms depends on its financial condition, credit ratings and market conditions. The decline in commodity prices and reductions in ONEOK Partners’ volume growth outlook have resulted in a decrease in its common unit price, which is expected to increase its debt and equity financing costs. While lower commodity prices and industry uncertainty may result in increased financing costs, we believe it has sufficient access to the financial resources and liquidity, including access to public or private markets for equity and/or debt, necessary to meet its requirements for working capital, debt service payments and capital expenditures.

In the second and third quarters of 2015, ONEOK Partners’ cash flow from operations exceeded its cash distributions. However, for the nine months ended September 30, 2015, ONEOK Partners’ cash distributions exceeded its cash flow from operations. As a result, ONEOK Partners utilized cash from operations, its commercial paper program and distributions received from its equity-method investments to fund its cash distributions, short-term liquidity needs and capital projects. ONEOK Partners subsequently financed its capital-growth projects and repaid amounts outstanding under its commercial paper program with proceeds from its March 2015 senior notes offering, its August 2015 equity issuance and its “at-the-market” equity program. We expect increases in ONEOK Partners’ cash flows from operations in the fourth quarter 2015, compared with the first, second and third quarters of 2015, and in 2016 compared with 2015, due primarily to completion of ONEOK Partners growth projects that we expect will provide increasing volumes in the Natural Gas Gathering and Processing and Natural Gas Liquids segments and contract renegotiations that we expect will provide increasing margins in the Natural Gas Gathering and Processing segment. See discussion under “Short-term Liquidity” and “Long-term Financing” for more information.

Cash Management - We and ONEOK Partners each use similar centralized cash management programs that concentrate the cash assets of our operating subsidiaries in joint accounts for the purposes of providing financial flexibility and lowering the cost of borrowing, transaction costs and bank fees. Both centralized cash management programs provide that funds in excess of the daily needs of the operating subsidiaries are concentrated, consolidated or otherwise made available for use by other entities within the respective consolidated groups. ONEOK Partners’ operating subsidiaries participate in these programs to the extent they are permitted pursuant to FERC regulations or their operating agreements. Under these cash management programs, depending on whether a participating subsidiary has short-term cash surpluses or cash requirements, we and ONEOK Partners provide cash to our respective subsidiaries or the subsidiaries provide cash to us.

Short-term Liquidity - ONEOK’s sources of short-term liquidity are quarterly distributions from ONEOK Partners, cash on hand and access to our $300 million ONEOK Credit Agreement. At September 30, 2015, ONEOK had no short-term debt outstanding.

ONEOK Partners’ principal sources of short-term liquidity consist of cash generated from operating activities, distributions received from its equity method investments and proceeds from its commercial paper program and its “at-the-market” equity program. To the extent commercial paper is unavailable, the ONEOK Partners Credit Agreement may be used.

We had working capital (defined as current assets less current liabilities) deficits of $1.0 billion and $1.1 billion as of September 30, 2015 and December 31, 2014, respectively. ONEOK Partners had working capital deficits of $1.0 billion and $1.3 billion as of September 30, 2015, and December 31, 2014, respectively. Although working capital is influenced by several

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factors, including, among other things, (i) the timing of (a) scheduled debt payments, (b) the collection and payment of accounts receivable and payable, and (c) equity and debt issuances, and (ii) the volume and cost of inventory and commodity imbalances, the consolidated working capital deficit at December 31, 2014, was driven primarily by ONEOK Partners’ capital-growth projects and ONEOK Partners’ November 2014 $800 million acquisition of West Texas LPG, which were initially funded with short-term borrowings under its commercial paper program. ONEOK Partners repaid these amounts outstanding with cash from operations, its March 2015 debt issuance and its August 2015 equity issuances. The consolidated working capital deficit at September 30, 2015, was driven primarily by ONEOK Partners’ capital-growth projects and current maturities of its long-term debt. ONEOK Partners may have working capital deficits in future periods as it continues to finance its capital-growth projects, often initially with short-term borrowings, which we would expect it to repay with proceeds from future issuances of long-term debt, common units or other debt or equity securities. We do not expect this working capital deficit to have an adverse impact to our or ONEOK Partners’ cash flows or operations.

ONEOK Credit Agreement - At September 30, 2015, ONEOK had $1.1 million in letters of credit issued under the ONEOK Credit Agreement and approximately $31.1 million of cash and cash equivalents. ONEOK had approximately $298.9 million of credit available at September 30, 2015, under the ONEOK Credit Agreement.

The ONEOK Credit Agreement is a $300 million revolving credit facility and contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of indebtedness to Consolidated EBITDA (EBITDA, as defined in our ONEOK Credit Agreement) of no more than 4.0 to 1. Upon breach of certain covenants by us in the ONEOK Credit Agreement, amounts outstanding under the ONEOK Credit Agreement, if any, may become due and payable immediately. At September 30, 2015, ONEOK’s ratio of indebtedness to Consolidated EBITDA, was 2.4 to 1, and ONEOK was in compliance with all covenants under the ONEOK Credit Agreement.

The ONEOK Credit Agreement also includes a $50 million sublimit for the issuance of standby letters of credit and a $50 million sublimit for swingline loans. Under the terms of the ONEOK Credit Agreement, ONEOK may request an increase in the size of the facility to an aggregate of $500 million from $300 million by either commitments from new lenders or increased commitments from existing lenders. The ONEOK Credit Agreement contains provisions for an applicable margin rate and an annual facility fee, both of which adjust with changes in our credit rating. Based on our current credit rating, borrowings, if any, will accrue at LIBOR plus 145 basis points, and the annual facility fee is 30 basis points.

ONEOK Partners Credit Agreement - At September 30, 2015, ONEOK Partners had $287.3 million in commercial paper outstanding, $14.0 million in letters of credit issued and no borrowings outstanding under the ONEOK Partners Credit Agreement.  At September 30, 2015, ONEOK Partners had approximately $7.3 million of cash and cash equivalents and approximately $2.1 billion of credit available under the ONEOK Partners Credit Agreement.

The ONEOK Partners Credit Agreement, which is scheduled to expire in January 2019, is a $2.4 billion revolving credit facility and includes a $100 million sublimit for the issuance of standby letters of credit and a $150 million swingline sublimit. The ONEOK Partners Credit Agreement is available for general partnership purposes. During the first quarter 2015, ONEOK Partners increased the size of the ONEOK Partners Credit Agreement and commercial paper program each to $2.4 billion from $1.7 billion. Amounts outstanding under ONEOK Partners’ commercial paper program reduce the borrowing capacity under the ONEOK Partners Credit Agreement.

The ONEOK Partners Credit Agreement contains provisions for an applicable margin rate and an annual facility fee, both of which adjust with changes in ONEOK Partners’ credit rating. Under the terms of the ONEOK Partners Credit Agreement, based on ONEOK Partners’ current credit rating, borrowings, if any, will accrue at LIBOR plus 117.5 basis points, and the annual facility fee is 20 basis points. The ONEOK Partners Credit Agreement is guaranteed fully and unconditionally by the Intermediate Partnership.

The ONEOK Partners Credit Agreement contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of indebtedness to adjusted EBITDA (EBITDA, as defined in the ONEOK Partners Credit Agreement, adjusted for all noncash charges and increased for projected EBITDA from certain lender-approved capital expansion projects) of no more than 5.0 to 1. If ONEOK Partners consummates one or more acquisitions in which the aggregate purchase price is $25 million or more, the allowable ratio of indebtedness to adjusted EBITDA will increase to 5.5 to 1 for the quarter in which the acquisition was completed and the two following quarters. As a result of the West Texas LPG acquisition ONEOK Partners completed in the fourth quarter 2014, the allowable ratio of indebtedness to adjusted EBITDA increased to 5.5 to 1 through the second quarter 2015. If ONEOK Partners were to breach certain covenants in the ONEOK Partners Credit Agreement, amounts outstanding under the ONEOK Partners Credit Agreement, if any, may become due and

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payable immediately. At September 30, 2015, ONEOK Partners’ ratio of indebtedness to adjusted EBITDA was 4.3 to 1, and it was in compliance with all covenants under the ONEOK Partners Credit Agreement.

At September 30, 2015, ONEOK Partners could have issued $1.2 billion of short- and long-term debt to meet its liquidity needs under the most restrictive provisions contained in its various borrowing agreements.

Borrowings under the ONEOK Partners Credit Agreement and ONEOK Partners’ senior notes are nonrecourse to ONEOK, and ONEOK does not guarantee ONEOK Partners’ debt, commercial paper or other similar commitments.

Long-term Financing - We expect ONEOK Partners to fund its longer-term cash requirements by issuing common units or long-term notes. Other options to obtain financing include, but are not limited to, issuance of convertible debt securities, asset securitization and the sale and lease-back of facilities.

ONEOK Partners’ ability to obtain financing is subject to changes in the debt and equity markets, and there is no assurance it will be able or willing to access the public or private markets in the future. ONEOK Partners may choose to meet its cash requirements by utilizing some combination of cash flows from operations, borrowing under its commercial paper program or the ONEOK Partners Credit Agreement, altering the timing of controllable expenditures, restricting future acquisitions and capital projects, selling assets or pursuing other debt or equity financing alternatives. Some of these alternatives could result in higher costs or negatively affect its respective credit ratings, among other factors. Based on ONEOK Partners’ general financial condition, expectations regarding its future earnings and projected cash flows and ONEOK Partners’ investment-grade credit ratings, we expect ONEOK Partners will be able to meet its cash requirements and maintain investment-grade credit ratings.

ONEOK Debt Issuance - In August 2015, we completed an underwritten public offering of $500 million of senior notes, 7.5 percent senior notes due 2023. The net proceeds, after deducting underwriting discounts, commissions and other expenses, were approximately $487.1 million. We used the proceeds together with cash on hand to purchase $650 million of additional common units from ONEOK Partners.

ONEOK Debt Repayment - In February 2014, we retired approximately $152.5 million, excluding accrued and unpaid interest, of our 4.25 percent senior notes due 2022 through a tender offer. The total amount paid, including fees and other charges, was approximately $150.0 million.

In February 2014, we called our $400 million, 5.2 percent senior notes due in 2015. The full repayment occurred in March 2014 and was $430.1 million, including accrued but unpaid interest to the redemption date.

In the first quarter 2014, we recorded a loss on extinguishment of $24.8 million related to the early retirement of long-term debt, which is included in other expense in our Consolidated Statements of Income. We also reclassified a loss of $4.6 million, net of tax of $3.1 million, from accumulated other comprehensive income (loss) for terminated cash flow hedges related to the debt retirements, which is included in interest expense in our Consolidated Statements of Income.

ONEOK Partners Debt Issuance - In March 2015, ONEOK Partners completed an underwritten public offering of $800 million of senior notes, consisting of $300 million, 3.8 percent senior notes due 2020 and $500 million, 4.9 percent senior notes due 2025. The net proceeds, after deducting underwriting discounts, commissions and offering expenses, were approximately $792.3 million. ONEOK Partners used the proceeds to repay amounts outstanding under its commercial paper program and for general partnership purposes.

ONEOK Partners Debt Maturity - ONEOK Partners’ $650 million, 3.25 percent senior notes mature on February 1, 2016. The carrying amount of these notes is reflected in the current portion of long-term debt on our Consolidated Balance Sheet as of September 30, 2015. We expect ONEOK Partners to refinance this debt.

ONEOK Partners Equity Issuances - In August 2015, ONEOK Partners completed a private placement of approximately 21.5 million common units at a price of $30.17 per unit with us. Additionally, ONEOK Partners completed a concurrent sale of approximately 3.3 million common units at a price of $30.17 per unit to funds managed by Kayne Anderson Capital Advisors in a registered direct offering, which were issued through ONEOK Partners’ existing “at-the-market” equity program. The combined offerings generated net cash proceeds of approximately $749 million to ONEOK Partners. In conjunction with these issuances, ONEOK Partners GP contributed approximately $15.3 million in order to maintain our 2 percent general partner interest in ONEOK Partners. ONEOK Partners used the proceeds for general partnership purposes, including capital expenditures and repayment of commercial paper borrowings. No other units were sold through the “at-the-market” program during the three months ended September 30, 2015.

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ONEOK Partners has an “at-the-market” equity program for the offer and sale from time to time of its common units, up to an aggregate amount of $650 million. The program allows ONEOK Partners to offer and sell its common units at prices it deems appropriate through a sales agent. Sales of common units are made by means of ordinary brokers’ transactions on the NYSE, in block transactions or as otherwise agreed to between ONEOK Partners and the sales agent. ONEOK Partners is under no obligation to offer and sell common units under the program. At September 30, 2015, ONEOK Partners had approximately $138 million of registered common units available for issuance through its “at-the-market” equity program.

During the nine months ended September 30, 2015, ONEOK Partners sold approximately 10.5 million common units through its “at-the-market” equity program, including the units sold to funds managed by Kayne Anderson Capital Advisors in the registered direct offering discussed above. The gross proceeds, including ONEOK Partners GP’s contributions to maintain our 2 percent general partner interest in ONEOK Partners, were approximately $384.4 million. Net cash proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, were approximately $381.6 million, which were used for general partnership purposes, including repayment of commercial paper borrowings.

As a result of these transactions, our aggregate ownership interest in ONEOK Partners increased to 41.2 percent at September 30, 2015, from 37.8 percent at December 31, 2014.

In May 2014, ONEOK Partners completed an underwritten public offering of approximately 13.9 million common units at a public offering price of $52.94 per common unit, generating net proceeds of approximately $714.5 million. In conjunction with this issuance, ONEOK Partners GP contributed approximately $15.0 million in order to maintain its 2 percent general partner interest in ONEOK Partners. The proceeds were used for general partnership purposes, including capital expenditures and repayment of commercial paper borrowings.

During the three months ended September 30, 2014, ONEOK Partners sold approximately 1.4 million common units through its “at-the-market” equity program. Net cash proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, were approximately $81.3 million, which were used for general partnership purposes.

During the nine months ended September 30, 2014, ONEOK Partners sold approximately 4.4 million common units through its “at-the-market” equity program. Net cash proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, were approximately $245.4 million, which were used for general partnership purposes.

Interest-rate Swaps - ONEOK Partners has entered into forward-starting interest-rate swaps to hedge the variability of interest payments on a portion of forecasted debt issuances that may result from changes in the benchmark interest rate before the debt is issued. Upon ONEOK Partners’ debt issuance in March 2015, ONEOK Partners paid $55.1 million to settle $500 million of its interest-rate swaps. At September 30, 2015, ONEOK Partners had forward-starting interest-rate swaps with notional amounts totaling $400 million that were designated as cash flow hedges and have settlement dates of less than 12 months.

Capital Expenditures - ONEOK Partners’ capital expenditures are financed typically through operating cash flows, short- and long-term debt and the issuance of equity. Consolidated capital expenditures were $930.3 million and $1.2 billion for the nine months ending September 30, 2015 and 2014, respectively. Of these amounts, ONEOK Partners’ capital expenditures were $928.9 million and $1.2 billion for the nine months ended September 30, 2015 and 2014, respectively.

The following table sets forth ONEOK Partners’ 2015 projected capital expenditures, excluding acquisitions, contributions to its equity method investments, and AFUDC:

2015 Projected Capital Expenditures
	(Millions of dollars)
Natural Gas Gathering and Processing	$	820
Natural Gas Liquids	245
Natural Gas Pipelines	75
Other	15
Total projected capital expenditures	$	1,155

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Credit Ratings - Our long-term debt credit ratings are shown in the table below:

	ONEOK		ONEOK Partners
Rating Agency	Rating	Outlook	Rating	Outlook
Moody’s	Ba1	Stable	Baa2	Negative
S&P	BB+	Negative	BBB	Negative

In connection with our August 2015 $500 million notes offering, Moody’s downgraded ONEOK’s rating to Ba1 and S&P affirmed ONEOK’s rating but revised our outlook to negative from stable. In August 2015, Moody’s and S&P affirmed ONEOK Partners’ current credit ratings and revised its outlook to negative from stable.

ONEOK Partners’ commercial paper program is rated Prime-2 by Moody’s and A-2 by S&P. ONEOK Partners’ credit ratings, which are currently investment grade, may be affected by a material change in financial ratios or a material event affecting its business and industry. The most common criteria for assessment of ONEOK Partners’ credit ratings are the debt-to-EBITDA ratio, interest coverage, business risk profile and liquidity.

Recent declines in the energy commodity price environment and its impact on ONEOK Partners’ results of operations and cash flows could cause the credit rating agencies to downgrade its credit ratings. If ONEOK Partners’ credit ratings were downgraded, the cost to borrow funds under its commercial paper program and the ONEOK Partners Credit Agreement would increase, or ONEOK Partners could potentially lose access to the commercial paper market. In the event that ONEOK Partners is unable to borrow funds under its commercial paper program and there has not been a material adverse change in its business, ONEOK Partners would continue to have access to the ONEOK Partners Credit Agreement, which expires in January 2019. An adverse credit rating change alone is not a default under the ONEOK Credit Agreement or the ONEOK Partners Credit Agreement. A downgrade in ONEOK Partners’ credit ratings could also result in a downgrade to ONEOK’s credit ratings. However, we would not expect a downgrade to our credit ratings to have a material impact on our results of operations.

In the normal course of business, ONEOK Partners’ counterparties provide secured and unsecured credit.  In the event of a downgrade in ONEOK Partners’ credit ratings or a significant change in ONEOK Partners’ counterparties’ evaluation of its creditworthiness, ONEOK Partners could be required to provide additional collateral in the form of cash, letters of credit or other negotiable instruments as a condition of continuing to conduct business with such counterparties. ONEOK Partners may be required to fund margin requirements with its counterparties with cash, letters of credit or other negotiable instruments. There were no financial derivative instruments with contingent features related to credit risk that were in a net liability position at September 30, 2015.

ONEOK Partners Cash Distributions - ONEOK Partners distributes 100 percent of its available cash, as defined in its Partnership Agreement that generally consists of all cash receipts less adjustments for cash disbursements and net change to reserves, to its general and limited partners. Distributions are allocated to the general partner and limited partners according to their partnership percentages of 2 percent and 98 percent, respectively. The effect of any incremental allocations for incentive distributions to the general partner is calculated after the allocation to the general partner’s partnership interest and before the allocation to the limited partners.

Energy Commodity Prices - ONEOK Partners is subject to commodity price volatility. Significant fluctuations in commodity prices will affect its overall liquidity due to the impact commodity price changes have on its cash flows from operating activities, including the impact on working capital for NGLs and natural gas held in storage, margin requirements and certain energy-related receivables. The decline in commodity prices and reductions in ONEOK Partners’ volume growth outlook have contributed to a decrease in its unit price. While lower commodity prices and industry uncertainty may increase debt and equity financing costs, we expect ONEOK Partners to have sufficient liquidity to finance its announced capital-growth projects. We believe that its available credit and cash and cash equivalents are adequate to meet liquidity requirements associated with commodity price volatility. See Note E of the Notes to Consolidated Financial Statements and the discussion under Natural Gas Gathering and Processing’s “Commodity Price Risk” in Part I, Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations, in this Quarterly Report for information on ONEOK Partners’ hedging activities.

Pension and Postretirement Benefit Plans - Information about our pension and postretirement benefits plans, including anticipated contributions, is included under Note N of the Notes to Consolidated Financial Statements in our Annual Report. See Note K of the Notes to Consolidated Financial Statements in this Quarterly Report for additional information.

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CASH FLOW ANALYSIS

We use the indirect method to prepare our Consolidated Statements of Cash Flows. Under this method, we reconcile net income to cash flows provided by operating activities by adjusting net income for those items that affect net income but do not result in actual cash receipts or payments during the period and for operating cash items that do not impact net income. These reconciling items include depreciation and amortization, allowance for equity funds used during construction, gain or loss on sale of assets, deferred income taxes, equity in net earnings from investments, distributions received from unconsolidated affiliates, share-based compensation expense, other amounts and changes in our assets and liabilities not classified as investing or financing activities.

The following table sets forth the changes in cash flows by operating, investing and financing activities for the periods indicated:

							Variances
	Nine Months Ended						2015 vs. 2014
	September 30,						Increase (Decrease)
	2015			2014
	(Millions of dollars)
Total cash provided by (used in):
Operating activities	$	695.1		$	870.5		$	(175.4	)
Investing activities	(942.1		)	(1,192.1		)	250.0
Financing activities	112.7			324.3			(211.6		)
Change in cash and cash equivalents	(134.3		)	2.7			(137.0		)
Change in cash and cash equivalents included in discontinued operations	(0.1		)	3.1			(3.2		)
Change in cash and cash equivalents included in continuing operations	(134.4		)	5.8			(140.2		)
Cash and cash equivalents at beginning of period	172.8			145.6			27.2
Cash and cash equivalents at end of period	$	38.4		$	151.4		$	(113.0	)

Operating Cash Flows - Operating cash flows are affected by earnings from our business activities. Changes in commodity prices and demand for our services or products, whether because of general economic conditions, changes in supply, changes in demand for the end products that are made with our products or increased competition from other service providers, could affect our earnings and operating cash flows.

Cash flows from operating activities, before changes in operating assets and liabilities, were $814.9 million for the nine months ended September 30, 2015, compared with $884.5 million for the same period in 2014. The decrease is due primarily to a decrease in net margin attributable to lower commodity prices in 2015 and interest expense, offset partially by equity in net earnings from investments, as discussed in “Financial Results and Operating Information.”

The changes in operating assets and liabilities decreased operating cash flows by $119.8 million for the nine months ended September 30, 2015, compared with a decrease of $14.0 million for the same period in 2014. This change is due primarily to the change in accounts receivable and accounts payable resulting from the timing of receipt of cash from customers and payments to vendors and suppliers, which vary from period to period and vary with changes in commodities prices. In the first quarter 2015, ONEOK Partners also paid $55.1 million to settle forward-starting interest-rate swaps in connection with its March 2015 debt offering.

Investing Cash Flows - Cash used in investing activities decreased for the nine months ended September 30, 2015, compared with the same period in 2014, due primarily to ONEOK Partners’ completion of growth projects in 2014 and the timing of capital expenditures for ONEOK Partners’ growth projects in the Natural Gas Gathering and Processing and Natural Gas Liquids segments, offset partially by contributions made to Roadrunner in 2015. ONEOK Partners also had an acquisition in the first quarter 2014 in the Natural Gas Pipelines segment. Additionally, capital expenditures decreased by $23.9 million due to the separation of ONE Gas, which occurred in January 2014.

Financing Cash Flows - Cash provided by financing activities decreased for the nine months ended September 30, 2015, compared with the same period in 2014. This decrease is due primarily to higher dividends paid on our common stock due to increases in the per share dividend as well as increases in distributions to noncontrolling interests related to ONEOK Partners’ unitholders due to increases in the per unit distributions declared and the number of units outstanding. During the nine months ended September 30, 2015, ONEOK Partners raised additional capital of approximately $1.8 billion through both debt and equity issuances, and during the nine months ended September 30, 2014, ONEOK Partners raised additional capital of

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approximately $947 million through equity issuances. During the nine months ended September 30, 2015, we raised approximately $500 million through our August 2015 debt issuance. These increases in financing cash inflows for the nine months ended September 30, 2015, compared with the same period in 2014, were offset by repayment of notes payable and increased distributions paid to noncontrolling interests related to ONEOK Partners’ unitholders. In the first quarter 2014, ONE Gas, which at the time was our consolidated subsidiary, issued $1.2 billion of senior notes, with proceeds of approximately $1.19 billion used to repay ONEOK commercial paper and long-term debt outstanding.

REGULATORY, ENVIRONMENTAL AND SAFETY MATTERS

Environmental Matters -ONEOK Partners is subject to multiple historical preservation, wildlife preservation and environmental laws and/or regulations that affect many aspects of its present and future operations. Regulated activities include, but are not limited to, those involving air emissions, storm water and wastewater discharges, handling and disposal of solid and hazardous wastes, wetlands preservation, hazardous materials transportation, and pipeline and facility construction. These laws and regulations require ONEOK Partners to obtain and/or comply with a wide variety of environmental clearances, registrations, licenses, permits and other approvals. Failure to comply with these laws, regulations, licenses and permits may expose ONEOK Partners to fines, penalties and/or interruptions in its operations that could be material to our results of operations. For example, if a leak or spill of hazardous substances or petroleum products occurs from pipelines or facilities that ONEOK Partners owns, operates or otherwise uses, ONEOK Partners could be held jointly and severally liable for all resulting liabilities, including response, investigation and cleanup costs, which could affect materially our results of operations and cash flows. In addition, emissions controls and/or other regulatory or permitting mandates under the Clean Air Act and other similar federal and state laws could require unexpected capital expenditures at ONEOK Partners’ facilities. We cannot assure that existing environmental statutes and regulations will not be revised or that new regulations will not be adopted or become applicable to ONEOK Partners.

In June 2013, the Executive Office of the President of the United States (the President) issued the President’s Climate Action Plan, which includes, among other things, plans for further regulatory actions to reduce carbon emissions from various sources. On March 28, 2014, the President released the Climate Action Plan - Strategy to Reduce Methane Emissions (Methane Strategy) that lists a number of actions the federal agencies will undertake to continue to reduce above-ground methane emissions from several industries, including the oil and natural gas sectors. The proposed measures outlined in the Methane Strategy include, without limitation, the following: collaboration with the states to encourage emission reductions; standards to minimize natural gas venting and flaring on public lands; policy recommendations for reducing emissions from energy infrastructure to increase the performance of the nation’s energy transmission, storage and distribution systems; and continued efforts by PHMSA to require pipeline operators to take steps to eliminate leaks and prevent accidental methane releases and evaluate the progress of states in replacing cast-iron pipelines. The impact of any such regulatory actions on ONEOK Partners’ facilities and operations is unknown. ONEOK Partners continues to monitor these developments and the impact they may have on its businesses. Revised or additional statutes or regulations that result in increased compliance costs or additional operating restrictions could have a significant impact on our business, financial position, results of operations and cash flows.

Additional information about environmental matters is included in Note N of the Notes to Consolidated Financial Statements in this Quarterly Report.

Pipeline Safety - ONEOK Partners is subject to PHMSA regulations, including pipeline asset integrity-management regulations. The Pipeline Safety Improvement Act of 2002 requires pipeline companies operating high-pressure pipelines to perform integrity assessments on pipeline segments that pass through densely populated areas or near specifically designated high-consequence areas. In January 2012, The Pipeline Safety, Regulatory Certainty and Job Creation Act of 2011 was signed into law. The law increased maximum penalties for violating federal pipeline safety regulations and directs the DOT and Secretary of Transportation to conduct further review or studies on issues that may or may not be material to ONEOK Partners. These issues include, but are not limited to, the following:

• an evaluation on whether hazardous natural gas liquids and natural gas pipeline integrity-management requirements should be expanded beyond current high-consequence areas;

• a review of all natural gas and hazardous natural gas liquids gathering pipeline exemptions;

• a verification of records for pipelines in Class 3 and 4 locations and high-consequence areas to confirm maximum allowable operating pressures; and

• a requirement to test previously untested pipelines operating above 30 percent yield strength in high-consequence areas.

In October 2015, PHMSA issued a notice of proposed rule-making to its hazardous liquid pipeline safety regulations.  Among other things, the proposed regulations would expand the current leak-detection requirements, apply new, more conservative repair criteria and establish timelines for inspecting pipeline facilities potentially affected by an extreme weather event or

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natural disaster.  The proposal would also increase the stringency of integrity management program requirements and set deadlines for the use of internal inspection tools on certain systems.  Comments on the proposed rule-making are currently due by January 2016.  The potential capital and operating expenditures related to the referenced legislation and regulations are unknown, but we do not anticipate a material impact to our planned capital, operations and maintenance costs resulting from compliance with the current or pending regulations.

Air and Water Emissions - The Clean Air Act, the Clean Water Act, analogous state laws and/or regulations promulgated thereunder impose restrictions and controls regarding the discharge of pollutants into the air and water in the United States. Under the Clean Air Act, a federally enforceable operating permit is required for sources of significant air emissions. ONEOK Partners may be required to incur certain capital expenditures for air pollution-control equipment in connection with obtaining or maintaining permits and approvals for sources of air emissions. The Clean Water Act imposes substantial potential liability for the removal of pollutants discharged to waters of the United States and remediation of waters affected by such discharge.

Federal, state and regional initiatives to measure and regulate GHG emissions are underway. ONEOK Partners monitors all relevant federal and state legislation to assess the potential impact on its operations. The EPA’s Mandatory Greenhouse Gas Reporting Rule requires annual GHG emissions reporting from affected facilities and the carbon dioxide emission equivalents for the natural gas delivered by ONEOK Partners and the emission equivalents for all NGLs produced by ONEOK Partners as if all of these products were combusted, even if they are used otherwise.

ONEOK Partners’ 2014 total reported emissions were approximately 45.7 million metric tons of carbon dioxide equivalents. This total includes direct emissions from the combustion of fuel in ONEOK Partners’ equipment, such as compressor engines and heaters, as well as carbon dioxide equivalents from natural gas and NGL products delivered to customers and produced, as if all such fuel and NGL products were combusted. The additional cost to gather and report this emission data did not have, and we do not expect it to have, a material impact on our results of operations, financial position or cash flows. In addition, Congress has considered, and may consider in the future, legislation to reduce GHG emissions, including carbon dioxide and methane. Likewise, the EPA may institute additional regulatory rule-making associated with GHG emissions from the oil and natural gas industry. At this time, no rule or legislation has been enacted that assesses any costs, fees or expenses on any of these emissions.

In April 2014, the EPA and the United States Army Corps of Engineers proposed a joint rule-making to redefine the definition of “Waters of the United States” under the Clean Water Act. The final rule was published on June 29, 2015, and became effective on August 28, 2015. The final rule is not expected to result in material impacts on ONEOK Partners’ projects, facilities and operations.

The EPA’s “Triggering and Tailoring Rules” regulate GHG emissions at new or modified facilities that meet certain criteria. Affected facilities are required to review BACT, conduct air-quality analysis, impact analysis and public reviews with respect to such emissions. At current emission threshold levels, this rule has had a minimal impact on ONEOK Partners’ existing facilities.  In addition, on June 23, 2014, the Supreme Court, in a case styled, Utility Air Regulatory Group v. EPA, 530 U.S. (2014), held that an industrial facility’s potential to emit GHG emissions alone cannot subject a facility to the permitting requirements for major stationary source provisions of the Clean Air Act. The decision invalidated the EPA’s current Triggering and Tailoring Rule for GHG PSD and Title V requirements as applied to facilities considered major sources only for GHGs (referred to as Step 2 sources). However, the Supreme Court also ruled that to the extent a source pursues a capital project (new construction or expansion of existing facility), which otherwise subjects the source to major source PSD permitting for conventional criteria pollutants, the permitting authorities may impose BACT analysis and emission limits for GHGs from those sources.

In April 2015, the United States Court of Appeals for the District of Columbia Circuit (D.C. Circuit), on remand from the Supreme Court, issued its further Order following the Supreme Court’s decision in Utility Air Regulatory Group v. EPA. The D.C. Circuit’s Order included the following: (1) it formally vacated EPA regulations implementing the Tailoring Rule to the extent that they require a stationary source to obtain a PSD or Title V permit based solely on the source’s GHG emissions; and (2) ordered the EPA to consider whether any further revisions to its regulations are appropriate in light of the Supreme Court’s decision.On April 30, 2015, the EPA issued a direct final rule to allow for the rescission of Clean Air Act PSD permits issued by the EPA or delegated state and local permitting authorities under Step 2 of the GHG Tailoring Rule. The direct final rule was to become effective unless adverse comments were received by the EPA. On August 19, 2015, the EPA published the direct final rule in the Federal Register to confirm that no adverse comments were received and that the rule was now in effect. We do not expect the direct final rule to have a material impact on our existing operations or design decisions for new project applications.

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In July 2011, the EPA issued a proposed rule that would change the air emissions New Source Performance Standards, also known as NSPS, and Maximum Achievable Control Technology requirements applicable to the oil and natural gas industry, including natural gas production, processing, transmission and underground storage sectors. In April 2012, the EPA released the final rule, which includes new NSPS and air toxic standards for a variety of sources within natural gas processing plants, oil and natural gas production facilities and natural gas transmission stations. The rule also regulates emissions from the hydraulic fracturing of wells for the first time. The NSPS final rule became effective in October 2012, but the dates for compliance vary and depend in part upon the type of affected facility and the date of construction, reconstruction or modification.

In September 2015, the EPA published several proposed rule-makings in the Federal Register that affect the oil and gas industry. The rule-makings included, but were not limited to, proposed amendments to the NSPS rule. The proposed amendments to the NSPS rule included, in part, the proposed direct regulation of methane emissions for the first time as an individual air pollutant from oil and gas sources, as part of the President’s Methane Strategy. Comments on the proposed rule-makings remain ongoing.

In October 2015, the EPA issued a prepublication version of a final rule-making to amend downward the NAAQS for ground level ozone. The final rule requires revised designations of the areas in the various states for classification as in attainment or nonattainment for the new ozone NAAQS. Any areas determined to not attain the ozone NAAQS will implicate more strict air permitting requirements for new or modified sources that emit pollutants that contribute to ground level ozone.

At this time we do not anticipate a material impact to our planned capital, operations and maintenance costs resulting from compliance with the current or pending regulations outlined above. However, the EPA may issue additional responses, amendments and/or policy guidance on the final rules, which could alter our present expectations. Generally, the EPA rule-makings will require expenditures for updated emissions controls, monitoring and record-keeping requirements at affected facilities. We do not expect these expenditures will have a material impact on our results of operations, financial position or cash flows.

CERCLA - The federal Comprehensive Environmental Response, Compensation and Liability Act (CERCLA), also commonly known as Superfund, imposes strict, joint and several liability, without regard to fault or the legality of the original act, on certain classes of “persons” (defined under CERCLA) who caused and/or contributed to the release of a hazardous substance into the environment. These persons include, but are not limited to, the owner or operator of a facility where the release occurred and/or companies that disposed or arranged for the disposal of the hazardous substances found at the facility. Under CERCLA, these persons may be liable for the costs of cleaning up the hazardous substances released into the environment, damages to natural resources and the costs of certain health studies. We do not expect ONEOK Partners’ responsibilities under CERCLA will have a material impact on our results of operations, financial position or cash flows.

Chemical Site Security - The United States Department of Homeland Security (Homeland Security) released the Chemical Facility Anti-Terrorism Standards in 2007, and the new final rule associated with these regulations was issued in December 2014. ONEOK Partners provided information regarding its chemicals via Top-Screens submitted to Homeland Security, and its facilities subsequently were assigned one of four risk-based tiers ranging from high (Tier 1) to low (Tier 4) risk, or not tiered at all due to low risk. To date, four of its facilities have been given a Tier 4 rating. Facilities receiving a Tier 4 rating are required to complete Site Security Plans and possible physical security enhancements. We do not expect the Site Security Plans and possible security enhancement costs to have a material impact on our results of operations, financial position or cash flows.

Pipeline Security - The United States Department of Homeland Security’s Transportation Security Administration and the DOT have completed a review and inspection of ONEOK Partners’ “critical facilities” and identified no material security issues. Also, the Transportation Security Administration has released new pipeline security guidelines that include broader definitions for the determination of pipeline “critical facilities.” ONEOK Partners has reviewed its pipeline facilities according to the new guideline requirements, and there have been no material changes required to date.

Environmental Footprint - ONEOK Partners’ environmental and climate change strategy focuses on minimizing the impact of its operations on the environment. These strategies include: (i) developing and maintaining an accurate GHG emissions inventory according to current rules issued by the EPA; (ii) improving the efficiency of its various pipelines, natural gas processing facilities and natural gas liquids fractionation facilities; (iii) following developing technologies for emissions control and the capture of carbon dioxide to keep it from reaching the atmosphere; and (iv) utilizing practices to reduce the loss of methane from its facilities.

ONEOK Partners participates in the EPA’s Natural Gas STAR Program to reduce voluntarily methane emissions. ONEOK Partners continues to focus on maintaining low rates of lost-and-unaccounted-for methane gas through expanded implementation of best practices to limit the release of natural gas during pipeline and facility maintenance and operations.

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IMPACT OF NEW ACCOUNTING STANDARDS

See Note A of the Notes to Consolidated Financial Statements in this Quarterly Report for discussion of new accounting standards.

ESTIMATES AND CRITICAL ACCOUNTING POLICIES

The preparation of our consolidated financial statements and related disclosures in accordance with GAAP requires us to make estimates and assumptions with respect to values or conditions that cannot be known with certainty that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the consolidated financial statements. These estimates and assumptions also affect the reported amounts of revenue and expenses during the reporting period. Although we believe these estimates and assumptions are reasonable, actual results could differ from our estimates.

Information about our estimates and critical accounting policies is included under Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations, “Estimates and Critical Accounting Policies,” in our Annual Report.

FORWARD-LOOKING STATEMENTS

Some of the statements contained and incorporated in this Quarterly Report are forward-looking statements as defined under federal securities laws. The forward-looking statements relate to our anticipated financial performance (including projected operating income, net income, capital expenditures, cash flow and projected levels of dividends and distributions), liquidity, management’s plans and objectives for our future growth projects and other future operations (including plans to construct additional natural gas and natural gas liquids pipelines and processing facilities and related cost estimates), our business prospects, the outcome of regulatory and legal proceedings, market conditions and other matters. We make these forward-looking statements in reliance on the safe harbor protections provided under federal securities legislation and other applicable laws. The following discussion is intended to identify important factors that could cause future outcomes to differ materially from those set forth in the forward-looking statements.

Forward-looking statements include the items identified in the preceding paragraph, the information concerning possible or assumed future results of our operations and other statements contained or incorporated in this Quarterly Report identified by words such as “anticipate,” “estimate,” “expect,” “project,” “intend,” “plan,” “believe,” “should,” “goal,” “forecast,” “guidance,” “could,” “may,” “continue,” “might,” “potential,” “scheduled” and other words and terms of similar meaning.

One should not place undue reliance on forward-looking statements. Known and unknown risks, uncertainties and other factors may cause our actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by forward-looking statements. Those factors may affect our operations, markets, products, services and prices. In addition to any assumptions and other factors referred to specifically in connection with the forward-looking statements, factors that could cause our actual results to differ materially from those contemplated in any forward-looking statement include, among others, the following:

• the effects of weather and other natural phenomena, including climate change, on our operations, demand for our services and energy prices;

• competition from other United States and foreign energy suppliers and transporters, as well as alternative forms of energy, including, but not limited to, solar power, wind power, geothermal energy and biofuels such as ethanol and biodiesel;

• the capital intensive nature of our businesses;

• the profitability of assets or businesses acquired or constructed by us;

• our ability to make cost-saving changes in operations;

• risks of marketing, trading and hedging activities, including the risks of changes in energy prices or the financial condition of our counterparties;

• the uncertainty of estimates, including accruals and costs of environmental remediation;

• the timing and extent of changes in energy commodity prices;

• the effects of changes in governmental policies and regulatory actions, including changes with respect to income and other taxes, pipeline safety, environmental compliance, climate change initiatives and authorized rates of recovery of natural gas and natural gas transportation costs;

• the impact on drilling and production by factors beyond our control, including the demand for natural gas and crude oil; producers’ desire and ability to obtain necessary permits; reserve performance; and capacity constraints on the pipelines that transport crude oil, natural gas and NGLs from producing areas and our facilities;

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• difficulties or delays experienced by trucks, railroads or pipelines in delivering products to or from our terminals or pipelines;

• changes in demand for the use of natural gas, NGLs and crude oil because of market conditions caused by concerns about climate change;

• the impact of unforeseen changes in interest rates, equity markets, inflation rates, economic recession and other external factors over which we have no control, including the effect on pension and postretirement expense and funding resulting from changes in stock and bond market returns;

• our indebtedness could make us vulnerable to general adverse economic and industry conditions, limit our ability to borrow additional funds and/or place us at competitive disadvantages compared with our competitors that have less debt, or have other adverse consequences;

• actions by rating agencies concerning the credit ratings of ONEOK and ONEOK Partners;

• the results of administrative proceedings and litigation, regulatory actions, rule changes and receipt of expected clearances involving any local, state or federal regulatory body, including the FERC, the National Transportation Safety Board, the PHMSA, the EPA and CFTC;

• our ability to access capital at competitive rates or on terms acceptable to us;

• risks associated with adequate supply to our gathering, processing, fractionation and pipeline facilities, including production declines that outpace new drilling or extended periods of ethane rejection;

• the risk that material weaknesses or significant deficiencies in our internal controls over financial reporting could emerge or that minor problems could become significant;

• the impact and outcome of pending and future litigation;

• the ability to market pipeline capacity on favorable terms, including the effects of:

– future demand for and prices of natural gas, NGLs and crude oil;

– competitive conditions in the overall energy market;

– availability of supplies of Canadian and United States natural gas and crude oil; and

– availability of additional storage capacity;

• performance of contractual obligations by our customers, service providers, contractors and shippers;

• the timely receipt of approval by applicable governmental entities for construction and operation of our pipeline and other projects and required regulatory clearances;

• our ability to acquire all necessary permits, consents or other approvals in a timely manner, to promptly obtain all necessary materials and supplies required for construction, and to construct gathering, processing, storage, fractionation and transportation facilities without labor or contractor problems;

• the mechanical integrity of facilities operated;

• demand for our services in the proximity of our facilities;

• our ability to control operating costs;

• acts of nature, sabotage, terrorism or other similar acts that cause damage to our facilities or our suppliers’ or shippers’ facilities;

• economic climate and growth in the geographic areas in which we do business;

• the risk of a prolonged slowdown in growth or decline in the United States or international economies, including liquidity risks in United States or foreign credit markets;

• the impact of recently issued and future accounting updates and other changes in accounting policies;

• the possibility of future terrorist attacks or the possibility or occurrence of an outbreak of, or changes in, hostilities or changes in the political conditions in the Middle East and elsewhere;

• the risk of increased costs for insurance premiums, security or other items as a consequence of terrorist attacks;

• risks associated with pending or possible acquisitions and dispositions, including our ability to finance or integrate any such acquisitions and any regulatory delay or conditions imposed by regulatory bodies in connection with any such acquisitions and dispositions;

• the impact of uncontracted capacity in our assets being greater or less than expected;

• the ability to recover operating costs and amounts equivalent to income taxes, costs of property, plant and equipment and regulatory assets in our state and FERC-regulated rates;

• the composition and quality of the natural gas and NGLs we gather and process in our plants and transport on our pipelines;

• the efficiency of our plants in processing natural gas and extracting and fractionating NGLs;

• the impact of potential impairment charges;

• the risk inherent in the use of information systems in our respective businesses, implementation of new software and hardware, and the impact on the timeliness of information for financial reporting;

• our ability to control construction costs and completion schedules of our pipelines and other projects; and

• the risk factors listed in the reports we have filed and may file with the SEC, which are incorporated by reference.

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These factors are not necessarily all of the important factors that could cause actual results to differ materially from those expressed in any of our forward-looking statements. Other factors could also have material adverse effects on our future results. These and other risks are described in greater detail in Part I, Item 1A, Risk Factors, in our most recent Annual Report on Form 10-K and in our other filings that we make with the SEC, which are available via the SEC’s website at www.sec.gov and our website at www.oneok.com. All forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these factors. Any such forward-looking statement speaks only as of the date on which such statement is made, and other than as required under securities laws, we undertake no obligation to update publicly any forward-looking statement whether as a result of new information, subsequent events or change in circumstances, expectations or otherwise.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Our quantitative and qualitative disclosures about market risk for ONEOK Partners are consistent with those discussed in Part II, Item 7A, Quantitative and Qualitative Disclosures About Market Risk, in our Annual Report.

COMMODITY PRICE RISK

See Note E of the Notes to Consolidated Financial Statements and the discussion under Natural Gas Gathering and Processing’s “Commodity Price Risk” in Part I, Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations, in this Quarterly Report for information on our hedging activities.

INTEREST-RATE RISK

We and ONEOK Partners are subject to the risk of interest-rate fluctuation in the normal course of business. We and ONEOK Partners manage interest-rate risk through the use of fixed-rate debt, floating-rate debt and interest-rate swaps. Interest-rate swaps are agreements to exchange interest payments at some future point based on specified notional amounts. At September 30, 2015, and December 31, 2014, ONEOK Partners had forward-starting interest-rate swaps with notional amounts totaling $400 million and $900 million, respectively, that have been designated as cash flow hedges of the variability of interest payments on a portion of a forecasted debt issuance that may result from changes in the benchmark interest rate before the debt is issued. The interest rate on all of our and ONEOK Partners’ long-term debt was fixed. Future issuances of long-term debt could be affected by changes in interest rates, which could result in higher interest costs. At September 30, 2015, ONEOK Partners had no derivative assets and $13.6 million of derivative liabilities related to these interest-rate swaps. At December 31, 2014, ONEOK Partners had derivative assets of $2.3 million and derivative liabilities of $44.8 million related to these interest-rate swaps.

COUNTERPARTY CREDIT RISK

ONEOK and ONEOK Partners assess the creditworthiness of their counterparties on an ongoing basis and require security, including prepayments and other forms of collateral, when appropriate. ONEOK Partners is not exposed to material credit risk with exploration and production customers under POP contracts in the Natural Gas Gathering and Processing segment due to the nature of the POP contracts whereby it receives proceeds from the sale of commodities and remits a portion of those proceeds back to the crude oil and natural gas producers. Certain of ONEOK Partners’ counterparties to the Natural Gas Gathering and Processing segment’s natural gas sales, the Natural Gas Liquids segment’s marketing activities and the Natural Gas Pipelines segment’s storage activities may be impacted by the depressed commodity price environment and could experience financial problems, which could result in nonpayment and/or nonperformance, which could adversely impact our results of operations. The majority of the Natural Gas Liquids segment’s and Natural Gas Pipeline segment’s pipeline tariffs provide ONEOK Partners the ability to require security from shippers. ONEOK Partners’ remaining customers are primarily large local distribution, power generation and petrochemical companies.

ITEM 4. CONTROLS AND PROCEDURES

Quarterly Evaluation of Disclosure Controls and Procedures - Our Chief Executive Officer (Principal Executive Officer) and Chief Financial Officer (Principal Financial Officer) have concluded that our disclosure controls and procedures were effective as of the end of the period covered by this report based on the evaluation of the controls and procedures required by Rules 13a-15(b) of the Exchange Act.

Changes in Internal Control Over Financial Reporting - There have been no changes in our internal control over financial reporting during the quarter ended September 30, 2015, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II - OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

Information about our legal proceedings is provided in Note N, “Legal Proceedings” of the Notes to Consolidated Financial Statements under Part I, Item 1 of this Quarterly Report. Additional information about our legal proceedings is included under Part 1, Item 3, Legal Proceedings, in our Annual Report.

ITEM 1A. RISK FACTORS

Our investors should consider the risks set forth in Part I, Item 1A, Risk Factors, of our Annual Report that could affect us and our business. Although we have tried to discuss key factors, our investors need to be aware that other risks may prove to be important in the future. New risks may emerge at any time, and we cannot predict such risks or estimate the extent to which they may affect our financial performance. Investors should carefully consider the discussion of risks and the other information included or incorporated by reference in this Quarterly Report, including “Forward-Looking Statements,” which are included in Part I, Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Not Applicable.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

Not Applicable.

ITEM 4. MINE SAFETY DISCLOSURES

Not Applicable.

ITEM 5. OTHER INFORMATION

Not Applicable.

ITEM 6. EXHIBITS

Readers of this report should not rely on or assume the accuracy of any representation or warranty or the validity of any opinion contained in any agreement filed as an exhibit to this Quarterly Report, because such representation, warranty or opinion may be subject to exceptions and qualifications contained in separate disclosure schedules, may represent an allocation of risk between parties in the particular transaction, may be qualified by materiality standards that differ from what may be viewed as material for securities law purposes, or may no longer continue to be true as of any given date. All exhibits attached to this Quarterly Report are included for the purpose of complying with requirements of the SEC. Other than the certifications made by our officers pursuant to the Sarbanes-Oxley Act of 2002 included as exhibits to this Quarterly Report, all exhibits are included only to provide information to investors regarding their respective terms and should not be relied upon as constituting or providing any factual disclosures about us, any other persons, any state of affairs or other matters.

The following exhibits are filed as part of this Quarterly Report:

Exhibit No. Exhibit Description

4.1 Indenture, dated January 26, 2012, between ONEOK, Inc. and U.S. Bank National Association, as trustee (incorporated by reference to Exhibit 4.1 to ONEOK, Inc.’s Current Report on Form 8-K filed on January 26, 2012).

4.2 Second Supplemental Indenture, dated as of August 21, 2015, between ONEOK, Inc. and U.S. Bank National Association, as trustee, with respect to the 7.50% Notes due 2023 (incorporated by reference to Exhibit 4.1 to ONEOK, Inc.’s Current Report on Form 8-K filed on August 21, 2015).

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10.1 Common Unit Purchase Agreement dated August 11, 2015, between ONEOK Partners, L.P. and ONEOK, Inc. (incorporated by reference to Exhibit 1.1 to ONEOK, Inc.’s Current Report on Form 8-K filed on August 17, 2015).

10.2 Underwriting Agreement dated August 18, 2015, between ONEOK, Inc. and Citigroup Global Markets, Inc., as representative of the several underwriters named therein (incorporated by reference to Exhibit 1.1 to ONEOK, Inc.’s Current Report on Form 8-K filed on August 21, 2015).

31.1 Certification of Terry K. Spencer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2 Certification of Derek S. Reiners pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1 Certification of Terry K. Spencer pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (furnished only pursuant to Rule 13a-14(b)).

32.2 Certification of Derek S. Reiners pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (furnished only pursuant to Rule 13a-14(b)).

99.1 Common Unit Purchase Agreement dated August 11, 2015, between ONEOK Partners, L.P. and Kayne Anderson MLP Investment Company, Kayne Anderson Energy Total Return Fund, Inc., Kayne Anderson Midstream/Energy Fund, Inc., Kayne Anderson Energy Development Company, KA First Reserve, LLC, Nationwide Mutual Insurance Company, Massachusetts Mutual Life Insurance Company, Kayne Anderson MLP Fund, L.P., Kayne Anderson Midstream Institutional Fund, L.P., Kayne Anderson Real Assets Fund, L.P., Kayne Institutional Energy Growth & Income Fund, L.P., Kayne Anderson Capital Income Partners (QP), L.P., Kayne Anderson Income Partners, L.P., KANTI (QP), L.P., Kayne Anderson Non-Traditional Investments, L.P., KARBO, L.P. and Kaiser Foundation Hospitals (incorporated by reference to Exhibit 99.1 to ONEOK Partners, L.P.’s Current Report on Form 8-K filed on August 17, 2015).

101.INS XBRL Instance Document.

101.SCH XBRL Taxonomy Extension Schema Document.

101.CAL XBRL Taxonomy Calculation Linkbase Document.

101.DEF XBRL Taxonomy Extension Definitions Document.

101.LAB XBRL Taxonomy Label Linkbase Document.

101.PRE XBRL Taxonomy Presentation Linkbase Document.

Attached as Exhibit 101 to this Quarterly Report are the following XBRL-related documents:  (i) Document and Entity Information; (ii) Consolidated Statements of Income for the three and nine months ended September 30, 2015 and 2014; (iii) Consolidated Statements of Comprehensive Income for the three and nine months ended September 30, 2015 and 2014; (iv) Consolidated Balance Sheets at September 30, 2015, and December 31, 2014; (v) Consolidated Statements of Cash Flows for the nine months ended September 30, 2015 and 2014; (vi) Consolidated Statement of Changes in Equity for the nine months ended September 30, 2015 and 2014; and (vii) Notes to Consolidated Financial Statements.

We also make available on our website the Interactive Data Files submitted as Exhibit 101 to this Quarterly Report.

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SIGNATURE

Pursuant to the requirements of the Exchange Act, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

	ONEOK, Inc.
	Registrant
Date: November 4, 2015	By:	/s/ Derek S. Reiners
		Derek S. Reiners
		Senior Vice President,
		Chief Financial Officer and Treasurer
		(Principal Financial Officer)

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EX-31.1

Exhibit 31.1

Certification

I, Terry K. Spencer, certify that:

I have reviewed this quarterly report on Form 10-Q of ONEOK, Inc.;

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors:

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: November 4, 2015

/s/ Terry K. Spencer

Terry K. Spencer

Chief Executive Officer

EX-31.2

Exhibit 31.2

Certification

I, Derek S. Reiners, certify that:

I have reviewed this quarterly report on Form 10-Q of ONEOK, Inc.;

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors:

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: November 4, 2015

/s/ Derek S. Reiners

Derek S. Reiners

Chief Financial Officer

EX-32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of ONEOK, Inc. (the “Registrant”) for the period ending September 30, 2015, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Terry K. Spencer, Chief Executive Officer of the Registrant, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) the Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Registrant.

/s/ Terry K. Spencer

Terry K. Spencer

Chief Executive Officer

November 4, 2015

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to ONEOK, Inc. and will be retained by ONEOK, Inc. and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.2

Exhibit 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of ONEOK, Inc. (the “Registrant”) for the period ending September 30, 2015, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Derek S. Reiners, Chief Financial Officer of the Registrant, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) the Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Registrant.

/s/ Derek S. Reiners

Derek S. Reiners

Chief Financial Officer

November 4, 2015

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to ONEOK, Inc. and will be retained by ONEOK, Inc. and furnished to the Securities and Exchange Commission or its staff upon request.

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UNCONSOLIDATED AFFILIATES (Tables)

9 Months Ended

Sep. 30, 2015

Equity In Net Earnings From Investments [Member]

Schedule of Equity Method Investments [Line Items]

Equity in Net Earnings from Investments

The following table sets forth ONEOK Partners’ equity in net earnings from investments for the periods indicated:

	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2015		2014			2015		2014
	(Thousands of dollars)
Share of investee earnings
Northern Border Pipeline	$	16,156	$	14,371		$	51,131	$	53,657
Overland Pass Pipeline Company	10,538		3,856			27,048		12,708
Other (a)	5,550		(17,153		)	15,026		(6,197		)
Total share of investee earnings	32,244		1,074			93,205		60,168
Impairment of investment in Bighorn Gas Gathering	—		(53,421		)	—		(53,421		)
Equity in net earnings (loss) from investments	$	32,244	$	(52,347	)	$	93,205	$	6,747

(a) - Includes proportionate share of investee impairment of long-lived assets charge on Bighorn Gas Gathering of $23.0 million for the three and nine months ended September 30, 2014.

Summarized Financial Information Of Unconsolidated Affiliates [Member]

Schedule of Equity Method Investments [Line Items]

Equity in Net Earnings from Investments

The following table sets forth summarized combined financial information of ONEOK Partners’ unconsolidated affiliates for the periods indicated:

	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2015		2014			2015		2014
	(Thousands of dollars)
Income Statement
Operating revenues	$	135,474	$	126,218		$	390,793	$	403,006
Operating expenses (a)	$	64,786	$	123,620		$	178,324	$	247,169
Net income (loss) (a)	$	67,121	$	(5,119	)	$	196,123	$	134,432
Distributions paid to ONEOK Partners	$	36,370	$	31,574		$	117,153	$	109,223

(a) - Includes long-lived asset impairment charge on Bighorn Gas Gathering for the three and nine months ended September 30, 2014.

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	$ (43,473)		$ (43,473)		$ (37,349)
Accumulated Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	0		0		955
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	(92,639)		(92,639)		(99,959)
Accumulated Other Comprehensive Income (Loss), Net of Tax	(136,112)		(136,112)		$ (136,353)
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net			3,661
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, before Reclassification Adjustments, Net of Tax			(955)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, before Reclassification Adjustments, Net of Tax			65
Other comprehensive income (loss) before reclassifications			2,771
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	(15,259)	$ 3,132	(35,530)	$ 48,170
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI for Sale of Securities, Net of Tax			0
Other Comprehensive Income (Loss), Reclassification Adjustment included in Net Income, Net of Tax	(2,691)	3,389	(2,530)	31,744
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax, Portion Attributable to Parent			(6,124)
Other Comprehensive Income (Loss), Unrealized Holding Gain (Loss) on Securities Arising During Period, Net of Tax	0	107	(955)	(6)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	2,441	2,185	7,320	8,069
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent			241
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Tax	2,957	(748)	5,621	(14,996)
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	(5,109)	1,204	(9,785)	23,596
Accumulated Defined Benefit Plans Adjustment [Member]
Other Comprehensive (Income) Loss, Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, Net of Tax	2,418	2,185	7,255	8,148
Defined Benefit Plan, Future Amortization of Gain (Loss)	4,422	4,009	13,268	11,936
Defined Benefit Plan, Future Amortization of Prior Service Cost (Credit)	(392)	(368)	(1,176)	(1,102)
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Gain (Loss), before Tax	4,030	3,641	12,092	10,834
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Gain (Loss), Tax	(1,612)	(1,456)	(4,837)	(4,334)
Total before tax [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	(18,216)	3,880	(41,151)	50,333
Tax benefit [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Tax	2,957	(748)	5,621	(9,845)
Continuing Operations [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	(15,259)	3,132	(35,530)	40,488
Continuing Operations [Member] | Accumulated Defined Benefit Plans Adjustment [Member]
Other Comprehensive (Income) Loss, Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, Net of Tax	2,418	2,185	7,255	6,500
Discontinued Operations [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	0	0	0	7,682
Discontinued Operations [Member] | Accumulated Defined Benefit Plans Adjustment [Member]
Other Comprehensive (Income) Loss, Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, Net of Tax	0	0	0	1,648
Net of tax [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	(15,259)	3,132	(35,530)	48,170
Net income attributable to noncontrolling interest [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax, Portion Attributable to Noncontrolling Interest	(10,150)	1,928	(25,745)	24,574
Commodity Contract [Member] | Sales [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	(22,770)	355	(54,020)	31,961
Interest Rate Contract [Member] | Interest Expense [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	$ 4,554	$ 3,525	$ 12,869	$ 18,372

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES Part 1 (Details) - USD ($)	Sep. 30, 2015	Dec. 31, 2014
Derivatives, Fair Value [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 0
Assets	51,421,000	$ 55,444,000
Liabilities	(19,547,000)	(46,003,000)
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	50,400,000	55,444,000
Liabilities	(18,756,000)	(45,980,000)
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	1,021,000	0
Liabilities	(791,000)	(23,000)
Interest Rate Contract [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	0	2,288,000
Liabilities	(13,648,000)	(44,843,000)
Physical Derivative Instrument [Member] | Commodity Contract [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	4,866,000	9,922,000
Liabilities	0	0
Physical Derivative Instrument [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	0	0
Liabilities	0	(23,000)
Financial Derivative Instrument [Member] | Commodity Contract [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	45,534,000	43,234,000
Liabilities	(5,108,000)	(1,137,000)
Financial Derivative Instrument [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	1,021,000	0
Liabilities	(791,000)	0
Natural Gas Pipelines [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net	$ 0	$ 0

XML

EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Basic EPS from continuing operations [Abstract]
Income from continuing operations attributable to ONEOK available for common stock	$ 86,017	$ 64,629	$ 223,606	$ 225,969
Weighted Average number of share, basic (in shares)	210,296	209,489	210,138	209,341
Per share amount, basic (in dollars per shares)	$ 0.41	$ 0.31	$ 1.06	$ 1.08
Diluted EPS from continuing operations [Abstract]
Effect of dilutive securities	$ 0	$ 0	$ 0	$ 0
Effect of dilutive securities, number of shares (in shares)	228	1,270	371	1,141
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$ 86,017	$ 64,629	$ 223,606	$ 225,969
Weighted Average number of share, diluted (in shares)	210,524	210,759	210,509	210,482
Per Share amount, diluted (in dollars per share)	$ 0.41	$ 0.31	$ 1.06	$ 1.07
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	0	0	0	0

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FAIR VALUE MEASUREMENTS - Part 1 (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash collateral held	$ 23,400	$ 24,800
Cash collateral posted	0	0
Derivative liabilities
Long-term Debt, Fair Value	8,100,000	7,500,000
Long-term Debt, Book Value	8,400,000	7,200,000
Fair Value, Measurements, Recurring [Member]
Derivative assets
Commodity contracts - financial	17,236	17,255
Commodity contracts - physical	4,866	9,922
Interest-rate contracts		2,288
Total derivatives assets	22,102	29,465
Other
Available-for-sale investment securities		1,773
Total assets		31,238
Derivative liabilities
Commodity contracts - financial	0	0
Commodity contracts - physical		(23)
Interest-rate contracts	(13,648)	(44,843)
Total derivative liabilities	(13,648)	(44,866)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Derivative assets
Commodity contracts - financial	40,799	42,880
Commodity contracts - physical	0	0
Interest-rate contracts		0
Total derivatives assets	40,799	42,880
Other
Available-for-sale investment securities		1,773
Total assets		44,653
Derivative liabilities
Commodity contracts - financial	(573)	(169)
Commodity contracts - physical		0
Interest-rate contracts	0	0
Total derivative liabilities	(573)	(169)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Derivative assets
Commodity contracts - financial	0	0
Commodity contracts - physical	0	0
Interest-rate contracts		2,288
Total derivatives assets	0	2,288
Other
Available-for-sale investment securities		0
Total assets		2,288
Derivative liabilities
Commodity contracts - financial	0	0
Commodity contracts - physical		0
Interest-rate contracts	(13,648)	(44,843)
Total derivative liabilities	(13,648)	(44,843)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Derivative assets
Commodity contracts - financial	5,756	354
Commodity contracts - physical	4,866	9,922
Interest-rate contracts		0
Total derivatives assets	10,622	10,276
Other
Available-for-sale investment securities		0
Total assets		10,276
Derivative liabilities
Commodity contracts - financial	(5,326)	(968)
Commodity contracts - physical		(23)
Interest-rate contracts	0	0
Total derivative liabilities	(5,326)	(991)
Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value Measurement [Member]
Derivative assets
Commodity contracts - financial	46,555	43,234
Commodity contracts - physical	4,866	9,922
Interest-rate contracts		2,288
Total derivatives assets	51,421	55,444
Other
Available-for-sale investment securities		1,773
Total assets		57,217
Derivative liabilities
Commodity contracts - financial	(5,899)	(1,137)
Commodity contracts - physical		(23)
Interest-rate contracts	(13,648)	(44,843)
Total derivative liabilities	(19,547)	(46,003)
Fair Value, Measurements, Recurring [Member] | Netting [Member]
Derivative assets
Commodity contracts - financial	(29,319)	(25,979)
Commodity contracts - physical	0	0
Interest-rate contracts		0
Total derivatives assets	(29,319)	(25,979)
Other
Available-for-sale investment securities		0
Total assets		(25,979)
Derivative liabilities
Commodity contracts - financial	5,899	1,137
Commodity contracts - physical		0
Interest-rate contracts	0	0
Total derivative liabilities	$ 5,899	$ 1,137

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DISCONTINUED OPERATIONS (Tables)

9 Months Ended

Sep. 30, 2015

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Restructuring and Related Costs [Table Text Block]

The following table summarizes the change in our liability related to released capacity contracts for the periods indicated:

	Nine Months Ended
	September 30,
	2015			2014
	(Millions of dollars)
Beginning balance	$	73.8		$	122.0
Noncash charges	—			1.7
Settlements	(31.2		)	(38.6		)
Accretion	0.8			1.5
Ending balance	$	43.4		$	86.6

Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]

Results of Operations of Discontinued Operations - The results of operations for our former natural gas distribution business and energy services business have been reported as discontinued operations for all periods presented. Income (loss) from discontinued operations, net of tax, in the Consolidated Statements of Income for the three and nine months ended September 30, 2015, consists of accretion expense, net of tax benefit, on the released contracts for our former energy services business and certain tax-related adjustments. The table below provides selected financial information reported in discontinued operations in the Consolidated Statements of Income for the three and nine months ended September 30, 2014:

	Three Months Ended									Nine Months Ended
	September 30, 2014									September 30, 2014
	Natural Gas Distribution		Energy Services				Total			Natural Gas Distribution				Energy Services			Total
	(Thousands of dollars)
Revenues	$	—	$	—			$	—		$	287,249			$	353,404		$	640,653
Cost of sales and fuel	—		—				—			190,893				364,648			555,541
Net margin	—		—				—			96,356				(11,244		)	85,112
Operating costs	—		142			(b)	142			60,847			(a)	4,664			65,511
Depreciation and amortization	—		—				—			11,035				319			11,354
Operating income (loss)	—		(142		)		(142		)	24,474				(16,227		)	8,247
Other income (expense), net	—		—				—			(888		)		(7		)	(895		)
Interest expense, net	—		—				—			(4,592		)		(413		)	(5,005		)
Income taxes	—		(29		)		(29		)	(16,415		)		7,662			(8,753		)
Income (loss) from discontinued operations, net	$	—	$	(171	)		$	(171	)	$	2,579			$	(8,985	)	$	(6,406	)

(a) - Includes approximately $23.0 million for the nine months ended September 30, 2014, of costs related to ONE Gas separation.

(b) - Represents primarily accretion expense.

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UNCONSOLIDATED AFFILIATES (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Schedule of Equity Method Investments [Line Items]
Equity in net earnings (loss) from investments	$ 32,244	$ (52,347)	$ 93,205	$ 6,747
Income (loss) from equity method investments before impairments	32,244	1,074	93,205	60,168
Investments in unconsolidated affiliates	1,137,059	1,128,509	1,137,059	1,128,509	$ 1,132,653
Accounts Payable, Related Parties, Current	9,400		9,400		$ 20,500
Income Statement
Operating revenues	135,474	126,218	390,793	403,006
Operating expenses	64,786	123,620	178,324	247,169
Net income (loss)	67,121	(5,119)	196,123	134,432
Distributions paid to ONEOK Partners	36,370	31,574	117,153	109,223
Bighorn Gas Gathering Llc [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Other than Temporary Impairment	0	(53,421)	0	(53,421)
Equity Method Investments, Proportionate Share of Investee Impairment of Long-Lived Assets Charge		23,000		23,000
Roadrunner Gas Transmission [Member]
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments			30,000
Northern Border Pipeline [Member]
Schedule of Equity Method Investments [Line Items]
Equity in net earnings (loss) from investments	16,156	14,371	51,131	53,657
Overland Pass Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Equity in net earnings (loss) from investments	10,538	3,856	27,048	12,708
Other Unconsolidated Affiliate [Member]
Schedule of Equity Method Investments [Line Items]
Equity in net earnings (loss) from investments	5,550	(17,153)	15,026	(6,197)
Unconsolidated Affiliates [Member]
Schedule of Equity Method Investments [Line Items]
Costs and operating expenses with equity method investees	28,400	$ 15,000	74,200	$ 43,500
Powder River Basin [Member]
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	214,200		214,200
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	$ 130,500		$ 130,500

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SEGMENTS

9 Months Ended

Sep. 30, 2015

Segment Reporting [Abstract]

SEGMENTS

O. SEGMENTS

Segment Descriptions - Our reportable business segments are based upon the following segments of ONEOK Partners:

• the Natural Gas Gathering and Processing segment gathers, treats and processes natural gas;

• the Natural Gas Liquids segment gathers, treats, fractionates and transports NGLs and stores, markets and distributes NGL products; and

• the Natural Gas Pipelines segment operates regulated interstate and intrastate natural gas transmission pipelines and natural gas storage facilities.

Other and eliminations consist of the operating and leasing operations of our headquarters building and related parking facility and other amounts needed to reconcile our reportable segments to our consolidated financial statements.

Accounting Policies - We evaluate performance based principally on each segment’s operating income and equity earnings. The accounting policies of the segments are described in Note A of the Notes to Consolidated Financial Statements in our Annual Report. Intersegment and affiliate sales are recorded on the same basis as sales to unaffiliated customers and are discussed further in Note M. Net margin is comprised of total revenues less cost of sales and fuel. Cost of sales and fuel includes commodity purchases, fuel, storage and transportation costs. Revenues from sales and services provided by ONEOK Partners to our former natural gas distribution business prior to the separation and to our former energy services business prior to the completion of the wind down, which were previously eliminated in consolidation, are now reported as sales to affiliated customers for the nine months ended September 30, 2014, and are no longer eliminated in consolidation. Revenues from sales and services provided by ONEOK Partners to our former natural gas distribution business after the separation are reported as sales to unaffiliated customers as these now represent third-party transactions.

Customers - The primary customers of the Natural Gas Gathering and Processing segment are major and independent crude oil and natural gas production companies. The Natural Gas Liquids segment’s customers are primarily NGL and natural gas gathering and processing companies, major and independent crude oil and natural gas production companies, propane distributors, ethanol producers and petrochemical, refining and NGL marketing companies. The Natural Gas Pipelines segment’s customers include natural gas distribution, electric-generation, natural gas marketing, industrial and major and independent crude oil and natural gas production companies.

For the three and nine months ended September 30, 2015 and 2014, ONEOK Partners had no single customer from which it received 10 percent or more of consolidated revenues.

Operating Segment Information - The following tables set forth certain selected financial information for our operating segments for the periods indicated:

Three Months Ended September 30, 2015	Natural Gas Gathering and Processing		Natural Gas Liquids (a)			Natural Gas Pipelines (b)			Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	294,948	$	1,522,224		$	81,246		$	528		$	1,898,946
Intersegment revenues	139,388		89,230			1,751			(230,369		)	—
Total revenues	$	434,336	$	1,611,454		$	82,997		$	(229,841	)	$	1,898,946
Net margin	$	140,655	$	321,772		$	75,369		$	341		$	538,137
Operating costs	61,162		74,464			26,674			1,877			164,177
Depreciation and amortization	37,286		39,317			10,914			782			88,299
Gain (loss) on sale of assets	132		(498		)	(77		)	(283		)	(726		)
Operating income	$	42,339	$	207,493		$	37,704		$	(2,601	)	$	284,935
Equity in net earnings from investments	$	4,350	$	10,912		$	16,982		$	—		$	32,244
Capital expenditures	$	231,835	$	52,807		$	14,718		$	1,508		$	300,868

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $252.8 million, of which $204.7 million was related to sales within the segment, net margin of $140.1 million and operating income of $80.3 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $65.1 million, net margin of $57.9 million and operating income of $24.7 million.

Three Months Ended September 30, 2014	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)		Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	374,403		$	2,667,939		$	77,027	$	776		$	3,120,145
Intersegment revenues	403,399			66,581			2,133		(472,113		)	—
Total revenues	$	777,802		$	2,734,520		$	79,160	$	(471,337	)	$	3,120,145
Net margin	$	178,171		$	282,963		$	73,399	$	2,408		$	536,941
Operating costs	64,279			76,946			27,998		3,272			172,495
Depreciation and amortization	31,327			31,661			10,913		687			74,588
Gain (loss) on sale of assets	324			(535		)	1,746		(1		)	1,534
Operating income	$	82,889		$	173,821		$	36,234	$	(1,552	)	$	291,392
Equity in net earnings (loss) from investments	$	(71,069	)	$	4,351		$	14,371	$	—		$	(52,347	)
Capital expenditures	$	214,917		$	153,785		$	10,650	$	2,833		$	382,185

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $190.3 million, of which $170.1 million related to sales within the segment, net margin of $94.3 million and operating income of $46.4 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $65.2 million, net margin of $57.4 million and operating income of $23.4 million.

Nine Months Ended September 30, 2015	Natural Gas Gathering and Processing		Natural Gas Liquids (a)			Natural Gas Pipelines (b)			Other and Eliminations (c)			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	862,462	$	4,726,617		$	241,605		$	1,620		$	5,832,304
Intersegment revenues	487,559		229,804			5,053			(722,416		)	—
Total revenues	$	1,350,021	$	4,956,421		$	246,658		$	(720,796	)	$	5,832,304
Net margin	$	402,482	$	902,382		$	218,599		$	1,075		$	1,524,538
Operating costs	193,922		234,120			79,156			1,347			508,545
Depreciation and amortization	109,035		118,044			32,484			1,678			261,241
Gain (loss) on sale of assets	328		(579		)	(76		)	(283		)	(610		)
Operating income	$	99,853	$	549,639		$	106,883		$	(2,233	)	$	754,142
Equity in net earnings from investments	$	13,511	$	27,585		$	52,109		$	—		$	93,205
Investments in unconsolidated affiliates	$	253,548	$	484,403		$	399,108		$	—		$	1,137,059
Total assets	$	5,206,987	$	8,041,064		$	1,837,776		$	422,471		$	15,508,298
Noncontrolling interests in consolidated subsidiaries	$	4,066	$	161,210		$	—		$	3,457,557		$	3,622,833
Capital expenditures	$	692,570	$	185,360		$	39,923		$	12,463		$	930,316

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $690.1 million, of which $556.4 million was related to sales within the segment, net margin of $392.7 million and operating income of $218.8 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $198.5 million, net margin of $175.9 million and operating income of $77.8 million.

(c) - Other and Eliminations includes assets of discontinued operations of $20.5 million.

Nine Months Ended September 30, 2014	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)		Other and Eliminations (c)			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	1,095,531		$	7,950,930		$	247,420	$	2,916		$	9,296,797
Sales to affiliated customers	41,214			—			12,312		—			53,526
Intersegment revenues	1,126,547			160,712			6,206		(1,293,465		)	—
Total revenues	$	2,263,292		$	8,111,642		$	265,938	$	(1,290,549	)	$	9,350,323
Net margin	$	486,695		$	818,086		$	242,359	$	(4,092	)	$	1,543,048
Operating costs	188,489			218,129			82,747		4,263			493,628
Depreciation and amortization	89,612			89,848			32,623		2,046			214,129
Gain (loss) on sale of assets	277			(572		)	1,663		165			1,533
Operating income	$	208,871		$	509,537		$	128,652	$	(10,236	)	$	836,824
Equity in net earnings (loss) from investments	$	(60,484	)	$	13,574		$	53,657	$	—		$	6,747
Investments in unconsolidated affiliates	$	253,930		$	484,238		$	390,341	$	—		$	1,128,509
Total assets	$	4,415,814		$	7,337,688		$	1,832,368	$	726,326		$	14,312,196
Noncontrolling interests in consolidated subsidiaries	$	4,394		$	—		$	—	$	3,131,769		$	3,136,163
Capital expenditures	$	506,016		$	637,524		$	25,987	$	34,859		$	1,204,386

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $479.4 million, of which $417.0 million related to sales within the segment, net margin of $263.4 million and operating income of $126.0 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $214.8 million, net margin of $185.5 million and operating income of $84.6 million.

(c) - Other and Eliminations includes assets and capital expenditures of discontinued operations of $84.2 million and $23.9 million, respectively.

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES Part 3 (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)			$ 3,661
Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on Discontinuation of Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net	$ 0	$ 0	0	$ (4,600)
Gain (Loss) on Discontinuation of Interest Rate Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Tax				3,100
Commodity Contract [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Commodity cash flow hedge gain to be reclassified	12,000		12,000
Price Risk Cash Flow Hedge Unrealized Gain (Loss) to be Reclassified During Next 12 Months	10,700		10,700
Commodity Cash Flow Hedge Gain To Be Reclassified After Next 12 Months Net	1,300		1,300
Interest Rate Contract [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of accumulated other comprehensive income (loss) attributable primarily to settled interest-rate swaps.	(50,600)		(50,600)
Amount of loss to be recognized in the next 12 months	(6,200)		(6,200)
Discontinued Operations [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income on derivatives (effective portion)				(12,800)
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)				(3,700)
Continuing Operations [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income on derivatives (effective portion)	18,216	(3,880)	41,151	(50,333)
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	15,949	7,378	21,373	(81,592)
Continuing Operations [Member] | Commodity Contract [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	36,559	17,133	47,650	(24,743)
Continuing Operations [Member] | Commodity Contract [Member] | Revenues [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income on derivatives (effective portion)	22,770	(355)	54,020	(31,961)
Continuing Operations [Member] | Interest Rate Contract [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	(20,610)	(9,755)	(26,277)	(56,849)
Continuing Operations [Member] | Interest Rate Contract [Member] | Interest Expense [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income on derivatives (effective portion)	$ (4,554)	$ (3,525)	$ (12,869)	$ (18,372)

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Part 1 (Details)	9 Months Ended
	Sep. 30, 2015
Entity [Line Items]
Ownership Interest	41.20%

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EARNINGS PER SHARE (Tables)

9 Months Ended

Sep. 30, 2015

Earnings Per Share [Abstract]

Earnings Per Share

The following tables set forth the computation of basic and diluted EPS from continuing operations for the periods indicated:

	Three Months Ended September 30, 2015
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	86,017	210,296	$	0.41
Diluted EPS from continuing operations
Effect of dilutive securities	—		228
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	86,017	210,524	$	0.41

	Three Months Ended September 30, 2014
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	64,629	209,489	$	0.31
Diluted EPS from continuing operations
Effect of dilutive securities	—		1,270
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	64,629	210,759	$	0.31

	Nine Months Ended September 30, 2015
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	223,606	210,138	$	1.06
Diluted EPS from continuing operations
Effect of dilutive securities	—		371
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	223,606	210,509	$	1.06

	Nine Months Ended September 30, 2014
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	225,969	209,341	$	1.08
Diluted EPS from continuing operations
Effect of dilutive securities	—		1,141
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	225,969	210,482	$	1.07

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LONG-TERM DEBT (Details) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2015	Mar. 31, 2015	Mar. 31, 2014	Sep. 30, 2015
Debt Instrument [Line Items]
Payments to Acquire Interest in Subsidiaries and Affiliates	$ 650.0
ONE Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 1,200.0
Proceeds from Debt, Net of Issuance Costs			$ 1,190.0
ONE Gas [Member] | Notes Payable due 2019 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			2.07%
Long-term Debt, Gross			$ 300.0
ONE Gas [Member] | Notes Payable due 2024 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			3.61%
Long-term Debt, Gross			$ 300.0
ONE Gas [Member] | Notes Payable due 2044 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			4.658%
Long-term Debt, Gross			$ 600.0
Parent Company [Member]
Debt Instrument [Line Items]
Related Party Transaction, Amounts of Transaction			1,130.0
Loss on extinguishment of debt			24.8
Parent Company [Member] | Note Payable Due 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	7.50%			7.50%
Long-term Debt, Gross	$ 500.0			$ 500.0
Proceeds from Debt, Net of Issuance Costs	$ 487.1
Parent Company [Member] | Note Payable from Public Offering Due 2022 [Member]
Debt Instrument [Line Items]
Extinguishment of Debt, Amount			$ 152.5
Debt Instrument, Interest Rate, Stated Percentage			4.25%
Early Repayment of Senior Debt			$ 150.0
Parent Company [Member] | Note Payable due 2015 [Member]
Debt Instrument [Line Items]
Extinguishment of Debt, Amount			$ 400.0
Debt Instrument, Interest Rate, Stated Percentage			5.20%
Early Repayment of Senior Debt			$ 430.1
Partnership Interest [Member] | Note Payable from Public Offering Due 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		3.80%
Long-term Debt, Gross		$ 300.0
Partnership Interest [Member] | Note Payable from Public Offering Due 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		4.90%
Long-term Debt, Gross		$ 500.0
Partnership Interest [Member] | Note Payable from Public Offering Due 2016 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.25%			3.25%
Long-term Debt, Gross	$ 650.0			$ 650.0
Senior Notes [Member] | Parent Company [Member]
Debt Instrument [Line Items]
Debt Instrument, Call Feature				ONEOK may redeem the remaining balance of its senior notes due 2023 at a redemption price equal to the principal amount, plus accrued and unpaid interest, starting three months before the maturity date.  Prior to this date, ONEOK may redeem these senior notes in whole or in part, at any time prior to their maturity at a redemption price equal to the principal amount, plus accrued and unpaid interest and a make-whole premium.  The redemption price will never be less than 100 percent of the principal amount of the respective note plus accrued and unpaid interest to the redemption date.  ONEOK’s senior notes due 2023 are senior unsecured obligations, ranking equally in right of payment with all of ONEOK’s existing and future unsecured senior indebtedness.
Debt Instrument, Covenant Description				The indenture governing ONEOK’s senior notes due 2023 include an event of default upon the acceleration of other indebtedness of $100 million or more.  Such an event of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of the outstanding senior notes due 2023 to declare those senior notes immediately due and payable in full. The indenture also contains a provision that allows the holders of the notes to require ONEOK to offer to repurchase all or any part of their notes if a change of control and a credit rating downgrade occur at a purchase price of 101 percent of the principal amount, plus accrued and unpaid interest, if any.
Senior Notes [Member] | Partnership Interest [Member]
Debt Instrument [Line Items]
Debt Instrument, Call Feature				ONEOK Partners may redeem its 3.8 percent senior notes due 2020 and its 4.9 percent senior notes due 2025 from the March 2015 offering at par, plus accrued and unpaid interest to the redemption date, starting one month and three months, respectively, before their maturity dates. Prior to these dates, ONEOK Partners may redeem these notes, in whole or in part, at a redemption price equal to the principal amount, plus accrued and unpaid interest and a make-whole premium. The redemption price will never be less than 100 percent of the principal amount of the respective note plus accrued and unpaid interest to the redemption date. ONEOK Partners’ senior notes are senior unsecured obligations, ranking equally in right of payment with all of ONEOK Partners’ existing and future unsecured senior indebtedness, and structurally subordinate to any of the existing and future debt and other liabilities of any ONEOK Partners’ nonguarantor subsidiaries.
Debt Instrument, Covenant Description				These notes are governed by an indenture, dated as of September 25, 2006, between ONEOK Partners and Wells Fargo Bank, N.A., the trustee, as supplemented. The indenture does not limit the aggregate principal amount of debt securities that may be issued and provides that debt securities may be issued from time to time in one or more additional series. The indenture contains covenants including, among other provisions, limitations on ONEOK Partners’ ability to place liens on its property or assets and to sell and lease back its property. The indenture includes an event of default upon acceleration of other indebtedness of $100 million or more. Such events of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of any of ONEOK Partners’ outstanding senior notes to declare those notes immediately due and payable in full.
Senior Notes, Noncurrent		800.0
Proceeds from Debt, Net of Issuance Costs		$ 792.3

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FAIR VALUE MEASUREMENTS - Part 2 (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Transfers Between Levels	$ 0	$ 0	$ 0	$ 0
Derivative Financial Instruments Assets Liabilities Net [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Net assets (liabilities) at beginning of period	10,387	(1,313)	9,285	(782)
Total realized/unrealized gains (losses):
Included in earnings	(15)	207	95	(688)
Included in other comprehensive income (loss)	(5,076)	402	(4,084)	(2,968)
Purchases, issuances and settlements	0	0	0	3,734
Net assets (liabilities) at end of period	$ 5,296	$ (704)	$ 5,296	$ (704)

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CONSOLIDATED STATEMENT OF CHANGES IN EQUITY - USD ($) $ in Thousands	Total	Common Stock [Member]	Paid-in Capital [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Retained Earnings [Member]	Treasury Stock [Member]	Noncontrolling Interests in Consolidated Subsidiaries [Member]
Stockholders' equity, beginning balance at Dec. 31, 2013	$ 4,845,180	$ 2,458	$ 1,433,600	$ (121,987)	$ 2,020,815	$ (997,035)	$ 2,507,329
Common stock issued, beginning balance (in shares) at Dec. 31, 2013		245,811,180
Net income	461,543	$ 0	0	0	219,563	0	241,980
Other comprehensive income (loss) (Note I)	(16,394)	$ 0	0	10,942	0	0	(27,336)
Common stock issued (in shares)		0
Common stock issued	19,661	$ 0	(20,397)	0	0	40,058	0
Common stock dividends - $1.535 and $1.815 per share (Note H)	(321,051)	0	0	0	(321,051)	0	0
Issuance of common units of ONEOK Partners (Note M)	877,658	0	138,310	0	0	0	739,348
Distributions of ONE Gas to Shareholders	(1,745,689)	0	0	3,389	(1,749,078)	0	0
Distributions to noncontrolling interests	(325,158)	0	0	0	0	0	(325,158)
Other	(36,355)	0	(36,355)	0	0	0	0
Stockholders' equity, ending balance at Sep. 30, 2014	3,759,395	$ 2,458	1,515,158	(107,656)	170,249	(956,977)	3,136,163
Common stock issued, ending balance (in shares) at Sep. 30, 2014		245,811,180
Stockholders' equity, beginning balance at Dec. 31, 2014	4,005,883	$ 2,458	1,541,583	(136,353)	138,128	(953,701)	3,413,768
Common stock issued, beginning balance (in shares) at Dec. 31, 2014		245,811,180
Net income	407,411	$ 0	0	0	219,462	0	187,949
Other comprehensive income (loss) (Note I)	(9,948)	$ 0	0	241	0	0	(10,189)
Common stock issued (in shares)		0
Common stock issued	17,912	$ 0	(6,284)	0	0	24,196	0
Common stock dividends - $1.535 and $1.815 per share (Note H)	(380,498)	0	(22,807)	0	(357,691)	0	0
Issuance of common units of ONEOK Partners (Note M)	394,144	0	(34,446)	0	0	0	428,590
Distributions to noncontrolling interests	(396,847)	0	0	0	0	0	(396,847)
Other	(752)	0	(415)	0	101	0	(438)
Stockholders' equity, ending balance at Sep. 30, 2015	$ 4,037,305	$ 2,458	$ 1,477,631	$ (136,112)	$ 0	$ (929,505)	$ 3,622,833
Common stock issued, ending balance (in shares) at Sep. 30, 2015		245,811,180

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Part 2 (Details) $ in Millions	12 Months Ended
	Dec. 31, 2014 USD ($)
Long-term Debt [Member] | Accounting Standards Update 2015-03 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Adoption, Quantification	$ 42.8

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FAIR VALUE MEASUREMENTS FAIR VALUE MEASUREMENTS (Policies)

9 Months Ended

Sep. 30, 2015

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments, Policy [Policy Text Block]

Determining Fair Value -We define fair value as the price that would be received from the sale of an asset or the transfer of a liability in an orderly transaction between market participants at the measurement date. We use market and income approaches to determine the fair value of our assets and liabilities and consider the markets in which the transactions are executed. We measure the fair value of a group of financial assets and liabilities consistent with how a market participant would price the net risk exposure at the measurement date.

While many of the contracts in ONEOK Partners’ portfolio are executed in liquid markets where price transparency exists, some contracts are executed in markets for which market prices may exist, but the market may be relatively inactive. This results in limited price transparency that requires management’s judgment and assumptions to estimate fair values.  For certain transactions, we utilize modeling techniques using NYMEX-settled pricing data and implied forward LIBOR curves. Inputs into our fair value estimates include commodity-exchange prices, over-the-counter quotes, historical correlations of pricing data, data obtained from third-party pricing services and LIBOR and other liquid money-market instrument rates. We validate our valuation inputs with third-party information and settlement prices from other sources, where available.

In addition, as prescribed by the income approach, we compute the fair value of our and ONEOK Partners’ derivative portfolio by discounting the projected future cash flows from our and ONEOK Partners’ derivative assets and liabilities to present value using interest-rate yields to calculate present-value discount factors derived from LIBOR, Eurodollar futures and interest-rate swaps. We also take into consideration the potential impact on market prices of liquidating positions in an orderly manner over a reasonable period of time under current market conditions. We consider current market data in evaluating counterparties’, as well as our own, nonperformance risk, net of collateral, by using specific and sector bond yields and monitoring the credit default swap markets. Although we use our best estimates to determine the fair value of the derivative contracts we and ONEOK Partners have executed, the ultimate market prices realized could differ from our estimates, and the differences could be material.

The fair value of our forward-starting interest-rate swaps are determined using financial models that incorporate the implied forward LIBOR yield curve for the same period as the future interest swap settlements.

Fair Value Hierarchy - At each balance sheet date, we utilize a fair value hierarchy to classify fair value amounts recognized or disclosed in our financial statements based on the observability of inputs used to estimate such fair value. The levels of the hierarchy are described below:

• Level 1 - fair value measurements are based on unadjusted quoted prices for identical securities in active markets, including NYMEX-settled prices. These balances are comprised predominantly of exchange-traded derivative contracts for natural gas and crude oil.

• Level 2 - fair value measurements are based on significant observable pricing inputs, such as NYMEX-settled prices for natural gas and crude oil, and financial models that utilize implied forward LIBOR yield curves for interest-rate swaps.

• Level 3 - fair value measurements are based on inputs that may include one or more unobservable inputs, including natural gas basis and NGL price curves that incorporate observable and unobservable market data from broker quotes, third-party pricing services, market volatilities derived from the most recent NYMEX close spot prices and forward LIBOR curves, and adjustments for the credit risk of our counterparties. We corroborate the data on which our fair value estimates are based using our market knowledge of recent transactions, analysis of historical correlations and validation with independent broker quotes. These balances categorized as Level 3 are comprised of derivatives for natural gas and NGLs. We do not believe that our Level 3 fair value estimates have a material impact on our results of operations, as the majority of our derivatives are accounted for as hedges for which ineffectiveness has not been material.

Determining the appropriate classification of our fair value measurements within the fair value hierarchy requires management’s judgment regarding the degree to which market data is observable or corroborated by observable market data. We categorize derivatives for which fair value is determined using multiple inputs within a single level, based on the lowest level input that is significant to the fair value measurement in its entirety.

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ACQUISITIONS ACQUISITIONS (Policies)

9 Months Ended

Sep. 30, 2015

Business Acquisition [Line Items]

Business Combinations Policy [Policy Text Block]

We accounted for this acquisition as a business combination which, among other things, requires assets acquired and liabilities assumed to be measured at their acquisition-date fair values.

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EMPLOYEE BENEFIT PLANS (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Pension Benefits [Member]
Components of net periodic benefit cost
Service cost	$ 1,887	$ 1,784	$ 5,661	$ 5,429
Interest cost	4,546	4,488	13,638	13,744
Expected return on assets	(5,213)	(4,775)	(15,639)	(14,644)
Amortization of unrecognized prior service cost	23	48	69	144
Amortization of net loss	3,987	3,798	11,961	11,309
Other	0	16	0	136
Net periodic benefit cost	5,230	5,359	15,690	16,118
Postretirement Benefits [Member]
Components of net periodic benefit cost
Service cost	186	175	558	533
Interest cost	587	603	1,760	1,825
Expected return on assets	(564)	(513)	(1,692)	(1,623)
Amortization of unrecognized prior service cost	(415)	(416)	(1,245)	(1,246)
Amortization of net loss	435	211	1,307	627
Other	0	0	0	(2)
Net periodic benefit cost	$ 229	$ 60	$ 688	$ 114

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DISCONTINUED OPERATIONS (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014	Dec. 31, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Accumulated charges attributable to exit activities	$ 43,400	$ 86,600	$ 43,400	$ 86,600	$ 73,800	$ 122,000
Noncash charges			0	1,739
Settlements			(31,200)	(38,600)
Accretion			800	1,500
Effect on future cash flows, amount			26,000
Disposal group, including discontinued operation, revenue		0		640,653
Disposal group, including discontinued operation, costs of sales and fuel		0		555,541
Disposal group, including discontinued operation, net margin		0		85,112
Disposal group, including discontinued operation, operating costs		142		65,511
Disposal group, including discontinued operation, depreciation and amortization		0		11,354
Disposal group, including discontinued operation, operating income (loss)		(142)		8,247
Disposal group, including discontinued operation, other income (expense), net		0		(895)
Disposal group, including discontinued operation, interest expense, net		0		(5,005)
Discontinued operation, income taxes		(29)		(8,753)
Income (loss) from discontinued operations, net of tax, including portion attributable to noncontrolling interest	$ (3,860)	(171)	(4,144)	(6,406)
Costs related to separation				23,000
Natural Gas Distribution [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal group, including discontinued operation, revenue		0		287,249
Disposal group, including discontinued operation, costs of sales and fuel		0		190,893
Disposal group, including discontinued operation, net margin		0		96,356
Disposal group, including discontinued operation, operating costs		0		60,847
Disposal group, including discontinued operation, depreciation and amortization		0		11,035
Disposal group, including discontinued operation, operating income (loss)		0		24,474
Disposal group, including discontinued operation, other income (expense), net		0		(888)
Disposal group, including discontinued operation, interest expense, net		0		(4,592)
Discontinued operation, income taxes		0		(16,415)
Income (loss) from discontinued operations, net of tax, including portion attributable to noncontrolling interest		0		2,579
Energy Services [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal group, including discontinued operation, revenue		0		353,404
Disposal group, including discontinued operation, costs of sales and fuel		0		364,648
Disposal group, including discontinued operation, net margin		0		(11,244)
Disposal group, including discontinued operation, operating costs		142		4,664
Disposal group, including discontinued operation, depreciation and amortization		0		319
Disposal group, including discontinued operation, operating income (loss)		(142)		(16,227)
Disposal group, including discontinued operation, other income (expense), net		0		(7)
Disposal group, including discontinued operation, interest expense, net		0		(413)
Discontinued operation, income taxes		(29)		7,662
Income (loss) from discontinued operations, net of tax, including portion attributable to noncontrolling interest		$ (171)		(8,985)
2015 [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Effect on future cash flows, amount			4,000
2016 [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Effect on future cash flows, amount			11,000
2017 [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Effect on future cash flows, amount			6,000
2018 - 2023 [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Effect on future cash flows, amount			$ 5,000
ONEOK Partners [Member] | Natural Gas Distribution [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party				7,500
ONEOK Partners [Member] | Energy Services [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party				$ 46,000

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES (Policies)

9 Months Ended

Sep. 30, 2015

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES [Abstract]

Accounting treatment for derivative instruments

Accounting Treatment -We and ONEOK Partners record all derivative instruments at fair value, with the exception of normal purchases and normal sales transactions that are expected to result in physical delivery. Commodity price and interest-rate volatility may have a significant impact on the fair value of derivative instruments as of a given date. The accounting for changes in the fair value of a derivative instrument depends on whether it has been designated and qualifies as part of a hedging relationship and, if so, the reason for holding it.

The table below summarizes the various ways in which we account for our derivative instruments and the impact on our consolidated financial statements:

		Recognition and Measurement
Accounting Treatment		Balance Sheet		Income Statement
Normal purchases and normal sales	-	Fair value not recorded	-	Change in fair value not recognized in earnings
Mark-to-market	-	Recorded at fair value	-	Change in fair value recognized in earnings
Cash flow hedge	-	Recorded at fair value	-	Ineffective portion of the gain or loss on the derivative instrument is recognized in earnings
	-	Effective portion of the gain or loss on the derivative instrument is reported initially as a component of accumulated other comprehensive income (loss)	-	Effective portion of the gain or loss on the derivative instrument is reclassified out of accumulated other comprehensive income (loss) into earnings when the forecasted transaction affects earnings
Fair value hedge	-	Recorded at fair value	-	The gain or loss on the derivative instrument is recognized in earnings
	-	Change in fair value of the hedged item is recorded as an adjustment to book value	-	Change in fair value of the hedged item is recognized in earnings

To reduce its exposure to fluctuations in natural gas, NGLs and condensate prices, ONEOK Partners periodically enters into futures, forward purchases and sales, options or swap transactions in order to hedge anticipated purchases and sales of natural gas, NGLs and condensate. Interest-rate swaps are used from time to time to manage interest-rate risk. Under certain conditions, we designate these derivative instruments as a hedge of exposure to changes in fair values or cash flows. We formally document all relationships between hedging instruments and hedged items, as well as risk-management objectives and strategies for undertaking various hedge transactions, and methods for assessing and testing correlation and hedge ineffectiveness. We specifically identify the forecasted transaction that has been designated as the hedged item in a cash flow hedge relationship. We assess the effectiveness of hedging relationships quarterly by performing an effectiveness analysis on our fair value and cash flow hedging relationships to determine whether the hedge relationships are highly effective on a retrospective and prospective basis. ONEOK Partners also documents its normal purchases and normal sales transactions that are expected to result in physical delivery and that ONEOK Partners elects to exempt from derivative accounting treatment.

The realized revenues and purchase costs of our and ONEOK Partners’ derivative instruments not considered held for trading purposes and derivatives that qualify as normal purchases or normal sales that are expected to result in physical delivery are reported on a gross basis. Cash flows from futures, forwards and swaps that are accounted for as hedges are included in the same category as the cash flows from the related hedged items in our Consolidated Statements of Cash Flows.

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ONEOK PARTNERS (Policies)

9 Months Ended

Sep. 30, 2015

Related Party Transactions [Abstract]

Consolidation, Subsidiaries or Other Investments, Consolidated Entities, Policy [Policy Text Block]

We account for the difference between the carrying amount of our investment in ONEOK Partners and the underlying book value arising from issuance of common units by ONEOK Partners as an equity transaction. If ONEOK Partners issues common units at a price different than our carrying value per unit, we account for the premium or deficiency as an adjustment to paid-in capital. As a result of ONEOK Partners’ issuance of common units, we recognized a decrease to paid-in capital of approximately $34.4 million, net of taxes, for the nine months ended September 30, 2015.

Cash Distributions

Cash Distributions - We receive distributions from ONEOK Partners on the common and Class B units we own and the 2 percent general partner interest, which includes our incentive distribution rights. Under the Partnership Agreement, distributions are made to the partners with respect to each calendar quarter in an amount equal to 100 percent of available cash as defined in the Partnership Agreement. Available cash generally will be distributed 98 percent to limited partners and 2 percent to the general partner. The general partner’s percentage interest in quarterly distributions is increased after certain specified target levels are met during the quarter. Under the incentive distribution provisions, as set forth in the Partnership Agreement the general partner receives:

• 15 percent of amounts distributed in excess of $0.3025 per unit;

• 25 percent of amounts distributed in excess of $0.3575 per unit; and

• 50 percent of amounts distributed in excess of $0.4675 per unit.

Allocation of Costs Incurred by Related Party, Policy [Policy Text Block]

We provide a variety of services to our affiliates, including cash management and financial services, employee benefits, legal and administrative services by our employees and management, insurance and office space leased in our headquarters building and other field locations. Where costs are incurred specifically on behalf of an affiliate, the costs are billed directly to the affiliate by us. In other situations, the costs may be allocated to the affiliates through a variety of methods, depending upon the nature of the expenses and the activities of the affiliates. Beginning in the second quarter 2014, we allocate substantially all of our general overhead costs to ONEOK Partners as a result of the separation of our natural gas distribution business and the wind down of our energy services business in the first quarter 2014. For the first quarter 2014, it is not practicable to determine what these general overhead costs would have been on a stand-alone basis.

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CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Operating Activities
Net income	$ 407,411	$ 461,543
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	261,241	225,483
Charges attributable to exit activities	0	1,739
Equity in net earnings from investments	(93,205)	(6,747)
Distributions received from unconsolidated affiliates	92,042	84,298
Deferred income taxes	124,615	96,044
Share-based compensation expense	13,732	23,359
Pension and postretirement benefit expense, net of contributions	10,145	14,282
Allowance for equity funds used during construction	(1,718)	(13,947)
Loss (gain) on sale of assets	610	(1,533)
Changes in assets and liabilities:
Accounts receivable	157,742	156,555
Natural gas and natural gas liquids in storage	(8,174)	(43,351)
Accounts payable	(191,542)	(111,186)
Commodity imbalances, net	25,728	(33,214)
Settlement of exit activities liabilities	(31,207)	(38,627)
Energy marketing and risk management assets and liabilities	(45,240)	27,924
Accrued interest	3,577	(6,390)
Other assets and liabilities, net	(30,680)	34,307
Cash provided by operating activities	695,077	870,539
Investing Activities
Capital expenditures (less allowance for equity funds used during construction)	(930,316)	(1,204,386)
Cash paid for acquisitions	0	(14,000)
Contributions to unconsolidated affiliates	(27,540)	(1,063)
Distributions received from unconsolidated affiliates in excess of cumulative earnings	25,111	24,925
Proceeds from sale of assets	3,171	2,388
Other	(12,607)	0
Cash used in investing activities	(942,181)	(1,192,136)
Financing Activities
Borrowing (repayment) of notes payable, net	(768,024)	(564,462)
Issuance of ONE Gas debt, net of discounts	0	1,199,994
Issuance of long-term debt, net of discounts	1,291,506	0
ONE Gas long-term debt financing costs	0	(9,663)
Debt financing costs	(17,126)	0
Repayment of long-term debt	(5,795)	(555,768)
Issuance of common stock	13,839	12,908
Issuance of common units, net of issuance costs	375,660	947,472
Dividends paid	(380,498)	(321,051)
Cash of ONE Gas at separation	0	(60,000)
Distributions to noncontrolling interests	(396,847)	(325,158)
Cash provided by financing activities	112,715	324,272
Change in cash and cash equivalents	(134,389)	2,675
Change in cash and cash equivalents included in discontinued operations	(52)	3,163
Change in cash and cash equivalents included in continuing operations	(134,441)	5,838
Cash and cash equivalents at beginning of period	172,812	145,565
Cash and cash equivalents at end of period	$ 38,371	$ 151,403

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SEGMENTS SEGMENTS (Policies)

9 Months Ended

Sep. 30, 2015

Segment Accounting Policies [Abstract]

Segments Accounting Policies [Text Block]

Accounting Policies - We evaluate performance based principally on each segment’s operating income and equity earnings. The accounting policies of the segments are described in Note A of the Notes to Consolidated Financial Statements in our Annual Report. Intersegment and affiliate sales are recorded on the same basis as sales to unaffiliated customers and are discussed further in Note M. Net margin is comprised of total revenues less cost of sales and fuel. Cost of sales and fuel includes commodity purchases, fuel, storage and transportation costs. Revenues from sales and services provided by ONEOK Partners to our former natural gas distribution business prior to the separation and to our former energy services business prior to the completion of the wind down, which were previously eliminated in consolidation, are now reported as sales to affiliated customers for the nine months ended September 30, 2014, and are no longer eliminated in consolidation. Revenues from sales and services provided by ONEOK Partners to our former natural gas distribution business after the separation are reported as sales to unaffiliated customers as these now represent third-party transactions.

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ONEOK PARTNERS (Tables)

9 Months Ended

Sep. 30, 2015

Related Party Transaction [Line Items]

ONEOK Partners' transactions

Ownership Interestin ONEOK Partners - Our ownership interest in ONEOK Partners is shown in the table below at September 30, 2015:

General partner interest	2.0	%
Limited partner interest (a)	39.2	%
Total ownership interest	41.2	%

(a) - Represents 41.3 million common units and approximately 73.0 million Class B units, which are convertible, at our option, into common units.

ONEOK Partners' Distributions Paid

The following table shows ONEOK Partners’ distributions paid in the periods indicated:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2015		2014		2015		2014
	(Thousands, except per unit amounts)
Distribution per unit	$	0.79	$	0.76	$	2.37	$	2.235
General partner distributions	$	6,081	$	5,501	$	17,950	$	15,361
Incentive distributions	91,794		80,381		270,962		220,547
Distributions to general partner	97,875		85,882		288,912		235,908
Limited partner distributions to ONEOK	73,302		70,519		219,907		207,381
Limited partner distributions to noncontrolling interest	132,862		118,644		388,655		324,805
Total distributions paid	$	304,039	$	275,045	$	897,474	$	768,094

ONEOK Partners' Distributions Declared

The following table shows ONEOK Partners’ distributions declared for the periods indicated and paid within 45 days of the end of the period:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2015		2014		2015		2014
	(Thousands, except per unit amounts)
Distribution per unit	$	0.79	$	0.775	$	2.37	$	2.280
General partner distributions	$	6,660	$	5,683	$	18,696	$	16,195
Incentive distributions	100,538		84,452		282,221		236,744
Distributions to general partner	107,198		90,135		300,917		252,939
Limited partner distributions to ONEOK	90,323		71,911		236,927		211,557
Limited partner distributions to noncontrolling interest	135,480		122,105		396,925		345,255
Total distributions declared	$	333,001	$	284,151	$	934,769	$	809,751

Affiliated Entity [Member]

Related Party Transaction [Line Items]

ONEOK Partners' transactions

The following table shows ONEOK Partners’ transactions with us for the periods indicated:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2015		2014		2015		2014
	(Thousands of dollars)
Revenues	$	—	$	—	$	—	$	53,526
Expenses
Cost of sales and fuel	$	—	$	—	$	—	$	10,835
Operating expenses	89,342		84,221		265,611		240,172
Total expenses	$	89,342	$	84,221	$	265,611	$	251,007

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EQUITY (Details) - $ / shares	3 Months Ended					9 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Common Stock, Dividends, Per Share, Cash Paid		$ 0.605	$ 0.605	$ 0.605		$ 1.815	$ 1.535
Common Stock, Dividends, Per Share, Declared		$ 0.605			$ 0.575	$ 1.815	$ 1.535
Subsequent Event [Member]
Common Stock, Dividends, Per Share, Declared	$ 0.615
Dividends Payable, Date of Record	Nov. 02, 2015
Dividends Payable, Date to be Paid	Nov. 13, 2015

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CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Revenues
Commodity sales	$ 1,484,350	$ 2,754,495	$ 4,642,320	$ 8,276,333
Services	414,596	365,650	1,189,984	1,073,990
Total revenues	1,898,946	3,120,145	5,832,304	9,350,323
Cost of sales and fuel	1,360,809	2,583,204	4,307,766	7,807,275
Net margin	538,137	536,941	1,524,538	1,543,048
Operating expenses
Operations and maintenance	146,979	153,408	442,179	433,457
Depreciation and amortization	88,299	74,588	261,241	214,129
General taxes	17,198	19,087	66,366	60,171
Total operating expenses	252,476	247,083	769,786	707,757
Gain (loss) on sale of assets	(726)	1,534	(610)	1,533
Operating income	284,935	291,392	754,142	836,824
Equity in net earnings (loss) from investments (Note L)	32,244	(52,347)	93,205	6,747
Allowance for equity funds used during construction	177	1,723	1,718	13,947
Other income	71	100	249	3,117
Other expense	(7,508)	(2,506)	(7,754)	(27,827)
Interest expense (net of capitalized interest of $8,851, $14,303, $26,008 and $41,446, respectively)	(106,923)	(86,052)	(306,057)	(269,704)
Income before income taxes	202,996	152,310	535,503	563,104
Income taxes	(38,298)	(37,858)	(123,948)	(95,155)
Income from continuing operations	164,698	114,452	411,555	467,949
Income (loss) from discontinued operations, net of tax (Note B)	(3,860)	(171)	(4,144)	(6,406)
Net income	160,838	114,281	407,411	461,543
Less: Net income attributable to noncontrolling interests	78,681	49,823	187,949	241,980
Net income attributable to ONEOK	82,157	64,458	219,462	219,563
Amounts attributable to ONEOK:
Income from continuing operations	86,017	64,629	223,606	225,969
Income (loss) from discontinued operations	(3,860)	(171)	(4,144)	(6,406)
Net income attributable to ONEOK	$ 82,157	$ 64,458	$ 219,462	$ 219,563
Basic earnings per share:
Income from continuing operations (Note J)	$ 0.41	$ 0.31	$ 1.06	$ 1.08
Income (loss) from discontinued operations	(0.02)	0.00	(0.02)	(0.03)
Net income	0.39	0.31	1.04	1.05
Diluted earnings per share:
Income from continuing operations (Note J)	0.41	0.31	1.06	1.07
Income (loss) from discontinued operations	(0.02)	0.00	(0.02)	(0.03)
Net income	$ 0.39	$ 0.31	$ 1.04	$ 1.04
Average shares (thousands)
Basic	210,296	209,489	210,138	209,341
Diluted	210,524	210,759	210,509	210,482
Dividends declared per share of common stock	$ 0.605	$ 0.575	$ 1.815	$ 1.535

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ACQUISITIONS ACQUISITIONS (Details) $ in Millions	12 Months Ended
	Dec. 31, 2014 USD ($) Rate
Mesquite Pipeline [Member]
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired | Rate	100.00%
West Texas LPG and Mesquite Systems [Member]
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Less Noncontrolling Interest	$ 800
Business Acquisition, Effective Date of Acquisition	Nov. 28, 2014
West Texas LPG Pipeline Limited Partnership [Member]
Business Acquisition [Line Items]
Business Acquisition, Description of Acquired Entity	80 percent interest

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CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Current assets
Cash and cash equivalents	$ 38,371	$ 172,812
Accounts receivable, net	586,157	745,494
Materials and supplies	62,604	55,833
Natural gas and natural gas liquids in storage	142,308	134,134
Commodity imbalances	30,602	64,788
Other current assets	76,129	117,466
Assets of discontinued operations (Note B)	16,619	16,717
Total current assets	952,790	1,307,244
Property, plant and equipment
Property, plant and equipment	14,457,280	13,602,647
Accumulated depreciation and amortization	2,178,687	1,940,210
Net property, plant and equipment	12,278,593	11,662,437
Investments and other assets
Investments in unconsolidated affiliates	1,137,059	1,132,653
Goodwill and intangible assets	1,020,233	1,014,740
Other assets	115,716	124,679
Assets of discontinued operations (Note B)	3,907	20,020
Total investments and other assets	2,276,915	2,292,092
Total assets	15,508,298	15,261,773
Current liabilities
Current maturities of long-term debt	660,650	10,650
Notes payable (Note F)	287,272	1,055,296
Accounts payable	620,568	891,413
Commodity imbalances	96,192	104,650
Accrued interest	108,454	104,877
Other current liabilities	157,705	180,558
Liabilities of discontinued operations (Note B)	29,980	44,901
Total current liabilities	1,960,821	2,392,345
Long-term debt, excluding current maturities (Note G)	7,773,756	7,150,142
Deferred credits and other liabilities
Deferred income taxes	1,437,087	1,395,222
Other deferred credits	278,731	281,757
Liabilities of discontinued operations (Note B)	20,598	36,424
Total deferred credits and other liabilities	$ 1,736,416	$ 1,713,403
Commitments and contingencies (Note N)
ONEOK shareholders' equity:
Common stock, $0.01 par value: authorized 600,000,000 shares; issued 245,811,180 shares and outstanding 209,273,336 shares at September 30, 2015; issued 245,811,180 shares and outstanding 208,322,247 shares at December 31, 2014	$ 2,458	$ 2,458
Paid-in capital	1,477,631	1,541,583
Accumulated other comprehensive loss (Note I)	(136,112)	(136,353)
Retained earnings	0	138,128
Treasury stock, at cost: 36,537,844 shares at September 30, 2015, and 37,488,933 shares at December 31, 2014	(929,505)	(953,701)
Total ONEOK shareholders' equity	414,472	592,115
Noncontrolling interests in consolidated subsidiaries	3,622,833	3,413,768
Total equity	4,037,305	4,005,883
Total liabilities and equity	$ 15,508,298	$ 15,261,773

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SEGMENTS (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Segment Reporting Information [Line Items]
Segment Reporting, Disclosure of Major Customers	For the three months ended September 30, 2015, ONEOK Partners had no single customer from which it received 10 percent or more of our consolidated revenues.	For the three months ended September 30, 2014, ONEOK Partners had no single customer from which it received 10 percent or more of our consolidated revenues.	For the nine months ended September 30, 2015, ONEOK Partners had no single customer from which it received 10 percent or more of our consolidated revenues.	For the nine months ended September 30, 2014, ONEOK Partners had no single customer from which it received 10 percent or more of our consolidated revenues.
Total revenues	$ 1,898,946	$ 3,120,145	$ 5,832,304	$ 9,350,323
Net Margin	538,137	536,941	1,524,538	1,543,048
Operating Costs	164,177	172,495	508,545	493,628
Depreciation and amortization	88,299	74,588	261,241	214,129
Gain (loss) on sale of assets	(726)	1,534	(610)	1,533
Operating income	284,935	291,392	754,142	836,824
Equity in net earnings (loss) from investments	32,244	(52,347)	93,205	6,747
Investments in unconsolidated affiliates	1,137,059	1,128,509	1,137,059	1,128,509	$ 1,132,653
Total assets	15,508,298	14,312,196	15,508,298	14,312,196	15,261,773
Noncontrolling interests in consolidated subsidiaries	3,622,833	3,136,163	3,622,833	3,136,163	$ 3,413,768
Capital expenditures	300,868	382,185	930,316	1,204,386
Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Total revenues	434,336	777,802	1,350,021	2,263,292
Net Margin	140,655	178,171	402,482	486,695
Operating Costs	61,162	64,279	193,922	188,489
Depreciation and amortization	37,286	31,327	109,035	89,612
Gain (loss) on sale of assets	132	324	328	277
Operating income	42,339	82,889	99,853	208,871
Equity in net earnings (loss) from investments	4,350	(71,069)	13,511	(60,484)
Investments in unconsolidated affiliates	253,548	253,930	253,548	253,930
Total assets	5,206,987	4,415,814	5,206,987	4,415,814
Noncontrolling interests in consolidated subsidiaries	4,066	4,394	4,066	4,394
Capital expenditures	231,835	214,917	692,570	506,016
Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Total revenues	1,611,454	2,734,520	4,956,421	8,111,642
Net Margin	321,772	282,963	902,382	818,086
Operating Costs	74,464	76,946	234,120	218,129
Depreciation and amortization	39,317	31,661	118,044	89,848
Gain (loss) on sale of assets	(498)	(535)	(579)	(572)
Operating income	207,493	173,821	549,639	509,537
Equity in net earnings (loss) from investments	10,912	4,351	27,585	13,574
Investments in unconsolidated affiliates	484,403	484,238	484,403	484,238
Total assets	8,041,064	7,337,688	8,041,064	7,337,688
Noncontrolling interests in consolidated subsidiaries	161,210	0	161,210	0
Capital expenditures	52,807	153,785	185,360	637,524
Natural Gas Liquids [Member] | Natural Gas Liquids for Regulated Segment [Member]
Segment Reporting Information [Line Items]
Total revenues	252,800	190,300	690,100	479,400
Net Margin	140,100	94,300	392,700	263,400
Operating income	80,300	46,400	218,800	126,000
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Total revenues	82,997	79,160	246,658	265,938
Net Margin	75,369	73,399	218,599	242,359
Operating Costs	26,674	27,998	79,156	82,747
Depreciation and amortization	10,914	10,913	32,484	32,623
Gain (loss) on sale of assets	(77)	1,746	(76)	1,663
Operating income	37,704	36,234	106,883	128,652
Equity in net earnings (loss) from investments	16,982	14,371	52,109	53,657
Investments in unconsolidated affiliates	399,108	390,341	399,108	390,341
Total assets	1,837,776	1,832,368	1,837,776	1,832,368
Noncontrolling interests in consolidated subsidiaries	0	0	0	0
Capital expenditures	14,718	10,650	39,923	25,987
Natural Gas Pipelines [Member] | Natural Gas Pipelines for Regulated Segment [Member]
Segment Reporting Information [Line Items]
Total revenues	65,100	65,200	198,500	214,800
Net Margin	57,900	57,400	175,900	185,500
Operating income	24,700	23,400	77,800	84,600
Corporate Elimination [Member]
Segment Reporting Information [Line Items]
Total revenues	(229,841)	(471,337)	(720,796)	(1,290,549)
Net Margin	341	2,408	1,075	(4,092)
Operating Costs	1,877	3,272	1,347	4,263
Depreciation and amortization	782	687	1,678	2,046
Gain (loss) on sale of assets	(283)	(1)	(283)	165
Operating income	(2,601)	(1,552)	(2,233)	(10,236)
Equity in net earnings (loss) from investments	0	0	0	0
Investments in unconsolidated affiliates	0	0	0	0
Total assets	422,471	726,326	422,471	726,326
Noncontrolling interests in consolidated subsidiaries	3,457,557	3,131,769	3,457,557	3,131,769
Capital expenditures	1,508	2,833	12,463	34,859
Discontinued Operations [Member] | Corporate Elimination [Member]
Segment Reporting Information [Line Items]
Total assets	20,500	84,200	20,500	84,200
Capital expenditures				23,900
Sales to unaffiliated customers
Segment Reporting Information [Line Items]
Total revenues	1,898,946	3,120,145	5,832,304	9,296,797
Sales to unaffiliated customers | Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Total revenues	294,948	374,403	862,462	1,095,531
Sales to unaffiliated customers | Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Total revenues	1,522,224	2,667,939	4,726,617	7,950,930
Sales to unaffiliated customers | Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Total revenues	81,246	77,027	241,605	247,420
Sales to unaffiliated customers | Corporate Elimination [Member]
Segment Reporting Information [Line Items]
Total revenues	528	776	1,620	2,916
Sales to affiliated customers
Segment Reporting Information [Line Items]
Total revenues				53,526
Sales to affiliated customers | Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Total revenues				41,214
Sales to affiliated customers | Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Total revenues				0
Sales to affiliated customers | Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Total revenues				12,312
Sales to affiliated customers | Corporate Elimination [Member]
Segment Reporting Information [Line Items]
Total revenues				0
Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	0	0	0	0
Operating Segments [Member] | Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Total revenues	139,388	403,399	487,559	1,126,547
Operating Segments [Member] | Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Total revenues	89,230	66,581	229,804	160,712
Operating Segments [Member] | Natural Gas Liquids [Member] | Natural Gas Liquids for Regulated Segment [Member]
Segment Reporting Information [Line Items]
Total revenues	204,700	170,100	556,400	417,000
Operating Segments [Member] | Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Total revenues	1,751	2,133	5,053	6,206
Operating Segments [Member] | Corporate Elimination [Member]
Segment Reporting Information [Line Items]
Total revenues	$ (230,369)	$ (472,113)	$ (722,416)	$ (1,293,465)

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES (Tables)

9 Months Ended

Sep. 30, 2015

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair value of derivatives

The following table sets forth the fair values of derivative instruments for our continuing operations for the periods indicated:

	September 30, 2015					December 31, 2014
	Assets (a)		(Liabilities) (a)			Assets (a)		(Liabilities) (a)
	(Thousands of dollars)
Derivatives designated as hedging instruments
Commodity contracts
Financial contracts	$	45,534	$	(5,108	)	$	43,234	$	(1,137	)
Physical contracts	4,866		—			9,922		—
Interest-rate contracts	—		(13,648		)	2,288		(44,843		)
Total derivatives designated as hedging instruments	50,400		(18,756		)	55,444		(45,980		)
Derivatives not designated as hedging instruments
Commodity contracts
Financial contracts	1,021		(791		)	—		—
Physical contracts	—		—			—		(23		)
Total derivatives not designated as hedging instruments	1,021		(791		)	—		(23		)
Total derivatives	$	51,421	$	(19,547	)	$	55,444	$	(46,003	)

(a) - Included on a net basis in other current assets, other assets or other current liabilities in our Consolidated Balance Sheets.

Notional amounts of derivative instruments

The following table sets forth the notional quantities for derivative instruments for our continuing operations for the periods indicated:

		September 30, 2015					December 31, 2014
	Contract Type	Purchased/ Payor		Sold/ Receiver			Purchased/ Payor		Sold/ Receiver
Derivatives designated as hedging instruments:
Cash flow hedges
Fixed price
- Natural gas (Bcf)	Futures and swaps	—		(38.7		)	—		(41.2		)
- Crude oil and NGLs (MMBbl)	Futures, forwards and swaps	—		(3.5		)	—		(0.5		)
Basis
- Natural gas (Bcf)	Futures and swaps	—		(38.7		)	—		(41.2		)
Interest-rate contracts (Millions of dollars)	Forward-starting swaps	$	400.0	$	—		$	900.0	$	—
Derivatives not designated as hedging instruments:
Fixed price
- Crude oil and NGLs (MMBbl)	Futures, forwards and swaps	0.5		(0.5		)	—		—

Schedule of cash flow hedging instruments effect on comprehensive income (loss)

The following table sets forth the unrealized effect of cash flow hedges recognized in other comprehensive income (loss) for the periods indicated:

Derivatives in Cash Flow Hedging Relationships	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2015			2014			2015			2014
	(Thousands of dollars)
Continuing Operations
Commodity contracts	$	36,559		$	17,133		$	47,650		$	(24,743	)
Interest-rate contracts	(20,610		)	(9,755		)	(26,277		)	(56,849		)
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion) for continuing operations	$	15,949		$	7,378		$	21,373		$	(81,592	)

Schedule of cash flow hedging instruments effect on income

The following table sets forth the effect of cash flow hedges in our Consolidated Statements of Income for the periods indicated:

Derivatives in Cash Flow Hedging Relationships	Location of Gain (Loss) Reclassified from  Accumulated Other Comprehensive Income (Loss) into Net Income (Effective Portion)	Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2015			2014			2015			2014
		(Thousands of dollars)
Continuing Operations
Commodity contracts	Commodity sales revenues	$	22,770		$	(355	)	$	54,020		$	(31,961	)
Interest-rate contracts	Interest expense	(4,554		)	(3,525		)	(12,869		)	(18,372		)
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income on derivatives (effective portion) for continuing operations		$	18,216		$	(3,880	)	$	41,151		$	(50,333	)

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UNCONSOLIDATED AFFILIATES

9 Months Ended

Sep. 30, 2015

Equity Method Investments and Joint Ventures [Abstract]

UNCONSOLIDATED AFFILIATES

L. UNCONSOLIDATED AFFILIATES

Equity in Net Earnings from Investments -The following table sets forth ONEOK Partners’ equity in net earnings from investments for the periods indicated:

	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2015		2014			2015		2014
	(Thousands of dollars)
Share of investee earnings
Northern Border Pipeline	$	16,156	$	14,371		$	51,131	$	53,657
Overland Pass Pipeline Company	10,538		3,856			27,048		12,708
Other (a)	5,550		(17,153		)	15,026		(6,197		)
Total share of investee earnings	32,244		1,074			93,205		60,168
Impairment of investment in Bighorn Gas Gathering	—		(53,421		)	—		(53,421		)
Equity in net earnings (loss) from investments	$	32,244	$	(52,347	)	$	93,205	$	6,747

(a) - Includes proportionate share of investee impairment of long-lived assets charge on Bighorn Gas Gathering of $23.0 million for the three and nine months ended September 30, 2014.

Unconsolidated Affiliates Financial Information - The following table sets forth summarized combined financial information of ONEOK Partners’ unconsolidated affiliates for the periods indicated:

	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2015		2014			2015		2014
	(Thousands of dollars)
Income Statement
Operating revenues	$	135,474	$	126,218		$	390,793	$	403,006
Operating expenses (a)	$	64,786	$	123,620		$	178,324	$	247,169
Net income (loss) (a)	$	67,121	$	(5,119	)	$	196,123	$	134,432
Distributions paid to ONEOK Partners	$	36,370	$	31,574		$	117,153	$	109,223

(a) - Includes long-lived asset impairment charge on Bighorn Gas Gathering for the three and nine months ended September 30, 2014.

ONEOK Partners incurred expenses in transactions with unconsolidated affiliates of $28.4 million and $15.0 million for the three months ended September 30, 2015 and 2014, respectively, and $74.2 million and $43.5 million for the nine months ended September 30, 2015 and 2014, respectively, primarily related to Overland Pass Pipeline Company and Northern Border Pipeline Company. Accounts payable to ONEOK Partners’ equity method investees at September 30, 2015, and December 31, 2014, were $9.4 million and $20.5 million, respectively.

Roadrunner Gas Transmission - In March 2015, ONEOK Partners entered into a 50-50 joint venture named Roadrunner Gas Transmission (Roadrunner) with a subsidiary of Fermaca Infrastructure B.V. (Fermaca), a Mexico City-based natural gas infrastructure company, to construct a pipeline to transport natural gas from the Permian Basin in West Texas to the Mexican border near El Paso, Texas. During the nine months ended September 30, 2015, ONEOK Partners contributed approximately $30 million to Roadrunner.

Powder River Basin Equity Method Investments - Crude oil and natural gas producers have primarily focused their development efforts on crude oil and NGL-rich supply basins rather than areas with dry natural gas production, such as the coal-bed methane areas in the Powder River Basin. The reduced coal-bed methane development activities and natural production declines in the dry natural gas formations of the Powder River Basin have resulted in lower natural gas volumes available to be gathered. While the reserve potential in the dry natural gas formations of the Powder River Basin still exists, future drilling and development in this area will be affected by commodity prices and producers’ alternative prospects.

The current commodity price environment has caused natural gas producers to reduce drilling for natural gas, which we expect will slow volume growth or reduce volumes of natural gas delivered to systems owned by ONEOK Partners’ Powder River Basin equity method investments. A continued decline in volumes gathered in the coal-bed methane area of the Powder River Basin may reduce ONEOK Partners’ ability to recover the carrying value of its equity investments in this area and could result in noncash charges to earnings. The net book value of ONEOK Partners’ equity method investments in this dry natural gas area is $214.2 million, which includes $130.5 million of equity method goodwill.

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Tables)

9 Months Ended

Sep. 30, 2015

Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]

Accumulated other comprehensive income (loss)

The following table sets forth the balance in accumulated other comprehensive income (loss) for the period indicated:

	Unrealized Gains (Losses) on Risk- Management Assets/Liabilities (a)			Unrealized Holding Gains (Losses) on Investment Securities (a)			Pension and Postretirement Benefit Plan Obligations (a) (b)			Accumulated Other Comprehensive Income (Loss) (a)
	(Thousands of dollars)
January 1, 2015	$	(37,349	)	$	955		$	(99,959	)	$	(136,353	)
Other comprehensive income (loss) before reclassifications	3,661			(955		)	65			2,771
Amounts reclassified from accumulated other comprehensive income (loss)	(9,785		)	—			7,255			(2,530		)
Net current period other comprehensive income (loss) attributable to ONEOK	(6,124		)	(955		)	7,320			241
September 30, 2015	$	(43,473	)	$	—		$	(92,639	)	$	(136,112	)

(a) All amounts are presented net of tax.

(b) Includes amounts related to supplemental executive retirement plan.

Disclosure of Reclassification Amount [Text Block]

The following table sets forth the effect of reclassifications from accumulated other comprehensive income (loss) in our Consolidated Statements of Income for the periods indicated:

Details about Accumulated Other Comprehensive Income (Loss) Components	Three Months Ended						Nine Months Ended						Affected Line Item in the Consolidated Statements of Income
	September 30,						September 30,
	2015			2014			2015			2014
	(Thousands of dollars)
Unrealized (gains) losses on risk-management assets/liabilities
Commodity contracts	$	(22,770	)	$	355		$	(54,020	)	$	31,961		Commodity sales revenues
Interest-rate contracts	4,554			3,525			12,869			18,372			Interest expense
	(18,216		)	3,880			(41,151		)	50,333			Income before income taxes
	2,957			(748		)	5,621			(9,845		)	Income tax expense
	(15,259		)	3,132			(35,530		)	40,488			Income from continuing operations
	—			—			—			7,682			Income (loss) from discontinued operations
	(15,259		)	3,132			(35,530		)	48,170			Net income
Noncontrolling interests	(10,150		)	1,928			(25,745		)	24,574			Less: Net income attributable to noncontrolling interests
	$	(5,109	)	$	1,204		$	(9,785	)	$	23,596		Net income attributable to ONEOK
Pension and postretirement benefit plan obligations (a)
Amortization of net loss	$	4,422		$	4,009		$	13,268		$	11,936
Amortization of unrecognized prior service cost	(392		)	(368		)	(1,176		)	(1,102		)
	4,030			3,641			12,092			10,834			Income before income taxes
	(1,612		)	(1,456		)	(4,837		)	(4,334		)	Income tax expense
	2,418			2,185			7,255			6,500			Income from continuing operations
	—			—			—			1,648			Income from discontinued operations
	$	2,418		$	2,185		$	7,255		$	8,148		Net income attributable to ONEOK
Total reclassifications for the period attributable to ONEOK	$	(2,691	)	$	3,389		$	(2,530	)	$	31,744		Net income attributable to ONEOK

(a) These components of accumulated other comprehensive income (loss) are included in the computation of net periodic benefit cost. See Note K for additional detail of our net periodic benefit cost.

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COMMITMENTS AND CONTINGENCIES

9 Months Ended

Sep. 30, 2015

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

N. COMMITMENTS AND CONTINGENCIES

Environmental Matters - ONEOK Partners is subject to multiple historical preservation, wildlife preservation and environmental laws and/or regulations that affect many aspects of our present and future operations. Regulated activities include, but are not limited to, those involving air emissions, storm water and wastewater discharges, handling and disposal of solid and hazardous wastes, wetlands preservation, hazardous materials transportation, and pipeline and facility construction. These laws and regulations require ONEOK Partners to obtain and/or comply with a wide variety of environmental clearances, registrations, licenses, permits and other approvals. Failure to comply with these laws, regulations, licenses and permits may expose ONEOK Partners to fines, penalties and/or interruptions in its operations that could be material to our results of operations. For example, if a leak or spill of hazardous substances or petroleum products occurs from pipelines or facilities that ONEOK Partners owns, operates or otherwise uses, ONEOK Partners could be held jointly and severally liable for all resulting liabilities, including response, investigation and cleanup costs, which could affect materially our results of operations and cash flows. In addition, emissions controls and/or other regulatory or permitting mandates under the Clean Air Act and other similar federal and state laws could require unexpected capital expenditures at ONEOK Partners’ facilities. We cannot assure that existing environmental statutes and regulations will not be revised or that new regulations will not be adopted or become applicable to ONEOK Partners.

In June 2013, the Executive Office of the President of the United States (the President) issued the President’s Climate Action Plan, which includes, among other things, plans for further regulatory actions to reduce carbon emissions from various sources. On March 28, 2014, the President released the Climate Action Plan - Strategy to Reduce Methane Emissions (Methane Strategy) that lists a number of actions the federal agencies will undertake to continue to reduce above-ground methane emissions from several industries, including the oil and natural gas sectors. The proposed measures outlined in the Methane Strategy include, without limitation, the following: collaboration with the states to encourage emission reductions; standards to minimize natural gas venting and flaring on public lands; policy recommendations for reducing emissions from energy infrastructure to increase the performance of the nation’s energy transmission, storage and distribution systems; and continued efforts by PHMSA to require pipeline operators to take steps to eliminate leaks and prevent accidental methane releases and evaluate the progress of states in replacing cast-iron pipelines. The impact of any such regulatory actions on ONEOK Partners’ facilities and operations is unknown. ONEOK Partners continues to monitor these developments and the impact they may have on its businesses. Revised or additional statutes or regulations that result in increased compliance costs or additional operating restrictions could have a significant impact on our business, financial position, results of operations and cash flows.

ONEOK Partners’ expenditures for environmental assessment, mitigation, remediation and compliance to date have not been significant in relation to our financial position, results of operations or cash flows, and its expenditures related to environmental matters have had no material effects on earnings or cash flows during the three and nine months ended September 30, 2015 and 2014.

In April 2014, the EPA and the United States Army Corps of Engineers proposed a joint rule-making to redefine the definition of “Waters of the United States” under the Clean Water Act. The final rule was published on June 29, 2015, and became effective on August 28, 2015. The final rule is not expected to result in material impacts on ONEOK Partners’ projects, facilities and operations.

The EPA’s “Triggering and Tailoring Rules” regulate GHG emissions at new or modified facilities that meet certain criteria. Affected facilities are required to review best available control technology (BACT), conduct air-quality analysis, impact analysis and public reviews with respect to such emissions. At current emission threshold levels, this rule has had a minimal impact on ONEOK Partners’ existing facilities. In addition, on June 23, 2014, the Supreme Court of the United States (Supreme Court), in a case styled, Utility Air Regulatory Group v. EPA, 530 U.S. (2014), held that an industrial facility’s potential to emit GHG emissions alone cannot subject a facility to the permitting requirements for major stationary source provisions of the Clean Air Act. The decision invalidated the EPA’s current Triggering and Tailoring Rule for GHG Prevention of Significant Deterioration (PSD) and Title V requirements as applied to facilities considered major sources only for GHGs (referred to as Step 2 sources). However, the Supreme Court also ruled that to the extent a source pursues a capital project (new construction or expansion of existing facility), which otherwise subjects the source to major source PSD permitting for conventional criteria pollutants, the permitting authorities may impose BACT analysis and emission limits for GHGs from those sources.

In April 2015, the United States Court of Appeals for the District of Columbia Circuit (D.C. Circuit), on remand from the Supreme Court, issued its further Order following the Supreme Court’s decision in Utility Air Regulatory Group v. EPA. The D.C. Circuit’s Order included the following: (1) it formally vacated EPA regulations implementing the Tailoring Rule to the extent that they require a stationary source to obtain a PSD or Title V permit based solely on the source’s GHG emissions; and (2) ordered the EPA to consider whether any further revisions to its regulations are appropriate in light of the Supreme Court’s decision.On April 30, 2015, the EPA issued a direct final rule to allow for the rescission of Clean Air Act PSD permits issued by the EPA or delegated state and local permitting authorities under Step 2 of the GHG Tailoring Rule. The direct final rule was to become effective unless adverse comments were received by the EPA. On August 19, 2015, the EPA published the direct final rule in the Federal Register to confirm that no adverse comments were received and that the rule was now in effect. We do not expect the direct final rule to have a material impact on ONEOK Partners’ existing operations or design decisions for new project applications.

In July 2011, the EPA issued a proposed rule that would change the air emissions New Source Performance Standards, also known as NSPS, and Maximum Achievable Control Technology requirements applicable to the oil and natural gas industry, including natural gas production, processing, transmission and underground storage sectors. In April 2012, the EPA released the final rule, which includes new NSPS and air toxic standards for a variety of sources within natural gas processing plants, oil and natural gas production facilities and natural gas transmission stations. The rule also regulates emissions from the hydraulic fracturing of wells for the first time. The NSPS final rule became effective in October 2012, but the dates for compliance vary and depend in part upon the type of affected facility and the date of construction, reconstruction or modification.

In September 2015, the EPA published several proposed rule-makings in the Federal Register that affect the oil and gas industry. The rule-makings included, but were not limited to, proposed amendments to the NSPS rule. The proposed amendments to the NSPS rule included, in part, the proposed direct regulation of methane emissions for the first time as an individual air pollutant from oil and gas sources, as part of the President’s Methane Strategy. Comments on the proposed rule-makings remain ongoing.

In October 2015, the EPA issued a prepublication version of a final rule-making to amend downward the National Ambient Air Quality Standards (NAAQS) for ground level ozone. The final rule requires revised designations of the areas in the various states for classification as in attainment or nonattainment for the new ozone NAAQS. Any areas determined to not attain the ozone NAAQS will implicate more strict air permitting requirements for new or modified sources that emit pollutants that contribute to ground level ozone.

At this time we do not anticipate a material impact to ONEOK Partners’ planned capital, operations and maintenance costs resulting from compliance with the current or pending regulations outlined above. However, the EPA may issue additional responses, amendments and/or policy guidance on the final rules, which could alter our present expectations. Generally, the EPA rule-makings will require expenditures for updated emissions controls, monitoring and record-keeping requirements at affected facilities. We do not expect these expenditures will have a material impact on our results of operations, financial position or cash flows.

Pipeline Safety - ONEOK Partners is subject to PHMSA regulations, including pipeline asset integrity-management regulations. The Pipeline Safety Improvement Act of 2002 requires pipeline companies operating high-pressure pipelines to perform integrity assessments on pipeline segments that pass through densely populated areas or near specifically designated high-consequence areas. In January 2012, The Pipeline Safety, Regulatory Certainty and Job Creation Act of 2011 was signed into law. The law increased maximum penalties for violating federal pipeline safety regulations and directs the DOT and Secretary of Transportation to conduct further review or studies on issues that may or may not be material to ONEOK Partners. These issues include, but are not limited to, the following:

• an evaluation on whether hazardous natural gas liquids and natural gas pipeline integrity-management requirements should be expanded beyond current high-consequence areas;

• a review of all natural gas and hazardous natural gas liquids gathering pipeline exemptions;

• a verification of records for pipelines in Class 3 and 4 locations and high-consequence areas to confirm maximum allowable operating pressures; and

• a requirement to test previously untested pipelines operating above 30 percent yield strength in high-consequence areas.

In October 2015, PHMSA issued a notice of proposed rule-making to its hazardous liquid pipeline safety regulations.  Among other things, the proposed regulations would expand the current leak-detection requirements, apply new, more conservative repair criteria and establish timelines for inspecting pipeline facilities potentially affected by an extreme weather event or natural disaster.  The proposal would also increase the stringency of integrity management program requirements and set deadlines for the use of internal inspection tools on certain systems.  Comments on the proposed rule-making are currently due by January 2016.  The potential capital and operating expenditures related to the referenced legislation and regulations are unknown, but we do not anticipate a material impact to ONEOK Partners’ planned capital, operations and maintenance costs resulting from compliance with the current or pending regulations.

Legal Proceedings - Gas Index Pricing Litigation - As previously reported, ONEOK and its subsidiary, ONEOK Energy Services Company, L.P. (OESC), along with several other energy companies, are defending multiple lawsuits arising from alleged market manipulation or false reporting of natural gas prices to natural gas-index publications alleged to have occurred prior to 2003. On April 10, 2013, the United States Court of Appeals for the Ninth Circuit reversed the summary judgments that had been granted in favor of ONEOK, OESC and other unaffiliated defendants in the following cases: Reorganized FLI, Learjet, Arandell, Heartland and NewPage. The Ninth Circuit also reversed the summary judgment that had been granted in favor of OESC on all state law claims asserted in the Sinclair case. On April 21, 2015, the United States Supreme Court affirmed the decision of the Ninth Circuit. The cases have now been remanded back to the trial court (the United States District Court for the District of Nevada) for further proceedings.

Because of the uncertainty surrounding the Gas Index Pricing Litigation, including an insufficient description of the purported classes and other related matters, we cannot reasonably estimate a range of potential exposures at this time. However, it is reasonably possible that the ultimate resolution of these matters could result in future charges that may be material to our results of operations.

Other Legal Proceedings - We and ONEOK Partners are party to various other litigation matters and claims that have arisen in the normal course of our operations. While the results of these various other litigation matters and claims cannot be predicted with certainty, we believe the reasonably possible losses from such matters, individually and in the aggregate, are not material. Additionally, we believe the probable final outcome of such matters will not have a material adverse effect on our consolidated results of operations, financial position or cash flows.

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CONSOLIDATED BALANCE SHEETS Parenthetical - $ / shares	Sep. 30, 2015	Dec. 31, 2014
Equity (Note H)
Common stock, shares, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares, authorized (in shares)	600,000,000	600,000,000
Common stock, shares, issued (in shares)	245,811,180	245,811,180
Common stock, shares, outstanding (in shares)	209,273,336	208,322,247
Treasury stock, shares (in shares)	36,537,844	37,488,933

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CONSOLIDATED STATEMENTS OF INCOME (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Interest Costs, Capitalized During Period	$ 8,851	$ 14,303	$ 26,008	$ 41,446

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LONG-TERM DEBT

9 Months Ended

Sep. 30, 2015

Long-term Debt, Unclassified [Abstract]

LONG-TERM DEBT

G. LONG-TERM DEBT

ONEOK Debt Issuance - In August 2015, we completed an underwritten public offering of $500 million, 7.5 percent senior notes due 2023. The net proceeds, after deducting underwriting discounts, commissions and other expenses, were approximately $487.1 million. We used the proceeds together with cash on hand to purchase $650 million of additional common units from ONEOK Partners.

The indenture governing ONEOK’s senior notes due 2023 includes an event of default upon the acceleration of other indebtedness of $100 million or more. Such an event of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of the outstanding senior notes due 2023 to declare those senior notes immediately due and payable in full. The indenture also contains a provision that allows the holders of the notes to require ONEOK to offer to repurchase all or any part of their notes if a change of control and a credit rating downgrade occur at a purchase price of 101 percent of the principal amount, plus accrued and unpaid interest, if any.

ONEOK may redeem the remaining balance of its senior notes due 2023 at a redemption price equal to the principal amount, plus accrued and unpaid interest, starting three months before the maturity date.  Prior to this date, ONEOK may redeem these senior notes in whole or in part, at any time prior to their maturity at a redemption price equal to the principal amount, plus accrued and unpaid interest and a make-whole premium.  The redemption price will never be less than 100 percent of the principal amount of the respective note plus accrued and unpaid interest to the redemption date.  ONEOK’s senior notes due 2023 are senior unsecured obligations, ranking equally in right of payment with all of ONEOK’s existing and future unsecured senior indebtedness.

ONEOK Partners Debt Issuance - In March 2015, ONEOK Partners completed an underwritten public offering of $800 million of senior notes, consisting of $300 million, 3.8 percent senior notes due 2020, and $500 million, 4.9 percent senior notes due 2025. The net proceeds, after deducting underwriting discounts, commissions and other expenses, were approximately $792.3 million. ONEOK Partners used the proceeds to repay amounts outstanding under its commercial paper program and for general partnership purposes.

These notes are governed by an indenture, dated September 25, 2006, between ONEOK Partners and Wells Fargo Bank, N.A., the trustee, as supplemented. The indenture does not limit the aggregate principal amount of debt securities that may be issued and provides that debt securities may be issued from time to time in one or more additional series. The indenture contains covenants including, among other provisions, limitations on ONEOK Partners’ ability to place liens on its property or assets and to sell and lease back its property. The indenture includes an event of default upon acceleration of other indebtedness of $100 million or more. Such events of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of any of ONEOK Partners’ outstanding senior notes to declare those notes immediately due and payable in full.

ONEOK Partners may redeem its 3.8 percent senior notes due 2020 and its 4.9 percent senior notes due 2025 from the March 2015 offering at par, plus accrued and unpaid interest to the redemption date, starting one month and three months, respectively, before their maturity dates. Prior to these dates, ONEOK Partners may redeem these notes, in whole or in part, at a redemption price equal to the principal amount, plus accrued and unpaid interest and a make-whole premium. The redemption price will never be less than 100 percent of the principal amount of the respective note plus accrued and unpaid interest to the redemption date. ONEOK Partners’ senior notes are senior unsecured obligations, ranking equally in right of payment with all of ONEOK Partners’ existing and future unsecured senior indebtedness, and structurally subordinate to any of the existing and future debt and other liabilities of any ONEOK Partners’ nonguarantor subsidiaries.

ONEOK Partners Debt Maturity - ONEOK Partners’ $650 million, 3.25 percent senior notes mature on February 1, 2016. The carrying amount of these notes is reflected in current portion of long-term debt in our Consolidated Balance Sheet as of September 30, 2015.

ONE Gas Debt Issuance - In January 2014, ONE Gas, which at the time was our wholly owned subsidiary, completed a private placement of three series of senior notes aggregating $1.2 billion, consisting of $300 million of five-year senior notes at 2.07 percent; $300 million of 10-year senior notes at 3.61 percent; and $600 million of 30-year senior notes at 4.658 percent. ONE Gas received approximately $1.19 billion from the offering, net of issuance costs. Our obligations related to the ONE Gas Senior Notes terminated in connection with the completion of the separation of ONE Gas.

ONEOK Debt Repayment - ONE Gas made a cash payment to us of approximately $1.13 billion from the proceeds of the ONE Gas senior notes offering. In February 2014, we retired approximately $152.5 million of the 4.25 percent senior notes due in 2022 through a tender offer. The total amount paid was approximately $150 million.

In February 2014, we called our $400 million, 5.2 percent senior notes due in 2015. The full repayment occurred in March 2014 and totaled $430.1 million, including accrued but unpaid interest to the redemption date. We recorded a loss on extinguishment of $24.8 million related to the debt retirements, which is included in other expense in our Consolidated Statements of Income.

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Document And Entity Information - shares	9 Months Ended
	Sep. 30, 2015	Oct. 26, 2015
Document Information [Line Items]
Entity Registrant Name	ONEOK INC /NEW/
Entity Central Index Key	0001039684
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		209,277,589
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q3
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2015

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EQUITY

9 Months Ended

Sep. 30, 2015

Equity [Abstract]

Stockholders' Equity Note Disclosure [Text Block]

H. EQUITY

Dividends - Dividends paid on our common stock to shareholders of record at the close of business on January 30, 2015, April 30, 2015, and August 3, 2015, were $0.605 per share in each instance.  A dividend of $0.615 per share was declared for shareholders of record at the close of business on November 2, 2015, payable November 13, 2015.

See Note M for a discussion of ONEOK Partners’ issuance of common units and distributions to noncontrolling interests.

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Net income	$ 160,838	$ 114,281	$ 407,411	$ 461,543
Other comprehensive income (loss), net of tax
Unrealized gains (losses) on energy marketing and risk-management assets/liabilities, net of tax of $(1,109), $(1,160), $(2,156) and $12,664, respectively	14,840	6,219	19,217	(72,627)
Realized (gains) losses in net income, net of tax of $2,957, $(748), $5,621 and $(14,966), respectively	(15,259)	3,132	(35,530)	48,170
Unrealized holding gains (losses) on available-for-sale securities, net of tax of $0, $(73), $648 and $36, respectively	0	107	(955)	(6)
Change in pension and postretirement benefit plan liability, net of tax of $(1,599), $(1,456), $(4,798) and $(5,379), respectively	2,441	2,185	7,320	8,069
Total other comprehensive income (loss), net of tax	2,022	11,643	(9,948)	(16,394)
Comprehensive income	162,860	125,924	397,463	445,149
Less: Comprehensive income attributable to noncontrolling interest	81,481	55,995	177,760	214,644
Comprehensive income attributable to ONEOK	$ 81,379	$ 69,929	$ 219,703	$ 230,505

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DISCONTINUED OPERATIONS

9 Months Ended

Sep. 30, 2015

Discontinued Operations [Abstract]

DISCONTINUED OPERATIONS

B. DISCONTINUED OPERATIONS

Separation of ONE Gas - On January 31, 2014, we completed the separation of ONE Gas, which consists of our former natural gas distribution business. ONEOK shareholders of record at the close of business on January 21, 2014, retained their shares of ONEOK stock and received one share of ONE Gas stock for every four shares of ONEOK stock owned in a transaction that was tax-free to ONEOK and its shareholders. We retained no ownership interest in ONE Gas. Excluding cash of ONE Gas at separation, the separation was accounted for as a noncash activity.

Wind Down of Energy Services Business - On March 31, 2014, we completed the wind down of our former energy services business. We executed agreements in 2013 and the first quarter 2014 to release a significant portion of our nonaffiliated natural gas transportation and storage contracts to third parties that resulted in noncash charges, which are included in income (loss) from discontinued operations, net of tax, in our Consolidated Statements of Income.

The following table summarizes the change in our liability related to released capacity contracts for the periods indicated:

	Nine Months Ended
	September 30,
	2015			2014
	(Millions of dollars)
Beginning balance	$	73.8		$	122.0
Noncash charges	—			1.7
Settlements	(31.2		)	(38.6		)
Accretion	0.8			1.5
Ending balance	$	43.4		$	86.6

We expect future cash payments associated with released transportation and storage capacity contracts from the wind down of our former energy services business to total approximately $26 million on an after-tax basis, which consists of approximately $4 million to be paid in the remainder of 2015, $11 million in 2016, $6 million in 2017 and $5 million over the period 2018 through 2023.

Results of Operations of Discontinued Operations - The results of operations for our former natural gas distribution business and energy services business have been reported as discontinued operations for all periods presented. Income (loss) from discontinued operations, net of tax, in the Consolidated Statements of Income for the three and nine months ended September 30, 2015, consists of accretion expense, net of tax benefit, on the released contracts for our former energy services business and certain tax-related adjustments. The table below provides selected financial information reported in discontinued operations in the Consolidated Statements of Income for the three and nine months ended September 30, 2014:

	Three Months Ended									Nine Months Ended
	September 30, 2014									September 30, 2014
	Natural Gas Distribution		Energy Services				Total			Natural Gas Distribution				Energy Services			Total
	(Thousands of dollars)
Revenues	$	—	$	—			$	—		$	287,249			$	353,404		$	640,653
Cost of sales and fuel	—		—				—			190,893				364,648			555,541
Net margin	—		—				—			96,356				(11,244		)	85,112
Operating costs	—		142			(b)	142			60,847			(a)	4,664			65,511
Depreciation and amortization	—		—				—			11,035				319			11,354
Operating income (loss)	—		(142		)		(142		)	24,474				(16,227		)	8,247
Other income (expense), net	—		—				—			(888		)		(7		)	(895		)
Interest expense, net	—		—				—			(4,592		)		(413		)	(5,005		)
Income taxes	—		(29		)		(29		)	(16,415		)		7,662			(8,753		)
Income (loss) from discontinued operations, net	$	—	$	(171	)		$	(171	)	$	2,579			$	(8,985	)	$	(6,406	)

(a) - Includes approximately $23.0 million for the nine months ended September 30, 2014, of costs related to ONE Gas separation.

(b) - Represents primarily accretion expense.

Prior to the ONE Gas separation, natural gas sales and transportation and storage services provided to our former natural gas distribution business by ONEOK Partners were $7.5 million for the nine months ended September 30, 2014. Prior to February 1, 2014, these revenues and related costs were eliminated in consolidation. Beginning February 1, 2014, these revenues represent third-party transactions with ONE Gas and are not eliminated in consolidation for all periods presented, as such sales and services have continued subsequent to the separation and are expected to continue in future periods.

Prior to the completion of the energy services wind down, natural gas sales and transportation and storage services provided to our energy services business by ONEOK Partners were $46.0 million for the nine months ended September 30, 2014. While these transactions were eliminated in consolidation in previous periods, they are reflected now as affiliate transactions and are not eliminated in consolidation for all periods presented as these transactions have continued with third parties.

Statement of Financial Position of Discontinued Operations - At September 30, 2015, and December 31, 2014, assets and liabilities of discontinued operations in our Consolidated Balance Sheets relate primarily to deferred tax assets and capacity release obligations associated with our former energy services business.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

9 Months Ended

Sep. 30, 2015

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

A. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Our accompanying unaudited consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC. These statements have been prepared in accordance with GAAP and reflect all adjustments that, in our opinion, are necessary for a fair presentation of the results for the interim periods presented. All such adjustments are of a normal recurring nature. The 2014 year-end consolidated balance sheet data was derived from our audited financial statements but does not include all disclosures required by GAAP. These unaudited consolidated financial statements should be read in conjunction with our audited consolidated financial statements in our Annual Report.

Our significant accounting policies are consistent with those disclosed in Note A of the Notes to Consolidated Financial Statements in our Annual Report.

Organization and Nature of Operations - We are the sole general partner and own limited partner units of ONEOK Partners (NYSE: OKS), which together represent an aggregate 41.2 percent interest in ONEOK Partners at September 30, 2015. The results of operations for our former natural gas distribution and energy services businesses have been classified as discontinued operations for all periods presented. See Note B for additional information.

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

Goodwill Impairment Test - We assess our goodwill for impairment at least annually on July 1, unless events or changes in circumstances indicate an impairment may have occurred before that time.  At July 1, 2015, we assessed qualitative factors to determine whether it was more likely than not that the fair value of each of our reporting units was less than its carrying amount. Due to the current commodity price environment, we elected to perform a quantitative assessment, or Step 1 analysis, to test our goodwill for impairment. The assessment included our current commodity price assumptions, expected contractual terms, anticipated operating costs and volume estimates.  Our goodwill impairment analysis performed as of July 1, 2015, did not result in an impairment charge nor did our analysis reflect any reporting units at risk.  In each reporting unit, the fair value substantially exceeded its carrying value. Subsequent to that date, no event has occurred indicating that the implied fair value of each of the reporting units is less than the carrying value of its net assets. 

Recently Issued Accounting Standards Update - In March 2015, the FASB issued ASU 2015-03, “Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs,” which requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. In August 2015, the FASB issued ASU 2015-15, “Interest - Imputation of Interest (Subtopic 835-30): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements - Amendments to SEC Paragraphs Pursuant to Staff Announcement at June 18, 2015 EITF Meeting,” which amended the SEC paragraphs of ASC Subtopic 835-30 to include the language from the SEC Staff Announcement indicating that the SEC would not object to presenting deferred debt issuance costs related to line-of-credit agreements as assets and subsequently amortizing the deferred debt issuance costs ratably over the term of the agreement. This guidance is effective for public companies for fiscal years beginning after December 15, 2015, with early adoption permitted. We elected to adopt this guidance beginning in the second quarter 2015. Retrospective adjustment of prior periods presented was required. Therefore, the December 31, 2014, balance sheet was recast to reclassify $42.8 million of debt issuance costs from other assets to long-term debt. The impact of adopting this guidance was not material.

In April 2014, the FASB issued ASU 2014-08, “Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity,” which alters the definition of a discontinued operation to include only asset disposals that represent a strategic shift with a major effect on an entity’s operations and financial results. The amendment also requires more extensive disclosures about a discontinued operation’s assets, liabilities, income, expenses and cash flows. This guidance will be effective for interim and annual periods for all assets that are disposed of or classified as being held for sale in fiscal years that begin on or after December 15, 2014. We adopted this guidance beginning in the first quarter 2015, and it could impact us in the future if we dispose of any individually significant components.

In September 2015, the FASB issued ASU 2015-16, “Business Combinations (Topic 805) - Simplifying the Accounting for Measurement-Period Adjustments,” which requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. The amendment also requires the acquirer to record the income statement effects of changes to provisional amounts in the financial statements in the period in which the adjustments occurred. This guidance is effective for public companies for fiscal years beginning after December 15, 2015, with early adoption permitted. We expect to adopt this guidance in the first quarter 2016, and it could impact us in the future if we complete any acquisitions with subsequent measurement period adjustments.

In April 2015, the FASB issued ASU 2015-05, “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Fees Paid in a Cloud Computing Arrangement,” which clarifies whether a cloud computing arrangement includes a software license. If it does, the customer should account for the software license element of the arrangement consistent with the acquisition of other software licenses; if not, the customer should not account for the arrangement as a service contract. This guidance is effective for public companies for fiscal years beginning after December 15, 2015. Early adoption is permitted. We expect to adopt this guidance in the first quarter 2016, and we do not expect it to materially impact us.

In February 2015, the FASB issued ASU 2015-02, “Consolidation (Topic 810): Amendments to the Consolidation Analysis,” which eliminates the presumption that a general partner should consolidate a limited partnership. It also modifies the evaluation of whether limited partnerships are variable interest entities or voting interest entities and adds requirements that limited partnerships must meet to qualify as voting interest entities. This guidance is effective for public companies for fiscal years beginning after December 15, 2015. We expect to adopt this guidance in the first quarter 2016, and we are evaluating the impact on us.

In August 2014, the FASB issued ASU 2014-15, “Going Concern,” which provides guidance on determining when and how to disclose going-concern uncertainties in the financial statements. The new standard requires management to perform interim and annual assessments of an entity’s ability to continue as a going concern within one year of the date the financial statements are issued. An entity must provide certain disclosures if conditions or events raise substantial doubt about the entity’s ability to continue as a going concern. The standard applies to all entities and is effective for annual periods ending after December 15, 2016, and interim periods thereafter, with early adoption permitted. We expect to adopt this guidance beginning in the fourth quarter 2016, and we do not expect it to materially impact us.

In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers,” which outlines the principles an entity must apply to measure and recognize revenue for entities that enter into contracts to provide goods or services to their customers. The core principle is that an entity should recognize revenue at an amount that reflects the consideration to which the entity expects to be entitled in exchange for transferring goods or services to a customer. The amendment also requires more extensive disaggregated revenue disclosures in interim and annual financial statements. In August 2015, the FASB issued ASU 2015-14, “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date,” that deferred the effective date of ASU 2014-09 by one year. This update is now effective for interim and annual periods that begin after December 15, 2017, with either retrospective application for all periods presented or retrospective application with a cumulative effect adjustment. We expect to adopt this guidance beginning in the first quarter 2018, and we are evaluating the impact on us.

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ONEOK PARTNERS

9 Months Ended

Sep. 30, 2015

Related Party Transactions [Abstract]

ONEOK PARTNERS

M. ONEOK PARTNERS

Ownership Interestin ONEOK Partners - Our ownership interest in ONEOK Partners is shown in the table below at September 30, 2015:

General partner interest	2.0	%
Limited partner interest (a)	39.2	%
Total ownership interest	41.2	%

(a) - Represents 41.3 million common units and approximately 73.0 million Class B units, which are convertible, at our option, into common units.

Equity Issuances - In August 2015, ONEOK Partners completed the sale to us in a private placement of approximately 21.5 million common units at a price of $30.17 per unit. Additionally, ONEOK Partners completed a concurrent sale of approximately 3.3 million common units at a price of $30.17 per unit to funds managed by Kayne Anderson Capital Advisors in a registered direct offering, which were issued through ONEOK Partners’ existing “at-the-market” equity program. The combined offerings generated net cash proceeds of approximately $749 million to ONEOK Partners. In conjunction with these issuances, ONEOK Partners GP contributed approximately $15.3 million in order to maintain our 2 percent general partner interest in ONEOK Partners. ONEOK Partners used the proceeds for general partnership purposes, including capital expenditures and repayment of commercial paper borrowings. No other units were sold through the “at-the-market” program during the three months ended September 30, 2015.

ONEOK Partners has an “at-the-market” equity program for the offer and sale from time to time of its common units, up to an aggregate amount of $650 million. The program allows ONEOK Partners to offer and sell its common units at prices it deems appropriate through a sales agent. Sales of common units are made by means of ordinary brokers’ transactions on the NYSE, in block transactions or as otherwise agreed to between ONEOK Partners and the sales agent. ONEOK Partners is under no obligation to offer and sell common units under the program. At September 30, 2015, ONEOK Partners had approximately $138 million of registered common units available for issuance through its “at-the-market” equity program.

During the nine months ended September 30, 2015, ONEOK Partners sold approximately 10.5 million common units through its “at-the-market” equity program, including the units sold to funds managed by Kayne Anderson Capital Advisors in the registered direct offering discussed above. The net proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, were approximately $381.6 million, which were used for general partnership purposes, including repayment of commercial paper borrowings.

In May 2014, ONEOK Partners completed an underwritten public offering of approximately 13.9 million common units at a public offering price of $52.94 per common unit, generating net proceeds of approximately $714.5 million. In conjunction with this issuance, ONEOK Partners GP contributed approximately $15.0 million in order to maintain our 2 percent general partner interest in ONEOK Partners. ONEOK Partners used the proceeds for general partnership purposes, including capital expenditures and repayment of commercial paper borrowings.

During the three months ended September 30, 2014, ONEOK Partners sold approximately 1.4 million common units through its “at-the-market” equity program. The net proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, were approximately $81.3 million, which were used for general partnership purposes.

During the nine months ended September 30, 2014, ONEOK Partners sold 4.4 million common units through the “at-the-market” program that resulted in net proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, of approximately $245.4 million and used the proceeds for general partnership purposes.

We account for the difference between the carrying amount of our investment in ONEOK Partners and the underlying book value arising from issuance of common units by ONEOK Partners as an equity transaction. If ONEOK Partners issues common units at a price different than our carrying value per unit, we account for the premium or deficiency as an adjustment to paid-in capital. As a result of ONEOK Partners’ issuance of common units, we recognized a decrease to paid-in capital of approximately $34.4 million, net of taxes, for the nine months ended September 30, 2015.

Cash Distributions - We receive distributions from ONEOK Partners on the common and Class B units we own and the 2 percent general partner interest, which includes our incentive distribution rights. Under the Partnership Agreement, distributions are made to the partners with respect to each calendar quarter in an amount equal to 100 percent of available cash as defined in the Partnership Agreement. Available cash generally will be distributed 98 percent to limited partners and 2 percent to the general partner. The general partner’s percentage interest in quarterly distributions is increased after certain specified target levels are met during the quarter. Under the incentive distribution provisions, as set forth in the Partnership Agreement the general partner receives:

• 15 percent of amounts distributed in excess of $0.3025 per unit;

• 25 percent of amounts distributed in excess of $0.3575 per unit; and

• 50 percent of amounts distributed in excess of $0.4675 per unit.

In October 2015, a cash distribution of $0.79 per unit ($3.16 per unit on an annualized basis) was declared for the third quarter 2015 and will be paid on November 13, 2015, to unitholders of record at the close of business on November 2, 2015.

The following table shows ONEOK Partners’ distributions paid in the periods indicated:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2015		2014		2015		2014
	(Thousands, except per unit amounts)
Distribution per unit	$	0.79	$	0.76	$	2.37	$	2.235
General partner distributions	$	6,081	$	5,501	$	17,950	$	15,361
Incentive distributions	91,794		80,381		270,962		220,547
Distributions to general partner	97,875		85,882		288,912		235,908
Limited partner distributions to ONEOK	73,302		70,519		219,907		207,381
Limited partner distributions to noncontrolling interest	132,862		118,644		388,655		324,805
Total distributions paid	$	304,039	$	275,045	$	897,474	$	768,094

The following table shows ONEOK Partners’ distributions declared for the periods indicated and paid within 45 days of the end of the period:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2015		2014		2015		2014
	(Thousands, except per unit amounts)
Distribution per unit	$	0.79	$	0.775	$	2.37	$	2.280
General partner distributions	$	6,660	$	5,683	$	18,696	$	16,195
Incentive distributions	100,538		84,452		282,221		236,744
Distributions to general partner	107,198		90,135		300,917		252,939
Limited partner distributions to ONEOK	90,323		71,911		236,927		211,557
Limited partner distributions to noncontrolling interest	135,480		122,105		396,925		345,255
Total distributions declared	$	333,001	$	284,151	$	934,769	$	809,751

Relationship - We consolidate ONEOK Partners in our consolidated financial statements; however, we are restricted from the assets and cash flows of ONEOK Partners except for the distributions we receive. Distributions are declared quarterly by ONEOK Partners GP based on the terms of the Partnership Agreement. See Note O for more information on ONEOK Partners’ results.

Affiliate Transactions - We provide a variety of services to our affiliates, including cash management and financial services, employee benefits, legal and administrative services by our employees and management, insurance and office space leased in our headquarters building and other field locations. Where costs are incurred specifically on behalf of an affiliate, the costs are billed directly to the affiliate by us. In other situations, the costs may be allocated to the affiliates through a variety of methods, depending upon the nature of the expenses and the activities of the affiliates. Beginning in the second quarter 2014, we allocate substantially all of our general overhead costs to ONEOK Partners as a result of the separation of our natural gas distribution business and the wind down of our energy services business in the first quarter 2014. For the first quarter 2014, it is not practicable to determine what these general overhead costs would have been on a stand-alone basis.

The following table shows ONEOK Partners’ transactions with us for the periods indicated:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2015		2014		2015		2014
	(Thousands of dollars)
Revenues	$	—	$	—	$	—	$	53,526
Expenses
Cost of sales and fuel	$	—	$	—	$	—	$	10,835
Operating expenses	89,342		84,221		265,611		240,172
Total expenses	$	89,342	$	84,221	$	265,611	$	251,007

Prior to the ONE Gas separation, ONEOK Partners provided natural gas sales and transportation and storage services to our former natural gas distribution business. Prior to February 1, 2014, these revenues and related costs were eliminated in consolidation. Beginning February 1, 2014, these revenues represent third-party transactions with ONE Gas and are not eliminated in consolidation, as such sales and services have continued subsequent to the separation and are expected to continue in future periods. Prior to the completion of the energy services wind down, ONEOK Partners provided natural gas and natural gas liquids sales and transportation and storage services to our energy services business. While these transactions were eliminated in consolidation in previous periods, they are now reflected as affiliate transactions and not eliminated in consolidation as these transactions have continued with third parties. See Note B for additional detail on these revenues.

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

9 Months Ended

Sep. 30, 2015

Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]

ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

I. ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

The following table sets forth the balance in accumulated other comprehensive income (loss) for the period indicated:

	Unrealized Gains (Losses) on Risk- Management Assets/Liabilities (a)			Unrealized Holding Gains (Losses) on Investment Securities (a)			Pension and Postretirement Benefit Plan Obligations (a) (b)			Accumulated Other Comprehensive Income (Loss) (a)
	(Thousands of dollars)
January 1, 2015	$	(37,349	)	$	955		$	(99,959	)	$	(136,353	)
Other comprehensive income (loss) before reclassifications	3,661			(955		)	65			2,771
Amounts reclassified from accumulated other comprehensive income (loss)	(9,785		)	—			7,255			(2,530		)
Net current period other comprehensive income (loss) attributable to ONEOK	(6,124		)	(955		)	7,320			241
September 30, 2015	$	(43,473	)	$	—		$	(92,639	)	$	(136,112	)

(a) All amounts are presented net of tax.

(b) Includes amounts related to supplemental executive retirement plan.

The following table sets forth the effect of reclassifications from accumulated other comprehensive income (loss) in our Consolidated Statements of Income for the periods indicated:

Details about Accumulated Other Comprehensive Income (Loss) Components	Three Months Ended						Nine Months Ended						Affected Line Item in the Consolidated Statements of Income
	September 30,						September 30,
	2015			2014			2015			2014
	(Thousands of dollars)
Unrealized (gains) losses on risk-management assets/liabilities
Commodity contracts	$	(22,770	)	$	355		$	(54,020	)	$	31,961		Commodity sales revenues
Interest-rate contracts	4,554			3,525			12,869			18,372			Interest expense
	(18,216		)	3,880			(41,151		)	50,333			Income before income taxes
	2,957			(748		)	5,621			(9,845		)	Income tax expense
	(15,259		)	3,132			(35,530		)	40,488			Income from continuing operations
	—			—			—			7,682			Income (loss) from discontinued operations
	(15,259		)	3,132			(35,530		)	48,170			Net income
Noncontrolling interests	(10,150		)	1,928			(25,745		)	24,574			Less: Net income attributable to noncontrolling interests
	$	(5,109	)	$	1,204		$	(9,785	)	$	23,596		Net income attributable to ONEOK
Pension and postretirement benefit plan obligations (a)
Amortization of net loss	$	4,422		$	4,009		$	13,268		$	11,936
Amortization of unrecognized prior service cost	(392		)	(368		)	(1,176		)	(1,102		)
	4,030			3,641			12,092			10,834			Income before income taxes
	(1,612		)	(1,456		)	(4,837		)	(4,334		)	Income tax expense
	2,418			2,185			7,255			6,500			Income from continuing operations
	—			—			—			1,648			Income from discontinued operations
	$	2,418		$	2,185		$	7,255		$	8,148		Net income attributable to ONEOK
Total reclassifications for the period attributable to ONEOK	$	(2,691	)	$	3,389		$	(2,530	)	$	31,744		Net income attributable to ONEOK

(a) These components of accumulated other comprehensive income (loss) are included in the computation of net periodic benefit cost. See Note K for additional detail of our net periodic benefit cost.

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

9 Months Ended

Sep. 30, 2015

Derivatives, Fair Value [Line Items]

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

E. RISK-MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

Risk-Management Activities - ONEOK Partners is sensitive to changes in natural gas, crude oil and NGL prices, principally as a result of contractual terms under which these commodities are processed, purchased and sold. ONEOK Partners uses physical-forward purchases and sales and financial derivatives to secure a certain price for a portion of its natural gas, condensate and NGL products; to reduce its exposure to interest-rate fluctuations; and to achieve more predictable cash flows. ONEOK Partners follows established policies and procedures to assess risk and approve, monitor and report its risk-management activities. ONEOK Partners has not used these instruments for trading purposes. We and ONEOK Partners are also subject to the risk of interest-rate fluctuation in the normal course of business.

Commodity price risk - Commodity price risk refers to the risk of loss in cash flows and future earnings arising from adverse changes in the price of natural gas, NGLs and condensate. ONEOK Partners uses the following commodity derivative instruments to mitigate the near-term commodity price risk associated with a portion of the forecasted sales of these commodities:

• Futures contracts - Standardized contracts to purchase or sell natural gas and crude oil for future delivery or settlement under the provisions of exchange regulations;

• Forward contracts - Nonstandardized commitments between two parties to purchase or sell natural gas, crude oil or NGLs for future physical delivery. These contracts are typically nontransferable and can only be canceled with the consent of both parties; and

• Swaps - Exchange of one or more payments based on the value of one or more commodities. These instruments transfer the financial risk associated with a future change in value between the counterparties of the transaction, without also conveying ownership interest in the asset or liability.

ONEOK Partners may also use other instruments including options or collars to mitigate commodity price risk. Options are contractual agreements that give the holder the right, but not the obligation, to buy or sell a fixed quantity of a commodity at a fixed price within a specified period of time. Options may either be standardized and exchange traded or customized and nonexchange traded. A collar is a combination of a purchased put option and a sold call option, which places a floor and a ceiling price for commodity sales being hedged.

The Natural Gas Gathering and Processing segment is exposed to commodity price risk as a result of receiving commodities in exchange for services associated with its POP contracts. ONEOK Partners also is exposed to basis risk between the various production and market locations where it receives and sells commodities. As part of ONEOK Partners’ hedging strategy, it uses the previously described commodity derivative financial instruments and physical-forward contracts to reduce the impact of price fluctuations related to natural gas, NGLs and condensate.

The Natural Gas Liquids segment is exposed to location price differential risk, primarily as a result of the relative value of NGL purchases at one location and sales at another location. ONEOK Partners is also exposed to commodity price risk resulting from the relative values of the various NGL products to each other, NGLs in storage and the relative value of NGLs to natural gas. ONEOK Partners utilizes physical-forward contracts and commodity derivative financial instruments to reduce the impact of price fluctuations related to NGLs.

The Natural Gas Pipelines segment is exposed to commodity price risk because its intrastate and interstate natural gas pipelines retain natural gas from its customers for operations or as part of its fee for services provided. When the amount of natural gas consumed in operations by these pipelines differs from the amount provided by its customers, ONEOK Partners’ pipelines must buy or sell natural gas, or store or use natural gas from inventory, which can expose it to commodity price risk depending on the regulatory treatment for this activity. To the extent that commodity price risk in the Natural Gas Pipelines segment is not mitigated by fuel cost-recovery mechanisms, ONEOK Partners uses physical-forward sales or purchases to reduce the impact of price fluctuations related to natural gas. At September 30, 2015, and December 31, 2014, there were no financial derivative instruments with respect to ONEOK Partners’ natural gas pipeline operations.

Interest-rate risk - We and ONEOK Partners manage interest-rate risk through the use of fixed-rate debt, floating-rate debt and interest-rate swaps. Interest-rate swaps are agreements to exchange interest payments at some future point based on specified notional amounts. At December 31, 2014, ONEOK Partners had forward-starting interest-rate swaps with notional amounts totaling $900 million that were designated as cash flow hedges of the variability of interest payments on a portion of forecasted debt issuances that may result from changes in the benchmark interest rate before the debt is issued. Upon ONEOK Partners’ debt issuance in March 2015, it settled $500 million of its interest-rate swaps and realized a loss of $55.1 million, which is included in accumulated other comprehensive loss and will be amortized to interest expense over the term of the related debt. At September 30, 2015, ONEOK Partners’ remaining interest-rate swaps with notional amounts totaling $400 million have settlement dates of less than 12 months.

Accounting Treatment -We and ONEOK Partners record all derivative instruments at fair value, with the exception of normal purchases and normal sales transactions that are expected to result in physical delivery. Commodity price and interest-rate volatility may have a significant impact on the fair value of derivative instruments as of a given date. The accounting for changes in the fair value of a derivative instrument depends on whether it has been designated and qualifies as part of a hedging relationship and, if so, the reason for holding it.

The table below summarizes the various ways in which we account for our derivative instruments and the impact on our consolidated financial statements:

		Recognition and Measurement
Accounting Treatment		Balance Sheet		Income Statement
Normal purchases and normal sales	-	Fair value not recorded	-	Change in fair value not recognized in earnings
Mark-to-market	-	Recorded at fair value	-	Change in fair value recognized in earnings
Cash flow hedge	-	Recorded at fair value	-	Ineffective portion of the gain or loss on the derivative instrument is recognized in earnings
	-	Effective portion of the gain or loss on the derivative instrument is reported initially as a component of accumulated other comprehensive income (loss)	-	Effective portion of the gain or loss on the derivative instrument is reclassified out of accumulated other comprehensive income (loss) into earnings when the forecasted transaction affects earnings
Fair value hedge	-	Recorded at fair value	-	The gain or loss on the derivative instrument is recognized in earnings
	-	Change in fair value of the hedged item is recorded as an adjustment to book value	-	Change in fair value of the hedged item is recognized in earnings

To reduce its exposure to fluctuations in natural gas, NGLs and condensate prices, ONEOK Partners periodically enters into futures, forward purchases and sales, options or swap transactions in order to hedge anticipated purchases and sales of natural gas, NGLs and condensate. Interest-rate swaps are used from time to time to manage interest-rate risk. Under certain conditions, we designate these derivative instruments as a hedge of exposure to changes in fair values or cash flows. We formally document all relationships between hedging instruments and hedged items, as well as risk-management objectives and strategies for undertaking various hedge transactions, and methods for assessing and testing correlation and hedge ineffectiveness. We specifically identify the forecasted transaction that has been designated as the hedged item in a cash flow hedge relationship. We assess the effectiveness of hedging relationships quarterly by performing an effectiveness analysis on our fair value and cash flow hedging relationships to determine whether the hedge relationships are highly effective on a retrospective and prospective basis. ONEOK Partners also documents its normal purchases and normal sales transactions that are expected to result in physical delivery and that ONEOK Partners elects to exempt from derivative accounting treatment.

The realized revenues and purchase costs of our and ONEOK Partners’ derivative instruments not considered held for trading purposes and derivatives that qualify as normal purchases or normal sales that are expected to result in physical delivery are reported on a gross basis. Cash flows from futures, forwards and swaps that are accounted for as hedges are included in the same category as the cash flows from the related hedged items in our Consolidated Statements of Cash Flows.

Fair Values of Derivative Instruments - See Note D for a discussion of the inputs associated with our fair value measurements. The following table sets forth the fair values of derivative instruments for our continuing operations for the periods indicated:

	September 30, 2015					December 31, 2014
	Assets (a)		(Liabilities) (a)			Assets (a)		(Liabilities) (a)
	(Thousands of dollars)
Derivatives designated as hedging instruments
Commodity contracts
Financial contracts	$	45,534	$	(5,108	)	$	43,234	$	(1,137	)
Physical contracts	4,866		—			9,922		—
Interest-rate contracts	—		(13,648		)	2,288		(44,843		)
Total derivatives designated as hedging instruments	50,400		(18,756		)	55,444		(45,980		)
Derivatives not designated as hedging instruments
Commodity contracts
Financial contracts	1,021		(791		)	—		—
Physical contracts	—		—			—		(23		)
Total derivatives not designated as hedging instruments	1,021		(791		)	—		(23		)
Total derivatives	$	51,421	$	(19,547	)	$	55,444	$	(46,003	)

(a) - Included on a net basis in other current assets, other assets or other current liabilities in our Consolidated Balance Sheets.

Notional Quantities for Derivative Instruments - The following table sets forth the notional quantities for derivative instruments for our continuing operations for the periods indicated:

		September 30, 2015					December 31, 2014
	Contract Type	Purchased/ Payor		Sold/ Receiver			Purchased/ Payor		Sold/ Receiver
Derivatives designated as hedging instruments:
Cash flow hedges
Fixed price
- Natural gas (Bcf)	Futures and swaps	—		(38.7		)	—		(41.2		)
- Crude oil and NGLs (MMBbl)	Futures, forwards and swaps	—		(3.5		)	—		(0.5		)
Basis
- Natural gas (Bcf)	Futures and swaps	—		(38.7		)	—		(41.2		)
Interest-rate contracts (Millions of dollars)	Forward-starting swaps	$	400.0	$	—		$	900.0	$	—
Derivatives not designated as hedging instruments:
Fixed price
- Crude oil and NGLs (MMBbl)	Futures, forwards and swaps	0.5		(0.5		)	—		—

These notional amounts are used to summarize the volume of financial instruments; however, they do not reflect the extent to which the positions offset one another and, consequently, do not reflect ONEOK Partners’ actual exposure to market or credit risk.

Cash Flow Hedges - ONEOK Partners uses derivative instruments to hedge the cash flows associated with anticipated purchases and sales of natural gas, NGLs and condensate and cost of fuel used in the transportation of natural gas. Accumulated other comprehensive loss at September 30, 2015, includes unrealized gains of approximately $12.0 million, net of tax, related to these hedges that will be realized within the next 15 months as the forecasted transactions affect earnings. If commodity prices remain at current levels, we will recognize $10.7 million in net gains over the next 12 months and net gains of $1.3 million thereafter. The amount deferred in accumulated other comprehensive loss attributable to our and ONEOK Partners’ settled interest-rate swaps is a loss of $50.6 million, net of tax, which will be recognized over the life of the long-term, fixed-rate debt, including losses of $6.2 million, net of tax, that will be reclassified into earnings during the next 12 months as the hedged items affect earnings. The remaining amounts in accumulated other comprehensive loss are attributable primarily to ONEOK Partners’ forward-starting interest-rate swaps with future settlement dates, which will be amortized to interest expense over the life of long-term, fixed-rate debt upon issuance of ONEOK Partners’ debt.

The following table sets forth the unrealized effect of cash flow hedges recognized in other comprehensive income (loss) for the periods indicated:

Derivatives in Cash Flow Hedging Relationships	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2015			2014			2015			2014
	(Thousands of dollars)
Continuing Operations
Commodity contracts	$	36,559		$	17,133		$	47,650		$	(24,743	)
Interest-rate contracts	(20,610		)	(9,755		)	(26,277		)	(56,849		)
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion) for continuing operations	$	15,949		$	7,378		$	21,373		$	(81,592	)

The following table sets forth the effect of cash flow hedges in our Consolidated Statements of Income for the periods indicated:

Derivatives in Cash Flow Hedging Relationships	Location of Gain (Loss) Reclassified from  Accumulated Other Comprehensive Income (Loss) into Net Income (Effective Portion)	Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2015			2014			2015			2014
		(Thousands of dollars)
Continuing Operations
Commodity contracts	Commodity sales revenues	$	22,770		$	(355	)	$	54,020		$	(31,961	)
Interest-rate contracts	Interest expense	(4,554		)	(3,525		)	(12,869		)	(18,372		)
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income on derivatives (effective portion) for continuing operations		$	18,216		$	(3,880	)	$	41,151		$	(50,333	)

For the nine months ended September 30, 2014, an unrealized loss of $3.7 million was recognized in other comprehensive income (loss) and a realized loss of $12.8 million was reclassified from accumulated other comprehensive income (loss) related to cash flow hedges for our former energy services business.

Ineffectiveness related to cash flow hedges was not material for the three and nine months ended September 30, 2015 and 2014. In the event that it becomes probable that a forecasted transaction will not occur, we would discontinue cash flow hedge treatment, which would affect earnings. For the three and nine months ended September 30, 2015, and the three months ended September 30, 2014, there were no gains or losses due to the discontinuance of cash flow hedge treatment. For the nine months ended September 30, 2014, we reclassified losses of $4.6 million, net of taxes of $3.1 million, to interest expense from accumulated other comprehensive loss due to the discontinuance of cash flow hedge treatment related to the early retirement of long-term debt. See Note G for additional information.

Credit Risk - We and ONEOK Partners monitor the creditworthiness of counterparties and compliance with policies and limits established by our Risk Oversight and Strategy Committee. We and ONEOK Partners maintain credit policies with regard to counterparties that we believe minimize overall credit risk. These policies include an evaluation of potential counterparties’ financial condition (including credit ratings, bond yields and credit default swap rates), collateral requirements under certain circumstances and the use of standardized master-netting agreements that allow us to net the positive and negative exposures associated with a single counterparty. ONEOK Partners has counterparties whose credit is not rated, and for those customers, it uses internally developed credit ratings.

Some of ONEOK Partners’ financial derivative instruments contain provisions that require it to maintain an investment-grade credit rating from S&P and/or Moody’s. If ONEOK Partners’ credit ratings on its senior unsecured long-term debt were to decline below investment grade, the counterparties to the derivative instruments could request collateralization on derivative instruments in net liability positions. There were no financial derivative instruments with contingent features related to credit risk that were in a net liability position at September 30, 2015.

The counterparties to ONEOK Partners’ derivative contracts consist primarily of major energy companies, financial institutions and commercial and industrial end users. This concentration of counterparties may affect ONEOK Partners’ overall exposure to credit risk, either positively or negatively, in that the counterparties may be affected similarly by changes in economic, regulatory or other conditions. Based on ONEOK Partners’ policies, exposures, credit and other reserves, we do not anticipate a material adverse effect on our financial position or results of operations as a result of counterparty nonperformance.

At September 30, 2015, the net credit exposure from ONEOK Partners’ derivative assets is primarily with investment-grade companies in the financial services sector.

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ACQUISITIONS ACQUISITIONS(Notes)

9 Months Ended

Sep. 30, 2015

Acquisitions [Abstract]

Mergers, Acquisitions and Dispositions Disclosures [Text Block]

C. ACQUISITIONS

West Texas LPG Acquisition - In November 2014, ONEOK Partners completed the acquisition of an 80 percent interest in the West Texas LPG Pipeline Limited Partnership and a 100 percent interest in the Mesquite Pipeline for approximately $800 million from affiliates of Chevron Corporation. We accounted for this acquisition as a business combination which, among other things, requires assets acquired and liabilities assumed to be measured at their acquisition-date fair values. See Note C in the Notes to Consolidated Financial Statements in our Annual Report for additional information on this acquisition.

Our consolidated balance sheet as of September 30, 2015, reflects the final purchase price allocation. Adjustments to the preliminary purchase price allocation reported in Note C in the Notes to the Consolidated Financial Statements in our Annual Report were not material. Therefore, prior period financial statements have not been recast.

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FAIR VALUE MEASUREMENTS

9 Months Ended

Sep. 30, 2015

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

D. FAIR VALUE MEASUREMENTS

Determining Fair Value -We define fair value as the price that would be received from the sale of an asset or the transfer of a liability in an orderly transaction between market participants at the measurement date. We use market and income approaches to determine the fair value of our assets and liabilities and consider the markets in which the transactions are executed. We measure the fair value of a group of financial assets and liabilities consistent with how a market participant would price the net risk exposure at the measurement date.

While many of the contracts in ONEOK Partners’ portfolio are executed in liquid markets where price transparency exists, some contracts are executed in markets for which market prices may exist, but the market may be relatively inactive. This results in limited price transparency that requires management’s judgment and assumptions to estimate fair values.  For certain transactions, we utilize modeling techniques using NYMEX-settled pricing data and implied forward LIBOR curves. Inputs into our fair value estimates include commodity-exchange prices, over-the-counter quotes, historical correlations of pricing data, data obtained from third-party pricing services and LIBOR and other liquid money-market instrument rates. We validate our valuation inputs with third-party information and settlement prices from other sources, where available.

In addition, as prescribed by the income approach, we compute the fair value of our and ONEOK Partners’ derivative portfolio by discounting the projected future cash flows from our and ONEOK Partners’ derivative assets and liabilities to present value using interest-rate yields to calculate present-value discount factors derived from LIBOR, Eurodollar futures and interest-rate swaps. We also take into consideration the potential impact on market prices of liquidating positions in an orderly manner over a reasonable period of time under current market conditions. We consider current market data in evaluating counterparties’, as well as our own, nonperformance risk, net of collateral, by using specific and sector bond yields and monitoring the credit default swap markets. Although we use our best estimates to determine the fair value of the derivative contracts we and ONEOK Partners have executed, the ultimate market prices realized could differ from our estimates, and the differences could be material.

The fair value of our forward-starting interest-rate swaps are determined using financial models that incorporate the implied forward LIBOR yield curve for the same period as the future interest swap settlements.

Fair Value Hierarchy - At each balance sheet date, we utilize a fair value hierarchy to classify fair value amounts recognized or disclosed in our financial statements based on the observability of inputs used to estimate such fair value. The levels of the hierarchy are described below:

• Level 1 - fair value measurements are based on unadjusted quoted prices for identical securities in active markets, including NYMEX-settled prices. These balances are comprised predominantly of exchange-traded derivative contracts for natural gas and crude oil.

• Level 2 - fair value measurements are based on significant observable pricing inputs, such as NYMEX-settled prices for natural gas and crude oil, and financial models that utilize implied forward LIBOR yield curves for interest-rate swaps.

• Level 3 - fair value measurements are based on inputs that may include one or more unobservable inputs, including natural gas basis and NGL price curves that incorporate observable and unobservable market data from broker quotes, third-party pricing services, market volatilities derived from the most recent NYMEX close spot prices and forward LIBOR curves, and adjustments for the credit risk of our counterparties. We corroborate the data on which our fair value estimates are based using our market knowledge of recent transactions, analysis of historical correlations and validation with independent broker quotes. These balances categorized as Level 3 are comprised of derivatives for natural gas and NGLs. We do not believe that our Level 3 fair value estimates have a material impact on our results of operations, as the majority of our derivatives are accounted for as hedges for which ineffectiveness has not been material.

Determining the appropriate classification of our fair value measurements within the fair value hierarchy requires management’s judgment regarding the degree to which market data is observable or corroborated by observable market data. We categorize derivatives for which fair value is determined using multiple inputs within a single level, based on the lowest level input that is significant to the fair value measurement in its entirety.

Recurring Fair Value Measurements - The following tables set forth our recurring fair value measurements for our continuing operations for the periods indicated:

	September 30, 2015
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Derivative assets
Commodity contracts
Financial contracts	$	40,799		$	—		$	5,756		$	46,555		$	(29,319	)	$	17,236
Physical contracts	—			—			4,866			4,866			—			4,866
Total derivative assets	$	40,799		$	—		$	10,622		$	51,421		$	(29,319	)	$	22,102
Derivative liabilities
Commodity contracts
Financial contracts	$	(573	)	$	—		$	(5,326	)	$	(5,899	)	$	5,899		$	—
Interest-rate contracts	—			(13,648		)	—			(13,648		)	—			(13,648		)
Total derivative liabilities	$	(573	)	$	(13,648	)	$	(5,326	)	$	(19,547	)	$	5,899		$	(13,648	)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis. We net derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and ONEOK Partners. At September 30, 2015, ONEOK Partners held $23.4 million of cash from various counterparties and no cash collateral posted.

(b) - Included in other current assets, other assets or other current liabilities in our Consolidated Balance Sheets.

	December 31, 2014
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Assets
Derivatives
Commodity contracts
Financial contracts	$	42,880		$	—		$	354		$	43,234		$	(25,979	)	$	17,255
Physical contracts	—			—			9,922			9,922			—			9,922
Interest-rate contracts	—			2,288			—			2,288			—			2,288
Total derivative assets	42,880			2,288			10,276			55,444			(25,979		)	29,465
Available-for-sale investment securities	1,773			—			—			1,773			—			1,773
Total assets	$	44,653		$	2,288		$	10,276		$	57,217		$	(25,979	)	$	31,238
Liabilities
Derivatives
Commodity contracts
Financial contracts	$	(169	)	$	—		$	(968	)	$	(1,137	)	$	1,137		$	—
Physical contracts	—			—			(23		)	(23		)	—			(23		)
Interest-rate contracts	—			(44,843		)	—			(44,843		)	—			(44,843		)
Total derivative liabilities	$	(169	)	$	(44,843	)	$	(991	)	$	(46,003	)	$	1,137		$	(44,866	)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis. We net derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and ONEOK Partners. At December 31, 2014, ONEOK Partners held $24.8 million of cash from various counterparties and no cash collateral posted.

(b) - Included in other current assets, other assets or other current liabilities in our Consolidated Balance Sheets.

The following table sets forth a reconciliation of our Level 3 fair value measurements for our continuing operations for the periods indicated:

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
Derivative Assets (Liabilities)	2015			2014			2015			2014
	(Thousands of dollars)
Net assets (liabilities) at beginning of period	$	10,387		$	(1,313	)	$	9,285		$	(782	)
Total realized/unrealized gains (losses):
Included in earnings (a)	(15		)	207			95			(688		)
Included in other comprehensive income (loss)	(5,076		)	402			(4,084		)	(2,968		)
Purchases, issuances and settlements	—			—			—			3,734
Net assets (liabilities) at end of period	$	5,296		$	(704	)	$	5,296		$	(704	)

(a) - Included in commodity sales revenues in our Consolidated Statements of Income.

Realized/unrealized gains (losses) include the realization of ONEOK Partners’ derivative contracts through maturity. During the three and nine months ended September 30, 2015 and 2014, gains or losses included in earnings attributable to the change in unrealized gains or losses relating to assets and liabilities still held at the end of each reporting period were not material.

We recognize transfers into and out of the levels in the fair value hierarchy as of the end of each reporting period. During the three and nine months ended September 30, 2015 and 2014, there were no transfers between levels.

Other Financial Instruments -The approximate fair value of cash and cash equivalents, accounts receivable, accounts payable and notes payable is equal to book value, due to the short-term nature of these items. Our cash and cash equivalents are comprised of bank and money market accounts and are classified as Level 1. Our notes payable are classified as Level 2 since the estimated fair value of the notes payable can be determined using information available in the commercial paper market.

The estimated fair value of our consolidated long-term debt, including current maturities, was $8.1 billion and $7.5 billion at September 30, 2015, and December 31, 2014, respectively. The book value of our consolidated long-term debt, including current maturities, was $8.4 billion and $7.2 billion at September 30, 2015, and December 31, 2014, respectively. The estimated fair value of the aggregate of ONEOK’s and ONEOK Partners’ senior notes outstanding was determined using quoted market prices for similar issues with similar terms and maturities. The estimated fair value of our consolidated long-term debt is classified as Level 2.

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CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE

9 Months Ended

Sep. 30, 2015

Short-term Debt [Abstract]

CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE

F. CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE

ONEOK Credit Agreement - The ONEOK Credit Agreement, which is scheduled to expire in January 2019, is a $300 million revolving credit facility and contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of indebtedness to Consolidated EBITDA (EBITDA, as defined in our ONEOK Credit Agreement) of no more than 4.0 to 1. Upon breach of certain covenants by us in the ONEOK Credit Agreement, amounts outstanding under the ONEOK Credit Agreement, if any, may become due and payable immediately. At September 30, 2015, ONEOK’s ratio of indebtedness to Consolidated EBITDA was 2.4 to 1, and ONEOK was in compliance with all covenants under the ONEOK Credit Agreement. As a result of a reduction in the borrowing capacity of the ONEOK Credit Agreement due to the ONE Gas separation, we wrote off approximately $2.9 million in interest expense of previously deferred credit agreement issuance costs in the first quarter 2014.

The ONEOK Credit Agreement also includes a $50 million sublimit for the issuance of standby letters of credit and a $50 million sublimit for swingline loans. Under the terms of the ONEOK Credit Agreement, ONEOK may request an increase in the size of the facility to an aggregate of $500 million from $300 million by either commitments from new lenders or increased commitments from existing lenders. The ONEOK Credit Agreement contains provisions for an applicable margin rate and an annual facility fee, both of which adjust with changes in our credit rating. Based on our current credit rating, borrowings, if any, will accrue at LIBOR plus 145 basis points, and the annual facility fee is 30 basis points.

At September 30, 2015, ONEOK had $1.1 million in letters of credit issued and no borrowings under the ONEOK Credit Agreement. In February 2014, we repaid all amounts outstanding under our commercial paper program, with a portion of the proceeds received from ONE Gas in connection with the separation, and terminated the program. See Note G for additional information.

ONEOK Partners Credit Agreement - At September 30, 2015, ONEOK Partners had $287.3 million of commercial paper outstanding, $14.0 million in letters of credit issued and no borrowings under the ONEOK Partners Credit Agreement.

The ONEOK Partners Credit Agreement, which is scheduled to expire in January 2019, is a $2.4 billion revolving credit facility and includes a $100 million sublimit for the issuance of standby letters of credit and a $150 million swingline sublimit. The ONEOK Partners Credit Agreement is available for general partnership purposes. During the first quarter 2015, ONEOK Partners increased the size of the ONEOK Partners Credit Agreement to $2.4 billion from $1.7 billion by exercising its option to increase the capacity of the facility through increased commitments from existing lenders and a commitment from one new lender. During the first quarter 2015, ONEOK Partners also increased the size of its commercial paper program to $2.4 billion from $1.7 billion. Amounts outstanding under ONEOK Partners’ commercial paper program reduce the borrowing capacity under the ONEOK Partners Credit Agreement.

The ONEOK Partners Credit Agreement contains provisions for an applicable margin rate and an annual facility fee, both of which adjust with changes in its credit rating. Under the terms of the ONEOK Partners Credit Agreement, based on ONEOK Partners’ current credit ratings, borrowings, if any, will accrue at LIBOR plus 117.5 basis points, and the annual facility fee is 20 basis points. The ONEOK Partners Credit Agreement is guaranteed fully and unconditionally by the Intermediate Partnership. Borrowings under the ONEOK Partners Credit Agreement are nonrecourse to ONEOK.

The ONEOK Partners Credit Agreement contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of indebtedness to adjusted EBITDA (EBITDA, as defined in the ONEOK Partners Credit Agreement, adjusted for all noncash charges and increased for projected EBITDA from certain lender-approved capital expansion projects) of no more than 5.0 to 1. If ONEOK Partners consummates one or more acquisitions in which the aggregate purchase price is $25 million or more, the allowable ratio of indebtedness to adjusted EBITDA will increase to 5.5 to 1 for the quarter in which the acquisition was completed and the two following quarters. As a result of the West Texas LPG acquisition ONEOK Partners completed in the fourth quarter 2014, the allowable ratio of indebtedness to adjusted EBITDA increased to 5.5 to 1 through the second quarter 2015. If ONEOK Partners were to breach certain covenants in the ONEOK Partners Credit Agreement, amounts outstanding under the ONEOK Partners Credit Agreement, if any, may become due and payable immediately. At September 30, 2015, ONEOK Partners’ ratio of indebtedness to adjusted EBITDA was 4.3 to 1, and it was in compliance with all covenants under the ONEOK Partners Credit Agreement.

Neither ONEOK nor ONEOK Partners guarantees the debt or other similar commitments of unaffiliated parties. ONEOK does not guarantee the debt, commercial paper or other similar commitments of ONEOK Partners, and ONEOK Partners does not guarantee the debt or other similar commitments of ONEOK.

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FAIR VALUE MEASUREMENTS (Tables)

9 Months Ended

Sep. 30, 2015

Fair Value Disclosures [Abstract]

Recurring Fair Value Measurments

Recurring Fair Value Measurements - The following tables set forth our recurring fair value measurements for our continuing operations for the periods indicated:

	September 30, 2015
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Derivative assets
Commodity contracts
Financial contracts	$	40,799		$	—		$	5,756		$	46,555		$	(29,319	)	$	17,236
Physical contracts	—			—			4,866			4,866			—			4,866
Total derivative assets	$	40,799		$	—		$	10,622		$	51,421		$	(29,319	)	$	22,102
Derivative liabilities
Commodity contracts
Financial contracts	$	(573	)	$	—		$	(5,326	)	$	(5,899	)	$	5,899		$	—
Interest-rate contracts	—			(13,648		)	—			(13,648		)	—			(13,648		)
Total derivative liabilities	$	(573	)	$	(13,648	)	$	(5,326	)	$	(19,547	)	$	5,899		$	(13,648	)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis. We net derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and ONEOK Partners. At September 30, 2015, ONEOK Partners held $23.4 million of cash from various counterparties and no cash collateral posted.

(b) - Included in other current assets, other assets or other current liabilities in our Consolidated Balance Sheets.

	December 31, 2014
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Assets
Derivatives
Commodity contracts
Financial contracts	$	42,880		$	—		$	354		$	43,234		$	(25,979	)	$	17,255
Physical contracts	—			—			9,922			9,922			—			9,922
Interest-rate contracts	—			2,288			—			2,288			—			2,288
Total derivative assets	42,880			2,288			10,276			55,444			(25,979		)	29,465
Available-for-sale investment securities	1,773			—			—			1,773			—			1,773
Total assets	$	44,653		$	2,288		$	10,276		$	57,217		$	(25,979	)	$	31,238
Liabilities
Derivatives
Commodity contracts
Financial contracts	$	(169	)	$	—		$	(968	)	$	(1,137	)	$	1,137		$	—
Physical contracts	—			—			(23		)	(23		)	—			(23		)
Interest-rate contracts	—			(44,843		)	—			(44,843		)	—			(44,843		)
Total derivative liabilities	$	(169	)	$	(44,843	)	$	(991	)	$	(46,003	)	$	1,137		$	(44,866	)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis. We net derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and ONEOK Partners. At December 31, 2014, ONEOK Partners held $24.8 million of cash from various counterparties and no cash collateral posted.

(b) - Included in other current assets, other assets or other current liabilities in our Consolidated Balance Sheets.

Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation

The following table sets forth a reconciliation of our Level 3 fair value measurements for our continuing operations for the periods indicated:

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
Derivative Assets (Liabilities)	2015			2014			2015			2014
	(Thousands of dollars)
Net assets (liabilities) at beginning of period	$	10,387		$	(1,313	)	$	9,285		$	(782	)
Total realized/unrealized gains (losses):
Included in earnings (a)	(15		)	207			95			(688		)
Included in other comprehensive income (loss)	(5,076		)	402			(4,084		)	(2,968		)
Purchases, issuances and settlements	—			—			—			3,734
Net assets (liabilities) at end of period	$	5,296		$	(704	)	$	5,296		$	(704	)

(a) - Included in commodity sales revenues in our Consolidated Statements of Income.

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CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE (Details)	3 Months Ended	9 Months Ended
	Mar. 31, 2014 USD ($)	Sep. 30, 2015 USD ($)	Dec. 31, 2014 USD ($)
ONEOK Credit Agreement [Member]
Line of Credit Facility [Line Items]
Line Of Credit Facility Option To Increase Borrowing Capacity		$ 500,000,000
Letters of credit issued		$ 1,100,000
Interest rate description		borrowings, if any, will accrue at LIBOR plus 145 basis points
Line Of Credit Facility, Annual Facility Fee Description		the annual facility fee is 30 basis points
Indebtedness To Adjusted EBITDA Maximum		4.0
Indebtedness To Adjusted EBITDA Current		2.4
Line of Credit Facility Letter of Credit Sublimit		$ 50,000,000
Line of Credit Facility Swingline Sublimit		50,000,000
Maximum borrowing capacity		300,000,000
Write off of Deferred Debt Issuance Cost	$ 2,900,000
Short-term Bank Loans and Notes Payable		0
Partnership Credit Agreement [Member]
Line of Credit Facility [Line Items]
Commercial paper		287,300,000
Letters of credit issued		$ 14,000,000
Interest rate description		borrowings, if any, will accrue at LIBOR plus 117.5 basis points
Line Of Credit Facility, Annual Facility Fee Description		the annual facility fee is 20 basis points
Indebtedness To Adjusted EBITDA Maximum		5.0
Acquisition price threshold for increase in permitted debt to EBITDA covenant ratio		$ 25,000,000
Indebtedness To Adjusted EBITDA From Acquisitions Maximum		5.5
Indebtedness To Adjusted EBITDA Current		4.3
Line of Credit Facility Letter of Credit Sublimit		$ 100,000,000
Line of Credit Facility Swingline Sublimit		150,000,000
Maximum borrowing capacity		2,400,000,000	$ 1,700,000,000
Maximum Amount Of Commercial Paper		2,400,000,000	$ 1,700,000,000
Short-term Bank Loans and Notes Payable		$ 0

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EMPLOYEE BENEFIT PLANS

9 Months Ended

Sep. 30, 2015

Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]

EMPLOYEE BENEFIT PLANS

K. EMPLOYEE BENEFIT PLANS

The following tables set forth the components of net periodic benefit cost for our pension and postretirement benefit plans for our continuing operations for the periods indicated:

	Pension Benefits
	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2015			2014			2015			2014
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	1,887		$	1,784		$	5,661		$	5,429
Interest cost	4,546			4,488			13,638			13,744
Expected return on assets	(5,213		)	(4,775		)	(15,639		)	(14,644		)
Amortization of unrecognized prior service cost	23			48			69			144
Amortization of net loss	3,987			3,798			11,961			11,309
Other	—			16			—			136
Net periodic benefit cost	$	5,230		$	5,359		$	15,690		$	16,118

	Postretirement Benefits
	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2015			2014			2015			2014
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	186		$	175		$	558		$	533
Interest cost	587			603			1,760			1,825
Expected return on assets	(564		)	(513		)	(1,692		)	(1,623		)
Amortization of unrecognized prior service cost	(415		)	(416		)	(1,245		)	(1,246		)
Amortization of net loss	435			211			1,307			627
Other	—			—			—			(2		)
Net periodic benefit cost	$	229		$	60		$	688		$	114

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Part 1 (Policies)

9 Months Ended

Sep. 30, 2015

Accounting Standards Update 2015-05 [Member]

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Accounting Pronouncements, Policy [Policy Text Block]

In April 2015, the FASB issued ASU 2015-05, “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Fees Paid in a Cloud Computing Arrangement,” which clarifies whether a cloud computing arrangement includes a software license. If it does, the customer should account for the software license element of the arrangement consistent with the acquisition of other software licenses; if not, the customer should not account for the arrangement as a service contract. This guidance is effective for public companies for fiscal years beginning after December 15, 2015. Early adoption is permitted. We expect to adopt this guidance in the first quarter 2016, and we do not expect it to materially impact us.

Accounting Standards Update 2015-03 [Member]

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Accounting Pronouncements, Policy [Policy Text Block]

In March 2015, the FASB issued ASU 2015-03, “Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs,” which requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. In August 2015, the FASB issued ASU 2015-15, “Interest - Imputation of Interest (Subtopic 835-30): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements - Amendments to SEC Paragraphs Pursuant to Staff Announcement at June 18, 2015 EITF Meeting,” which amended the SEC paragraphs of ASC Subtopic 835-30 to include the language from the SEC Staff Announcement indicating that the SEC would not object to presenting deferred debt issuance costs related to line-of-credit agreements as assets and subsequently amortizing the deferred debt issuance costs ratably over the term of the agreement. This guidance is effective for public companies for fiscal years beginning after December 15, 2015, with early adoption permitted. We elected to adopt this guidance beginning in the second quarter 2015. Retrospective adjustment of prior periods presented was required. Therefore, the December 31, 2014, balance sheet was recast to reclassify $42.8 million of debt issuance costs from other assets to long-term debt. The impact of adopting this guidance was not material.

Accounting Standards Update 2015-02 [Member]

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Accounting Pronouncements, Policy [Policy Text Block]

In February 2015, the FASB issued ASU 2015-02, “Consolidation (Topic 810): Amendments to the Consolidation Analysis,” which eliminates the presumption that a general partner should consolidate a limited partnership. It also modifies the evaluation of whether limited partnerships are variable interest entities or voting interest entities and adds requirements that limited partnerships must meet to qualify as voting interest entities. This guidance is effective for public companies for fiscal years beginning after December 15, 2015. We expect to adopt this guidance in the first quarter 2016, and we are evaluating the impact on us.

Accounting Standards Update 2014-15 [Member]

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Accounting Pronouncements, Policy [Policy Text Block]

In August 2014, the FASB issued ASU 2014-15, “Going Concern,” which provides guidance on determining when and how to disclose going-concern uncertainties in the financial statements. The new standard requires management to perform interim and annual assessments of an entity’s ability to continue as a going concern within one year of the date the financial statements are issued. An entity must provide certain disclosures if conditions or events raise substantial doubt about the entity’s ability to continue as a going concern. The standard applies to all entities and is effective for annual periods ending after December 15, 2016, and interim periods thereafter, with early adoption permitted. We expect to adopt this guidance beginning in the fourth quarter 2016, and we do not expect it to materially impact us.

Accounting Standards Update 2014-09 [Member]

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Accounting Pronouncements, Policy [Policy Text Block]

In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers,” which outlines the principles an entity must apply to measure and recognize revenue for entities that enter into contracts to provide goods or services to their customers. The core principle is that an entity should recognize revenue at an amount that reflects the consideration to which the entity expects to be entitled in exchange for transferring goods or services to a customer. The amendment also requires more extensive disaggregated revenue disclosures in interim and annual financial statements. In August 2015, the FASB issued ASU 2015-14, “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date,” that deferred the effective date of ASU 2014-09 by one year. This update is now effective for interim and annual periods that begin after December 15, 2017, with either retrospective application for all periods presented or retrospective application with a cumulative effect adjustment. We expect to adopt this guidance beginning in the first quarter 2018, and we are evaluating the impact on us.

Accounting Standards Update 2014-08 [Member]

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Accounting Pronouncements, Policy [Policy Text Block]

In April 2014, the FASB issued ASU 2014-08, “Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity,” which alters the definition of a discontinued operation to include only asset disposals that represent a strategic shift with a major effect on an entity’s operations and financial results. The amendment also requires more extensive disclosures about a discontinued operation’s assets, liabilities, income, expenses and cash flows. This guidance will be effective for interim and annual periods for all assets that are disposed of or classified as being held for sale in fiscal years that begin on or after December 15, 2014. We adopted this guidance beginning in the first quarter 2015, and it could impact us in the future if we dispose of any individually significant components.

Accounting Standards Update 2015-16 [Member]

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Accounting Pronouncements, Policy [Policy Text Block]

In September 2015, the FASB issued ASU 2015-16, “Business Combinations (Topic 805) - Simplifying the Accounting for Measurement-Period Adjustments,” which requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. The amendment also requires the acquirer to record the income statement effects of changes to provisional amounts in the financial statements in the period in which the adjustments occurred. This guidance is effective for public companies for fiscal years beginning after December 15, 2015, with early adoption permitted. We expect to adopt this guidance in the first quarter 2016, and it could impact us in the future if we complete any acquisitions with subsequent measurement period adjustments.

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES Part 2 (Details) $ in Millions	9 Months Ended
	Sep. 30, 2015 USD ($) MMcf MMBbls	Dec. 31, 2014 USD ($) MMcf MMBbls
Derivative [Line Items]
Notional Amount Of Cash Flow Hedge Instruments Settled	$ 500.0
Realized Loss On Settled Interest Rate Swaps Recorded in AOCI	$ 55.1
Not Designated as Hedging Instrument [Member] | Fixed Price [Member] | Sold [Member] | Crude oil and NGLs [Member] | Futures, forwards and swaps [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBbls	(0.5)	0.0
Not Designated as Hedging Instrument [Member] | Fixed Price [Member] | Purchased [Member] | Crude oil and NGLs [Member] | Futures, forwards and swaps [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBbls	0.5	0.0
Designated as Hedging Instrument [Member] | Sold [Member] | Forward Starting Interest Rate Swap [Member]
Derivative [Line Items]
Derivative, Notional Amount	$ 0.0	$ 0.0
Designated as Hedging Instrument [Member] | Fixed Price [Member] | Sold [Member] | Natural Gas [Member] | Futures and swaps [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMcf	(38,700)	(41,200)
Designated as Hedging Instrument [Member] | Fixed Price [Member] | Sold [Member] | Crude oil and NGLs [Member] | Futures, forwards and swaps [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBbls	(3.5)	(0.5)
Designated as Hedging Instrument [Member] | Fixed Price [Member] | Purchased [Member] | Natural Gas [Member] | Futures and swaps [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMcf	0	0
Designated as Hedging Instrument [Member] | Fixed Price [Member] | Purchased [Member] | Crude oil and NGLs [Member] | Futures, forwards and swaps [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBbls	0.0	0.0
Designated as Hedging Instrument [Member] | Basis [Member] | Sold [Member] | Natural Gas [Member] | Futures and swaps [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMcf	(38,700)	(41,200)
Designated as Hedging Instrument [Member] | Basis [Member] | Purchased [Member] | Natural Gas [Member] | Futures and swaps [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMcf	0	0
Interest Rate Contract [Member] | Designated as Hedging Instrument [Member] | Purchased [Member] | Forward Starting Interest Rate Swap [Member]
Derivative [Line Items]
Notional Amount Of Cash Flow Hedge Instruments Greater Than 12 Months	$ 400.0
Derivative, Notional Amount	$ 400.0	$ 900.0

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SEGMENTS (Tables)

9 Months Ended

Sep. 30, 2015

Segment Reporting Information [Line Items]

Segments

The following tables set forth certain selected financial information for our operating segments for the periods indicated:

Three Months Ended September 30, 2015	Natural Gas Gathering and Processing		Natural Gas Liquids (a)			Natural Gas Pipelines (b)			Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	294,948	$	1,522,224		$	81,246		$	528		$	1,898,946
Intersegment revenues	139,388		89,230			1,751			(230,369		)	—
Total revenues	$	434,336	$	1,611,454		$	82,997		$	(229,841	)	$	1,898,946
Net margin	$	140,655	$	321,772		$	75,369		$	341		$	538,137
Operating costs	61,162		74,464			26,674			1,877			164,177
Depreciation and amortization	37,286		39,317			10,914			782			88,299
Gain (loss) on sale of assets	132		(498		)	(77		)	(283		)	(726		)
Operating income	$	42,339	$	207,493		$	37,704		$	(2,601	)	$	284,935
Equity in net earnings from investments	$	4,350	$	10,912		$	16,982		$	—		$	32,244
Capital expenditures	$	231,835	$	52,807		$	14,718		$	1,508		$	300,868

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $252.8 million, of which $204.7 million was related to sales within the segment, net margin of $140.1 million and operating income of $80.3 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $65.1 million, net margin of $57.9 million and operating income of $24.7 million.

Three Months Ended September 30, 2014	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)		Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	374,403		$	2,667,939		$	77,027	$	776		$	3,120,145
Intersegment revenues	403,399			66,581			2,133		(472,113		)	—
Total revenues	$	777,802		$	2,734,520		$	79,160	$	(471,337	)	$	3,120,145
Net margin	$	178,171		$	282,963		$	73,399	$	2,408		$	536,941
Operating costs	64,279			76,946			27,998		3,272			172,495
Depreciation and amortization	31,327			31,661			10,913		687			74,588
Gain (loss) on sale of assets	324			(535		)	1,746		(1		)	1,534
Operating income	$	82,889		$	173,821		$	36,234	$	(1,552	)	$	291,392
Equity in net earnings (loss) from investments	$	(71,069	)	$	4,351		$	14,371	$	—		$	(52,347	)
Capital expenditures	$	214,917		$	153,785		$	10,650	$	2,833		$	382,185

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $190.3 million, of which $170.1 million related to sales within the segment, net margin of $94.3 million and operating income of $46.4 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $65.2 million, net margin of $57.4 million and operating income of $23.4 million.

Nine Months Ended September 30, 2015	Natural Gas Gathering and Processing		Natural Gas Liquids (a)			Natural Gas Pipelines (b)			Other and Eliminations (c)			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	862,462	$	4,726,617		$	241,605		$	1,620		$	5,832,304
Intersegment revenues	487,559		229,804			5,053			(722,416		)	—
Total revenues	$	1,350,021	$	4,956,421		$	246,658		$	(720,796	)	$	5,832,304
Net margin	$	402,482	$	902,382		$	218,599		$	1,075		$	1,524,538
Operating costs	193,922		234,120			79,156			1,347			508,545
Depreciation and amortization	109,035		118,044			32,484			1,678			261,241
Gain (loss) on sale of assets	328		(579		)	(76		)	(283		)	(610		)
Operating income	$	99,853	$	549,639		$	106,883		$	(2,233	)	$	754,142
Equity in net earnings from investments	$	13,511	$	27,585		$	52,109		$	—		$	93,205
Investments in unconsolidated affiliates	$	253,548	$	484,403		$	399,108		$	—		$	1,137,059
Total assets	$	5,206,987	$	8,041,064		$	1,837,776		$	422,471		$	15,508,298
Noncontrolling interests in consolidated subsidiaries	$	4,066	$	161,210		$	—		$	3,457,557		$	3,622,833
Capital expenditures	$	692,570	$	185,360		$	39,923		$	12,463		$	930,316

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $690.1 million, of which $556.4 million was related to sales within the segment, net margin of $392.7 million and operating income of $218.8 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $198.5 million, net margin of $175.9 million and operating income of $77.8 million.

(c) - Other and Eliminations includes assets of discontinued operations of $20.5 million.

Nine Months Ended September 30, 2014	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)		Other and Eliminations (c)			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	1,095,531		$	7,950,930		$	247,420	$	2,916		$	9,296,797
Sales to affiliated customers	41,214			—			12,312		—			53,526
Intersegment revenues	1,126,547			160,712			6,206		(1,293,465		)	—
Total revenues	$	2,263,292		$	8,111,642		$	265,938	$	(1,290,549	)	$	9,350,323
Net margin	$	486,695		$	818,086		$	242,359	$	(4,092	)	$	1,543,048
Operating costs	188,489			218,129			82,747		4,263			493,628
Depreciation and amortization	89,612			89,848			32,623		2,046			214,129
Gain (loss) on sale of assets	277			(572		)	1,663		165			1,533
Operating income	$	208,871		$	509,537		$	128,652	$	(10,236	)	$	836,824
Equity in net earnings (loss) from investments	$	(60,484	)	$	13,574		$	53,657	$	—		$	6,747
Investments in unconsolidated affiliates	$	253,930		$	484,238		$	390,341	$	—		$	1,128,509
Total assets	$	4,415,814		$	7,337,688		$	1,832,368	$	726,326		$	14,312,196
Noncontrolling interests in consolidated subsidiaries	$	4,394		$	—		$	—	$	3,131,769		$	3,136,163
Capital expenditures	$	506,016		$	637,524		$	25,987	$	34,859		$	1,204,386

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $479.4 million, of which $417.0 million related to sales within the segment, net margin of $263.4 million and operating income of $126.0 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $214.8 million, net margin of $185.5 million and operating income of $84.6 million.

(c) - Other and Eliminations includes assets and capital expenditures of discontinued operations of $84.2 million and $23.9 million, respectively.

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME Parenthetical - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Other comprehensive income (loss), net of tax
Unrealized gains (losses) on energy marketing and risk-management assets/liabilities, tax	$ (1,109)	$ (1,160)	$ (2,156)	$ 12,664
Realized losses (gains) in net income, tax	2,957	(748)	5,621	(14,996)
Unrealized holding gains (losses) on available-for-sale securities, tax	0	(73)	648	(36)
Change in pension and postretirement benefit plan liability, tax	$ (1,599)	$ (1,456)	$ (4,798)	$ (5,379)

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CONSOLIDATED STATEMENT OF CHANGES IN EQUITY Parenthetical - $ / shares	3 Months Ended			9 Months Ended
	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Sep. 30, 2015	Sep. 30, 2014
Statement of Stockholders' Equity [Abstract]
Common Stock, Dividends, Per Share, Cash Paid	$ 0.605	$ 0.605	$ 0.605	$ 1.815	$ 1.535

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ONEOK PARTNERS (Details) $ / shares in Units, $ in Thousands, shares in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2015 USD ($) $ / shares $ / unit shares	Sep. 30, 2014 USD ($) $ / shares shares	Jun. 30, 2014 USD ($) $ / shares shares	Sep. 30, 2015 USD ($) $ / shares shares	Sep. 30, 2014 USD ($) $ / shares shares
Related Party Transaction [Line Items]
Key Provisions of Operating or Partnership Agreement, Description				Cash Distributions - We receive distributions from ONEOK Partners on our common and Class B units and our 2 percent general partner interest, which includes our incentive distribution rights. Under the Partnership Agreement, distributions are made to the partners with respect to each calendar quarter in an amount equal to 100 percent of available cash as defined in the Partnership Agreement. Available cash generally will be distributed 98 percent to limited partners and 2 percent to the general partner. The general partner’s percentage interest in quarterly distributions is increased after certain specified target levels are met during the quarter. Under the incentive distribution provisions, as set forth in the Partnership Agreement the general partner receives: 15 percent of amounts distributed in excess of $0.3025 per unit; 25 percent of amounts distributed in excess of $0.3575 per unit; and 50 percent of amounts distributed in excess of $0.4675 per unit.
Remaining Capacity of At The Market Equity Program	$ 138,000			$ 138,000
Partners Capital Account Units Sold Under Equity Distribution Agreement | shares	3.3	1.4		10.5	4.4
Ownership Interest				41.20%
Common units | shares	41.3			41.3
Class B units | shares	73.0			73.0
Aggregate Amount Of Common Units Available For Issuance And Sale Under Equity Distribution Agreement				$ 650,000
Issuance of common units of ONEOK Partners				$ 394,144	$ 877,658
General Partner [Member]
Related Party Transaction [Line Items]
Ownership Interest				2.00%
Limited Partner [Member]
Related Party Transaction [Line Items]
Ownership Interest				39.20%
Distribution Paid [Member]
Related Party Transaction [Line Items]
Distribution per unit | $ / shares	$ 0.790	$ 0.760		$ 2.370	$ 2.235
Distributions to general partner	$ 97,875	$ 85,882		$ 288,912	$ 235,908
Total distributions	304,039	275,045		897,474	768,094
Distribution Paid [Member] | ONEOK [Member]
Related Party Transaction [Line Items]
Limited partner distributions to ONEOK	73,302	70,519		219,907	207,381
Distribution Paid [Member] | General Partner [Member]
Related Party Transaction [Line Items]
General partner distributions	6,081	5,501		17,950	15,361
Incentive distributions	91,794	80,381		270,962	220,547
Distribution Paid [Member] | Limited Partner [Member]
Related Party Transaction [Line Items]
Partners Capital Account Distributions to Other Unitholders	$ 132,862	$ 118,644		$ 388,655	$ 324,805
Distribution Declared [Member]
Related Party Transaction [Line Items]
Distribution per unit | $ / shares	$ 0.790	$ 0.775		$ 2.370	$ 2.280
Distribution Made To Member Or Limited Parter Annualized Quarterly Distribution | $ / unit	3.16
Distributions to general partner	$ 107,198	$ 90,135		$ 300,917	$ 252,939
Total distributions	$ 333,001	284,151		934,769	809,751
Distribution Made to Limited Partner, Date of Record	Nov. 02, 2015
Distribution Made to Limited Partner, Distribution Date	Nov. 13, 2015
Distribution Declared [Member] | ONEOK [Member]
Related Party Transaction [Line Items]
Limited partner distributions to ONEOK	$ 90,323	71,911		236,927	211,557
Distribution Declared [Member] | General Partner [Member]
Related Party Transaction [Line Items]
General partner distributions	6,660	5,683		18,696	16,195
Incentive distributions	100,538	84,452		282,221	236,744
Distribution Declared [Member] | Limited Partner [Member]
Related Party Transaction [Line Items]
Partners Capital Account Distributions to Other Unitholders	135,480	122,105		396,925	345,255
Private Placement [Member]
Related Party Transaction [Line Items]
Proceeds from Sale of Interest in Partnership Unit	749,000
Partners' Capital Account, Contributions	$ 15,300
Partners' Capital Account, Units, Sold in Private Placement | shares	21.5
Per Unit Offering Price Under Private Placement | $ / shares	$ 30.17
Issued under public offering [Member]
Related Party Transaction [Line Items]
Public offering price of common units | $ / shares			$ 52.94
Proceeds from Sale of Interest in Partnership Unit			$ 714,500
Partners' Capital Account, Contributions			$ 15,000
Partners' Capital Account, Units, Sold in Public Offering | shares			13.9
Paid-in Capital [Member]
Related Party Transaction [Line Items]
Issuance of common units of ONEOK Partners				(34,446)	138,310
Issued Under Equity Distribution Agreement [Member]
Related Party Transaction [Line Items]
Per Unit Offering Price Under Equity Distribution Agreement | $ / shares	$ 30.17
Proceeds from Sale of Interest in Partnership Unit		81,300		381,600	245,400
ONEOK [Member]
Related Party Transaction [Line Items]
Revenue	$ 0	0		0	53,526
Expenses
Cost of sales and fuel	0	0		0	10,835
Related Party Transaction, Expenses from Transactions with Related Party	89,342	84,221		265,611	240,172
Total expenses	$ 89,342	$ 84,221		$ 265,611	$ 251,007

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Part 2 (Policies)

9 Months Ended

Sep. 30, 2015

Accounting Policies [Abstract]

Basis of Accounting

Our accompanying unaudited consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC. These statements have been prepared in accordance with GAAP and reflect all adjustments that, in our opinion, are necessary for a fair presentation of the results for the interim periods presented. All such adjustments are of a normal recurring nature. The 2014 year-end consolidated balance sheet data was derived from our audited financial statements but does not include all disclosures required by GAAP. These unaudited consolidated financial statements should be read in conjunction with our audited consolidated financial statements in our Annual Report.

Our significant accounting policies are consistent with those disclosed in Note A of the Notes to Consolidated Financial Statements in our Annual Report.

Organization and Nature of Operations - We are the sole general partner and own limited partner units of ONEOK Partners (NYSE: OKS), which together represent an aggregate 41.2 percent interest in ONEOK Partners at September 30, 2015. The results of operations for our former natural gas distribution and energy services businesses have been classified as discontinued operations for all periods presented. See Note B for additional information.

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

Goodwill and Intangible Assets, Policy [Policy Text Block]

We assess our goodwill for impairment at least annually on July 1, unless events or changes in circumstances indicate an impairment may have occurred before that time.  At July 1, 2015, we assessed qualitative factors to determine whether it was more likely than not that the fair value of each of our reporting units was less than its carrying amount. Due to the current commodity price environment, we elected to perform a quantitative assessment, or Step 1 analysis, to test our goodwill for impairment. The assessment included our current commodity price assumptions, expected contractual terms, anticipated operating costs and volume estimates.  Our goodwill impairment analysis performed as of July 1, 2015, did not result in an impairment charge nor did our analysis reflect any reporting units at risk.  In each reporting unit, the fair value substantially exceeded its carrying value. Subsequent to that date, no event has occurred indicating that the implied fair value of each of the reporting units is less than the carrying value of its net assets.

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EMPLOYEE BENEFIT PLANS (Tables)

9 Months Ended

Sep. 30, 2015

Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]

The components of net periodic benefit cost

The following tables set forth the components of net periodic benefit cost for our pension and postretirement benefit plans for our continuing operations for the periods indicated:

	Pension Benefits
	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2015			2014			2015			2014
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	1,887		$	1,784		$	5,661		$	5,429
Interest cost	4,546			4,488			13,638			13,744
Expected return on assets	(5,213		)	(4,775		)	(15,639		)	(14,644		)
Amortization of unrecognized prior service cost	23			48			69			144
Amortization of net loss	3,987			3,798			11,961			11,309
Other	—			16			—			136
Net periodic benefit cost	$	5,230		$	5,359		$	15,690		$	16,118

	Postretirement Benefits
	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2015			2014			2015			2014
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	186		$	175		$	558		$	533
Interest cost	587			603			1,760			1,825
Expected return on assets	(564		)	(513		)	(1,692		)	(1,623		)
Amortization of unrecognized prior service cost	(415		)	(416		)	(1,245		)	(1,246		)
Amortization of net loss	435			211			1,307			627
Other	—			—			—			(2		)
Net periodic benefit cost	$	229		$	60		$	688		$	114

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EARNINGS PER SHARE

9 Months Ended

Sep. 30, 2015

Earnings Per Share [Abstract]

EARNINGS PER SHARE

J. EARNINGS PER SHARE

The following tables set forth the computation of basic and diluted EPS from continuing operations for the periods indicated:

	Three Months Ended September 30, 2015
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	86,017	210,296	$	0.41
Diluted EPS from continuing operations
Effect of dilutive securities	—		228
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	86,017	210,524	$	0.41

	Three Months Ended September 30, 2014
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	64,629	209,489	$	0.31
Diluted EPS from continuing operations
Effect of dilutive securities	—		1,270
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	64,629	210,759	$	0.31

	Nine Months Ended September 30, 2015
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	223,606	210,138	$	1.06
Diluted EPS from continuing operations
Effect of dilutive securities	—		371
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	223,606	210,509	$	1.06

	Nine Months Ended September 30, 2014
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	225,969	209,341	$	1.08
Diluted EPS from continuing operations
Effect of dilutive securities	—		1,141
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	225,969	210,482	$	1.07