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 June 30, 2016.

OR

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

For the transition period from __________ to __________.

Commission file number   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 July 25, 2016, the Company had 210,426,799 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 Six Months Ended June 30, 2016 and 2015	6
	Consolidated Statements of Comprehensive Income - Three and Six Months Ended June 30, 2016 and 2015	7
	Consolidated Balance Sheets - June 30, 2016, and December 31, 2015	8
	Consolidated Statements of Cash Flows - Six Months Ended June 30, 2016 and 2015	11
	Consolidated Statements of Changes in Equity - Six Months Ended June 30, 2016 and 2015	12
	Notes to Consolidated Financial Statements	14
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	37
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	60
Item 4.	Controls and Procedures	62
Part II.	Other Information	63
Item 1.	Legal Proceedings	63
Item 1A.	Risk Factors	63
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	63
Item 3.	Defaults Upon Senior Securities	63
Item 4.	Mine Safety Disclosures	63
Item 5.	Other Information	63
Item 6.	Exhibits	64
Signature		65

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.

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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, 2015
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
CFTC	U.S. Commodity Futures Trading Commission
Clean Air Act	Federal Clean Air Act, as amended
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
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.
NGL(s)	Natural gas liquid(s)
NGL products	Marketable natural gas liquid 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
ONEOK	ONEOK, Inc.
ONEOK Credit Agreement	ONEOK’s $300 million amended and restated revolving credit agreement effective as of January 31, 2014
ONEOK Partners	ONEOK Partners, L.P.
ONEOK Partners Credit Agreement	ONEOK Partners’ $2.4 billion amended and restated revolving credit agreement effective as of 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
Quarterly Report(s)	Quarterly Report(s) on Form 10-Q
Roadrunner	Roadrunner Gas Transmission, LLC
S&P	S&P Global Ratings
SCOOP	South Central Oklahoma Oil Province, an area in the Anadarko Basin in Oklahoma
SEC	Securities and Exchange Commission
STACK	Sooner Trend Anadarko Canadian Kingfisher, an area in the Anadarko Basin in Oklahoma
Term Loan Agreement	ONEOK Partners’ senior unsecured delayed-draw three-year $1.0 billion term loan agreement dated January 8, 2016

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West Texas LPG	West Texas LPG Pipeline Limited Partnership and Mesquite Pipeline
WTI	West Texas Intermediate
XBRL	eXtensible Business Reporting Language

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PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF INCOME
	Three Months Ended						Six Months Ended
	June 30,						June 30,
(Unaudited)	2016			2015			2016			2015
	(Thousands of dollars, except per share amounts)
Revenues
Commodity sales	$	1,633,272		$	1,722,254		$	2,916,783		$	3,157,970
Services	500,835			405,798			991,783			775,388
Total revenues	2,134,107			2,128,052			3,908,566			3,933,358
Cost of sales and fuel (exclusive of items shown separately below)	1,527,323			1,603,093			2,723,061			2,946,957
Operations and maintenance	167,667			140,869			322,812			295,200
Depreciation and amortization	99,247			86,987			193,725			172,942
General taxes	24,172			24,481			46,042			49,168
(Gain) loss on sale of assets	413			(122		)	(3,793		)	(116		)
Operating income	315,285			272,744			626,719			469,207
Equity in net earnings from investments (Note J)	32,372			30,040			65,286			60,961
Allowance for equity funds used during construction	—			742			208			1,541
Other income	4,804			60			5,109			2,670
Other expense	(941		)	(1,960		)	(1,578		)	(2,738		)
Interest expense (net of capitalized interest of $2,572, $9,927, $5,459 and $17,157, respectively)	(118,976		)	(102,384		)	(237,223		)	(199,134		)
Income before income taxes	232,544			199,242			458,521			332,507
Income taxes	(52,458		)	(48,222		)	(102,524		)	(85,650		)
Income from continuing operations	180,086			151,020			355,997			246,857
Income (loss) from discontinued operations, net of tax (Note M)	(227		)	(140		)	(1,179		)	(284		)
Net income	179,859			150,880			354,818			246,573
Less: Net income attributable to noncontrolling interests	93,915			74,375			185,428			109,268
Net income attributable to ONEOK	$	85,944		$	76,505		$	169,390		$	137,305
Amounts attributable to ONEOK:
Income from continuing operations	$	86,171		$	76,645		$	170,569		$	137,589
Income (loss) from discontinued operations	(227		)	(140		)	(1,179		)	(284		)
Net income	$	85,944		$	76,505		$	169,390		$	137,305
Basic earnings per share:
Income from continuing operations (Note H)	$	0.41		$	0.36		$	0.81		$	0.65
Income (loss) from discontinued operations	—			—			(0.01		)	—
Net income	$	0.41		$	0.36		$	0.80		$	0.65
Diluted earnings per share:
Income from continuing operations (Note H)	$	0.41		$	0.36		$	0.81		$	0.65
Income (loss) from discontinued operations	(0.01		)	—			(0.01		)	—
Net income	$	0.40		$	0.36		$	0.80		$	0.65
Average shares (thousands)
Basic	211,075			210,204			210,928			210,059
Diluted	212,618			210,477			211,663			210,486
Dividends declared per share of common stock	$	0.615		$	0.605		$	1.23		$	1.21

See accompanying Notes to Consolidated Financial Statements.

6

ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
	Three Months Ended						Six Months Ended
	June 30,						June 30,
(Unaudited)	2016			2015			2016			2015
	(Thousands of dollars)
Net income	$	179,859		$	150,880		$	354,818		$	246,573
Other comprehensive income (loss), net of tax
Unrealized gains (losses) on derivatives, net of taxof $13,295, $(2,726), $16,334 and $(1,047), respectively	(73,923		)	15,255			(90,817		)	4,377
Realized (gains) losses on derivatives in net income, net of tax of $1,193, $1,439, $2,469 and $2,664, respectively	(8,054		)	(11,041		)	(16,579		)	(20,271		)
Unrealized holding gains (losses) on available-for-sale securities, net of tax of $0, $0, $0 and $648, respectively	—			—			—			(955		)
Change in pension and postretirement benefit plan liability, net of tax of $(1,035), $(1,600), $(2,070) and $(3,199), respectively	1,552			2,441			3,105			4,879
Other comprehensive income (loss) on investments in unconsolidated affiliates, net of tax of $848, $0, $1,732 and $0, respectively	(4,714		)	—			(9,631		)	—
Total other comprehensive income (loss), net of tax	(85,139		)	6,655			(113,922		)	(11,970		)
Comprehensive income	94,720			157,535			240,896			234,603
Less: Comprehensive income attributable to noncontrolling interests	33,408			76,472			103,510			96,279
Comprehensive income attributable to ONEOK	$	61,312		$	81,063		$	137,386		$	138,324

See accompanying Notes to Consolidated Financial Statements.

7

ONEOK, Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS
	June 30,		December 31,
(Unaudited)	2016		2015
Assets	(Thousands of dollars)
Current assets
Cash and cash equivalents	$	180,854	$	97,619
Accounts receivable, net	672,059		593,979
Materials and supplies	85,127		76,696
Natural gas and natural gas liquids in storage	245,946		128,084
Commodity imbalances	38,300		38,681
Other current assets	58,200		39,946
Assets of discontinued operations (Note M)	702		205
Total current assets	1,281,188		975,210
Property, plant and equipment
Property, plant and equipment	14,811,606		14,530,460
Accumulated depreciation and amortization	2,326,984		2,156,471
Net property, plant and equipment	12,484,622		12,373,989
Investments and other assets
Investments in unconsolidated affiliates	913,813		948,221
Goodwill and intangible assets	1,011,309		1,017,258
Other assets	118,980		112,598
Assets of discontinued operations (Note M)	12,988		18,835
Total investments and other assets	2,057,090		2,096,912
Total assets	$	15,822,900	$	15,446,111

See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS
(Continued)
	June 30,			December 31,
(Unaudited)	2016			2015
Liabilities and equity	(Thousands of dollars)
Current liabilities
Current maturities of long-term debt (Note E)	$	460,650		$	110,650
Short-term borrowings (Note D)	576,307			546,340
Accounts payable	697,833			615,982
Commodity imbalances	105,544			74,460
Accrued interest	119,774			129,043
Other current liabilities	202,954			132,556
Liabilities of discontinued operations (Note M)	25,359			29,235
Total current liabilities	2,188,421			1,638,266
Long-term debt, excluding current maturities (Note E)	8,320,277			8,323,582
Deferred credits and other liabilities
Deferred income taxes	1,518,328			1,436,715
Other deferred credits	293,153			264,248
Liabilities of discontinued operations (Note M)	10,544			16,964
Total deferred credits and other liabilities	1,822,025			1,717,927
Commitments and contingencies (Note L)
Equity (Note F)
ONEOK shareholders’ equity:
Common stock, $0.01 par value: authorized 600,000,000 shares; issued 245,811,180 shares and outstanding 210,418,903 shares at June 30, 2016; issued 245,811,180 shares and outstanding 209,731,028 shares at December 31, 2015	2,458			2,458
Paid-in capital	1,294,583			1,378,444
Accumulated other comprehensive loss (Note G)	(159,246		)	(127,242		)
Retained earnings	—			—
Treasury stock, at cost: 35,392,277 shares at June 30, 2016, and 36,080,152 shares at December 31, 2015	(900,366		)	(917,862		)
Total ONEOK shareholders’ equity	237,429			335,798
Noncontrolling interests in consolidated subsidiaries	3,254,748			3,430,538
Total equity	3,492,177			3,766,336
Total liabilities and equity	$	15,822,900		$	15,446,111

See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF CASH FLOWS
	Six Months Ended
	June 30,
(Unaudited)	2016			2015
	(Thousands of dollars)
Operating activities
Net income	$	354,818		$	246,573
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	193,725			172,942
Equity in net earnings from investments	(65,286		)	(60,961		)
Distributions received from unconsolidated affiliates	72,204			61,969
Deferred income taxes	105,567			84,306
Share-based compensation expense	23,194			7,884
Pension and postretirement benefit expense, net of contributions	6,172			7,372
Allowance for equity funds used during construction	(208		)	(1,541		)
Gain on sale of assets	(3,793		)	(116		)
Changes in assets and liabilities:
Accounts receivable	(85,435		)	59,120
Natural gas and natural gas liquids in storage	(117,862		)	(16,003		)
Accounts payable	103,976			(136,119		)
Commodity imbalances, net	31,465			20,497
Settlement of exit activities liabilities	(11,590		)	(22,385		)
Accrued interest	(9,269		)	10,206
Risk-management assets and liabilities	(60,016		)	(66,148		)
Other assets and liabilities, net	(6,056		)	(33,676		)
Cash provided by operating activities	531,606			333,920
Investing activities
Capital expenditures (less allowance for equity funds used during construction)	(333,254		)	(629,448		)
Contributions to unconsolidated affiliates	(19,830		)	(33,222		)
Distributions received from unconsolidated affiliates in excess of cumulative earnings	36,373			18,814
Proceeds from sale of assets	18,232			691
Other	—			(12,607		)
Cash used in investing activities	(298,479		)	(655,772		)
Financing activities
Borrowing (repayment) of short-term borrowings, net	29,967			(184,812		)
Issuance of long-term debt, net of discounts	1,000,000			798,896
Debt financing costs	(2,770		)	(7,850		)
Repayment of long-term debt	(654,151		)	(3,875		)
Issuance of common stock	11,101			10,298
Issuance of common units, net of issuance costs	—			275,098
Dividends paid	(258,508		)	(252,416		)
Distributions to noncontrolling interests	(275,259		)	(260,488		)
Cash provided by (used in) financing activities	(149,620		)	374,851
Change in cash and cash equivalents	83,507			52,999
Change in cash and cash equivalents included in discontinued operations	(272		)	382
Change in cash and cash equivalents from continuing operations	83,235			53,381
Cash and cash equivalents at beginning of period	97,619			172,812
Cash and cash equivalents at end of period	$	180,854		$	226,193

See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
	ONEOK Shareholders’ Equity
(Unaudited)	Common Stock Issued	Common Stock		Paid-in Capital			Accumulated Other Comprehensive Loss
	(Shares)	(Thousands of dollars)
January 1, 2016	245,811,180	$	2,458	$	1,378,444		$	(127,242	)
Net income	—	—		—			—
Other comprehensive income (loss) (Note G)	—	—		—			(32,004		)
Common stock issued	—	—		(2,034		)	—
Common stock dividends - $1.23 per share (Note F)	—	—		(89,118		)	—
Distributions to noncontrolling interests	—	—		—			—
Other	—	—		7,291			—
June 30, 2016	245,811,180	$	2,458	$	1,294,583		$	(159,246	)

	ONEOK Shareholders’ Equity
(Unaudited)	Common Stock Issued	Common Stock		Paid-in Capital			Accumulated Other Comprehensive 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 G)	—	—		—			1,019
Common stock issued	—	—		(4,300		)	—
Common stock dividends - $1.21 per share (Note F)	—	—		—			—
Issuance of common units of ONEOK Partners (Note K)	—	—		26,294			—
Distributions to noncontrolling interests	—	—		—			—
Other	—	—		739			—
June 30, 2015	245,811,180	$	2,458	$	1,564,316		$	(135,334	)

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS 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, 2016	$	—		$	(917,862	)	$	3,430,538		$	3,766,336
Net income	169,390			—			185,428			354,818
Other comprehensive income (loss) (Note G)	—			—			(81,918		)	(113,922		)
Common stock issued	—			17,496			—			15,462
Common stock dividends - $1.23 per share (Note F)	(169,390		)	—			—			(258,508		)
Distributions to noncontrolling interests	—			—			(275,259		)	(275,259		)
Other	—			—			(4,041		)	3,250
June 30, 2016	$	—		$	(900,366	)	$	3,254,748		$	3,492,177

	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	137,305			—			109,268			246,573
Other comprehensive income (loss) (Note G)	—			—			(12,989		)	(11,970		)
Common stock issued	—			16,650			—			12,350
Common stock dividends - $1.21 per share (Note F)	(252,416		)	—			—			(252,416		)
Issuance of common units of ONEOK Partners (Note K)	—			—			232,254			258,548
Distributions to noncontrolling interests	—			—			(260,488		)	(260,488		)
Other	102			—			38			879
June 30, 2015	$	23,119		$	(937,051	)	$	3,481,851		$	3,999,359

See accompanying Notes to Consolidated Financial Statements.

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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 statement of the results for the interim periods presented. All such adjustments are of a normal recurring nature. The 2015 year-end consolidated balance sheet data was derived from our audited financial statements but does not include all disclosures required by GAAP. Certain reclassifications have been made in the prior-year financial statements to conform to the current-year presentation. These unaudited consolidated financial statements should be read in conjunction with our audited consolidated financial statements in our Annual Report.

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

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

Consolidation - Our consolidated financial statements include our accounts and the accounts of our subsidiaries over which we have control or are the primary beneficiary. Management’s judgment is required when:

• determining whether an entity is a variable interest entity (VIE);

• determining whether we are the primary beneficiary of a VIE; and

• identifying events that require reconsideration of whether an entity is a VIE.

As a result of adopting ASU 2015-02 described below, we have concluded that ONEOK Partners is a VIE and that we are the primary beneficiary. Therefore, we continue to consolidate ONEOK Partners. See Note K for additional information.

We record noncontrolling interests in consolidated subsidiaries on our Consolidated Balance Sheets to recognize the portion of ONEOK Partners that we do not own. We reflect our ownership interest in ONEOK Partners’ accumulated other comprehensive income (loss) in our consolidated accumulated other comprehensive income (loss). The remaining portion is reflected as an adjustment to noncontrolling interests in consolidated subsidiaries.

Recently Issued Accounting Standards Update - 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 was effective for public companies for fiscal years beginning after December 15, 2015. We adopted this guidance in the first quarter 2016, and there was no impact, but it could impact us in the future if we complete any acquisitions with subsequent measurement period adjustments.

In May 2015, the FASB issued ASU 2015-07, “Fair Value Measurement (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent),” which removes the requirement to categorize within the fair value hierarchy all investments for which fair value is measured using the net asset value per share practical expedient. The amendment also removes the requirement to make certain disclosures for all investments that are eligible to be measured at fair value using the net asset value per share practical expedient. This guidance was effective for public companies for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. We adopted this guidance in the first quarter 2016. The impact of adopting this guidance was not material.

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 account for the arrangement as a service contract. This guidance was effective for public companies for fiscal years beginning after December 15, 2015. We adopted this guidance in the first quarter 2016. The impact of adopting this guidance was not material.

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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 was effective for public companies for fiscal years beginning after December 15, 2015. We adopted this guidance in the first quarter 2016. As a result of adopting this guidance, we no longer consolidate ONEOK Partners under the presumption that a general partner should consolidate a limited partnership. We concluded, however, that ONEOK Partners is a VIE and ONEOK is the primary beneficiary, and we therefore consolidate ONEOK Partners under the variable interest model of consolidation. There was no financial statement impact due to the change in consolidation methodology. See Note K for additional information.

In June 2016, the FASB issued ASU 2016-13, “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments,” which requires a financial asset (or a group of financial assets) measured at amortized cost basis to be presented net of the allowance for credit losses to reflect the net carrying value at the amount expected to be collected on the financial asset; and the initial allowance for credit losses for purchased financial assets, including available-for-sale debt securities, to be added to the purchase price rather than being reported as a credit loss expense. This guidance is effective for public companies for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. Early adoption is permitted for the fiscal years beginning after December 15, 2018. We expect to adopt this guidance in the first quarter 2020, and we are evaluating the impact on us.

In March 2016, the FASB issued ASU 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting,” which provides simplified accounting for share-based payment transactions in relation to income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. This guidance is effective for public companies for annual periods beginning after December 15, 2016, and interim periods within those annual periods, with early adoption permitted. We expect to adopt this guidance in the first quarter 2017, and we are evaluating the impact on us.

In March 2016, the FASB issued ASU 2016-06, “Derivatives and Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments,” which clarifies the requirements for assessing whether a contingent call (put) option that can accelerate the payment of principal on a debt instrument is clearly and closely related to its debt host. Under the amendments in the update, assessments must be performed in accordance with the four-step decision sequence to conclude which call (put) options should be bifurcated and accounted for separately as derivatives. This guidance is effective for public companies for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years, with early adoption permitted. We expect to adopt this guidance in the first quarter 2017, and we are evaluating the impact on us.

In March 2016, the FASB issued ASU 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships,” which clarifies that a change in the counterparty to a derivative instrument that has been designated as the hedging instrument under Topic 815 does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge accounting criteria continue to be met. This guidance is effective for public companies for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. Early adoption is permitted. We expect to adopt this guidance in the first quarter 2017, and we are evaluating the impact on us.

In February 2016, the FASB issued ASU 2016-02, “Leases (Topic 842),” which requires the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases under previous GAAP. It also requires qualitative disclosures along with specific quantitative disclosures by lessees and lessors to meet the objective of enabling users of financial statements to assess the amount, timing and uncertainty of cash flows arising from leases. This guidance is effective for public companies for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early adoption is permitted. We expect to adopt this guidance in the first quarter 2019, and we are evaluating the impact on us.

In January 2016, the FASB issued ASU 2016-01, “Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities,” which requires all equity investments other than those accounted for using the equity method of accounting or those that result in consolidation of the investee to be measured at fair value with changes in fair value recognized in net income, eliminates the available-for-sale classification for equity securities with readily determinable fair values and eliminates the cost method for equity investments without readily determinable fair values. Additionally, this guidance eliminates the requirement to disclose the methods and significant assumptions used to estimate the fair value of financial instruments carried at amortized cost and requires the use of the exit price when measuring the fair value of such instruments for disclosure purposes. This guidance will be effective for public companies in fiscal years beginning after December 15, 2017, including interim periods within those fiscal years. Early adoption is only permitted for certain portions of the ASU. We expect to adopt this guidance in the first quarter 2018, and we are evaluating the impact on us.

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In July 2015, the FASB issued ASU 2015-11, “Inventory (Topic 330): Simplifying the Measurement of Inventory,” which requires that inventory, excluding inventory measured using last-in, first-out (LIFO) or the retail inventory method, be measured at the lower of cost or net realizable value. This guidance will be effective for public companies for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. We expect to adopt this guidance in the first quarter 2017, and we are evaluating the impact on us.

In August 2014, the FASB issued ASU 2014-15, “Presentation of Financial Statements - Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a 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 (Topic 606),” 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. The FASB has issued additional ASUs, which provide further guidance and clarification on implementation issues. We expect to adopt this guidance beginning in the first quarter 2018, and we are evaluating the impact on us.

B. 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 our 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 derivatives by discounting the projected future cash flows from the derivative assets and liabilities to present value using interest-rate yields to calculate present-value discount factors derived from LIBOR, Eurodollar futures and the LIBOR interest-rate swaps market. 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 executed derivative contracts , the ultimate market prices realized could differ from our estimates, and the differences could be material.

The fair value of 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-rate swap settlements.

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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 internally developed 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 the periods indicated:

	June 30, 2016
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Derivative assets
Commodity contracts
Financial contracts	$	13,966		$	—		$	3,205		$	17,171		$	(10,970	)	$	6,201
Physical contracts	—			—			68			68			—			68
Total derivative assets	$	13,966		$	—		$	3,273		$	17,239		$	(10,970	)	$	6,269
Derivative liabilities
Commodity contracts
Financial contracts	$	(15,352	)	$	—		$	(12,365	)	$	(27,717	)	$	27,717		$	—
Physical contracts	—			—			(4,929		)	(4,929		)	—			(4,929		)
Interest-rate contracts	—			(70,111		)	—			(70,111		)	—			(70,111		)
Total derivative liabilities	$	(15,352	)	$	(70,111	)	$	(17,294	)	$	(102,757	)	$	27,717		$	(75,040	)

(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 us. At June 30, 2016, we had no cash held and posted $33.5 million of cash with various counterparties, including $16.7 million of cash collateral that is offsetting derivative net liability positions under master-netting arrangements in the table above. The remaining $16.8 million of cash collateral in excess of derivative net liability positions is included in other current assets in our Consolidated Balance Sheets.

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

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	December 31, 2015
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Derivative assets
Commodity contracts
Financial contracts	$	38,921		$	—		$	7,253		$	46,174		$	(42,414	)	$	3,760
Physical contracts	—			—			3,591			3,591			—			3,591
Total derivative assets	$	38,921		$	—		$	10,844		$	49,765		$	(42,414	)	$	7,351
Derivative liabilities
Commodity contracts
Financial contracts	$	(4,513	)	$	—		$	(3,513	)	$	(8,026	)	$	8,026		$	—
Interest-rate contracts	—			(9,936		)	—			(9,936		)	—			(9,936		)
Total derivative liabilities	$	(4,513	)	$	(9,936	)	$	(3,513	)	$	(17,962	)	$	8,026		$	(9,936	)

(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 us. At December 31, 2015, we held $34.4 million of cash from various counterparties that is offsetting derivative net asset positions in the table above under master-netting arrangements and had no cash collateral posted.

(b) - Included in other current 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 the periods indicated:

	Three Months Ended						Six Months Ended
	June 30,						June 30,
Derivative Assets (Liabilities)	2016			2015			2016			2015
	(Thousands of dollars)
Net assets at beginning of period	$	34		$	7,040		$	7,331		$	9,285
Total realized/unrealized gains (losses):
Included in earnings (a)	318			(159		)	(427		)	110
Included in other comprehensive income (loss)	(14,373		)	3,506			(20,925		)	992
Net assets (liabilities) at end of period	$	(14,021	)	$	10,387		$	(14,021	)	$	10,387

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

Realized/unrealized gains (losses) include the realization of derivative contracts through maturity. During the three and six months ended June 30, 2016 and 2015, 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 six months ended June 30, 2016 and 2015, there were no transfers between levels.

Other Financial Instruments -The approximate fair value of cash and cash equivalents, accounts receivable, accounts payable and short-term borrowings 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 short-term borrowings are classified as Level 2 since the estimated fair value of the short-term borrowings 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 $9.0 billion and $7.4 billion at June 30, 2016, and December 31, 2015, respectively. The book value of our consolidated long-term debt, including current maturities, was $8.8 billion and $8.4 billion at June 30, 2016, and December 31, 2015, 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.

C. RISK-MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

Risk-Management Activities - We are 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. We use physical-forward purchases and

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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 commodity price and interest-rate fluctuations; and to achieve more predictable cash flows. We follow established policies and procedures to assess risk and approve, monitor and report risk-management activities. We have not used these instruments for trading purposes. We 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. We use 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;

• 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; and

• Options - 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.

We may also use other instruments including collars to mitigate commodity price risk. 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 as a portion of its compensation for services associated with its POP with fee contracts. Under certain POP with fee contracts, ONEOK Partners’ fee revenues may increase or decrease if production volumes, delivery pressures or commodity prices change relative to specified thresholds. The Natural Gas Gathering and Processing segment also is exposed to basis risk between the various production and market locations where it receives and sells commodities. As part of our hedging strategy, we use 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. The Natural Gas Liquids segment also is 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. We utilize 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, our 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, we use physical-forward sales or purchases to reduce the impact of price fluctuations related to natural gas. At June 30, 2016, and December 31, 2015, there were no financial derivative instruments with respect to ONEOK Partners’ natural gas pipeline operations.

Interest-rate risk - We 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. As of June 30, 2016, ONEOK Partners had interest-rate swaps with notional amounts totaling $1.0 billion to hedge the variability of ONEOK Partners’ LIBOR-based interest payments. In June 2016, ONEOK Partners entered into forward-starting interest-rate swaps with notional amounts totaling $750 million to hedge the variability of interest payments on a portion of its forecasted debt issuances that may result from changes in the benchmark interest rate before the debt is issued. At June 30, 2016, and December 31, 2015, ONEOK Partners had forward-starting interest-rate swaps with notional amounts totaling $1.2 billion and $400 million, respectively, to hedge the variability of interest payments on a portion of its forecasted debt issuances. All of ONEOK Partners’ interest-rate swaps are designated as cash flow hedges.

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Accounting Treatment -All derivative instruments are recorded 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 our exposure to fluctuations in natural gas, NGLs and condensate prices, we periodically enter 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, these derivative instruments are designated as a hedge of exposure to changes in fair values or cash flows. All relationships between hedging instruments and hedged items are formally documented, as well as risk-management objectives and strategies for undertaking various hedge transactions, and methods for assessing and testing correlation and hedge ineffectiveness. The forecasted transaction that has been designated as the hedged item in a cash flow hedge relationship is specifically identified. The effectiveness of hedging relationships are assessed quarterly by performing an effectiveness analysis on the fair value and cash flow hedging relationships to determine whether the hedge relationships are highly effective on a retrospective and prospective basis. Normal purchases and normal sales transactions that are expected to result in physical delivery and, through election, are exempt from derivative accounting treatment are also documented.

The realized revenues and purchase costs of 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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Fair Values of Derivative Instruments - See Note B for a discussion of the inputs associated with our fair value measurements. The following table sets forth the fair values of derivative instruments for the periods indicated:

	June 30, 2016					December 31, 2015
	Assets (a)		(Liabilities) (a)			Assets (b)		(Liabilities) (b)
	(Thousands of dollars)
Derivatives designated as hedging instruments
Commodity contracts
Financial contracts	$	14,591	$	(25,028	)	$	39,255	$	(1,440	)
Physical contracts	68		(4,929		)	3,591		—
Interest-rate contracts	—		(70,111		)	—		(9,936		)
Total derivatives designated as hedging instruments	14,659		(100,068		)	42,846		(11,376		)
Derivatives not designated as hedging instruments
Commodity contracts
Financial contracts	2,580		(2,689		)	6,919		(6,586		)
Total derivatives not designated as hedging instruments	2,580		(2,689		)	6,919		(6,586		)
Total derivatives	$	17,239	$	(102,757	)	$	49,765	$	(17,962	)

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

(b) - Included on a net basis in other current 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 held for the periods indicated:

		June 30, 2016					December 31, 2015
	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	—		(41.2		)	—		(27.1		)
- Natural gas (Bcf)	Put options	89.7		—			—		—
- Crude oil and NGLs (MMBbl)	Futures, forwards and swaps	—		(5.5		)	—		(2.3		)
- Propane (MMBbl)	Put options	1.5		—			—		—
Basis
- Natural gas (Bcf)	Futures and swaps	—		(41.2		)	—		(27.1		)
Interest-rate contracts (Millions of dollars)	Swaps	$	2,150.0	$	—		$	400.0	$	—
Derivatives not designated as hedging instruments:
Fixed price
- NGLs (MMBbl)	Futures, forwards and swaps	0.8		(1.0		)	0.6		(0.6		)

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 actual exposure to market or credit risk.

Cash Flow Hedges - At June 30, 2016, our Consolidated Balance Sheet reflected a net loss of $159.2 million in accumulated other comprehensive loss. The portion of accumulated other comprehensive loss attributable to commodity derivative financial instruments is an unrealized loss of $8.8 million, net of tax, which will be realized within the next 18 months as the forecasted transactions affect earnings. If commodity prices remain at current levels, we will realize approximately $5.8 million in net losses over the next 12 months and approximately $3.0 million in net losses thereafter. The amount deferred in accumulated other comprehensive loss attributable to settled interest-rate swaps is a loss of $47.0 million, net of tax, which will be recognized over the life of the long-term, fixed-rate debt, including losses of $6.3 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 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 the debt.

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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					Six Months Ended
	June 30,					June 30,
	2016			2015		2016			2015
	(Thousands of dollars)
Commodity contracts	$	(58,654	)	$	1,072	$	(46,976	)	$	11,091
Interest-rate contracts	(28,564		)	16,909		(60,175		)	(5,667		)
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	$	(87,218	)	$	17,981	$	(107,151	)	$	5,424

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 Loss into Net Income (Effective Portion)	Three Months Ended						Six Months Ended
		June 30,						June 30,
		2016			2015			2016			2015
		(Thousands of dollars)
Commodity contracts	Commodity sales revenues	$	14,049		$	17,078		$	28,548		$	31,250
Interest-rate contracts	Interest expense	(4,802		)	(4,598		)	(9,500		)	(8,315		)
Total gain (loss) reclassified from accumulated other comprehensive loss into net income on derivatives (effective portion)		$	9,247		$	12,480		$	19,048		$	22,935

Ineffectiveness related to our cash flow hedges for the three and six months ended June 30, 2016 and 2015, was not material. 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 six months ended June 30, 2016 and 2015, there were no gains or losses due to the discontinuance of cash flow hedge treatment.

Credit Risk - We monitor the creditworthiness of our counterparties and compliance with policies and limits established by our Risk Oversight and Strategy Committee. We maintain credit policies with regard to our 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. We have counterparties whose credit is not rated, and for those customers, we use internally developed credit ratings.

From time to time, ONEOK Partners may enter into financial derivative instruments that 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 at June 30, 2016.

The counterparties to our derivative contracts consist primarily of major energy companies, financial institutions and commercial and industrial end users. This concentration of counterparties may affect our 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 our 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 June 30, 2016, the net credit exposure from our derivative assets is primarily with investment-grade companies in the financial services sector.

D. SHORT-TERM BORROWINGS

ONEOK Credit Agreement - In January 2016, we extended the term of the ONEOK Credit Agreement by one year to January 2020. 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

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the ONEOK Credit Agreement, amounts outstanding under the ONEOK Credit Agreement, if any, may become due and payable immediately. At June 30, 2016, ONEOK’s ratio of indebtedness to Consolidated EBITDA was 2.2 to 1, and ONEOK was in compliance with all covenants under the ONEOK Credit Agreement.

The ONEOK Credit Agreement 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 interest at LIBOR plus 145 basis points, and the annual facility fee is 30 basis points.

At June 30, 2016, ONEOK had $1.1 million in letters of credit issued and no borrowings under the ONEOK Credit Agreement.

ONEOK Partners Credit Agreement - In January 2016, ONEOK Partners extended the term of the ONEOK Partners Credit Agreement by one year to January 2020. The ONEOK Partners Credit Agreement 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.

ONEOK Partners had $14 million of letters of credit issued, no borrowings outstanding and approximately $1.8 billion capacity available at June 30, 2016, 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. 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 June 30, 2016, ONEOK Partners’ ratio of indebtedness to adjusted EBITDA was 4.2 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.

ONEOK Partners Commercial Paper Program -At June 30, 2016, ONEOK Partners had $576 million of commercial paper outstanding under its $2.4 billion commercial paper program with weighted-average interest rates of 1.17 percent. Amounts outstanding under ONEOK Partners’ commercial paper program reduce the borrowing capacity under the ONEOK Partners Credit Agreement.

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E. LONG-TERM DEBT

The following table sets forth our long-term debt for the periods indicated:

	June 30,			December 31,
	2016			2015
	(Thousands of dollars)
ONEOK
$700,000 at 4.25% due 2022	$	547,397		$	547,397
$500,000 at 7.5% due 2023	500,000			500,000
$100,000 at 6.5% due 2028	87,190			87,516
$100,000 at 6.875% due 2028	100,000			100,000
$400,000 at 6.0% due 2035	400,000			400,000
Total ONEOK senior notes payable	1,634,587			1,634,913
ONEOK Partners
$650,000 at 3.25% due 2016	—			650,000
$450,000 at 6.15% due 2016	450,000			450,000
$400,000 at 2.0% due 2017	400,000			400,000
$425,000 at 3.2% due 2018	425,000			425,000
$1,000,000 term loan, variable rate, due 2019	1,000,000			—
$500,000 at 8.625% due 2019	500,000			500,000
$300,000 at 3.8% due 2020	300,000			300,000
$900,000 at 3.375% due 2022	900,000			900,000
$425,000 at 5.0% due 2023	425,000			425,000
$500,000 at 4.9% due 2025	500,000			500,000
$600,000 at 6.65% due 2036	600,000			600,000
$600,000 at 6.85% due 2037	600,000			600,000
$650,000 at 6.125% due 2041	650,000			650,000
$400,000 at 6.2% due 2043	400,000			400,000
Guardian Pipeline
Average 7.85% due 2022	48,082			51,907
Total ONEOK Partners long-term debt	7,198,082			6,851,907
Total long-term debt	8,832,669			8,486,820
Unamortized portion of terminated swaps	21,045			21,904
Unamortized debt issuance costs and discounts	(72,787		)	(74,492		)
Current maturities	(460,650		)	(110,650		)
Long-term debt, excluding current maturities	$	8,320,277		$	8,323,582

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.

ONEOK Partners Debt Issuances and Maturities - In January 2016, ONEOK Partners entered into the $1.0 billion senior unsecured delayed-draw Term Loan Agreement with a syndicate of banks. The Term Loan Agreement matures in January 2019 and bears interest at LIBOR plus a margin that is based on the credit ratings assigned to ONEOK Partners’ senior, unsecured, long-term indebtedness. Based on ONEOK Partners’ current applicable credit rating, borrowings on the Term Loan Agreement accrue at LIBOR plus 130 basis points. At June 30, 2016 the interest rate was 1.74 percent. The Term Loan Agreement contains an option, which may be exercised up to two times, to extend the term of the loan, in each case, for an additional one-year term, subject to approval of the banks. The Term Loan Agreement allows prepayment of all or any portion outstanding without penalty or premium and contains substantially the same covenants as the ONEOK Partners Credit Agreement. During the first quarter 2016, ONEOK Partners drew the full $1.0 billion available under the agreement and used the proceeds to repay its $650 million, 3.25 percent senior notes, to repay amounts outstanding under its commercial paper program and for general partnership purposes. At June 30, 2016, ONEOK Partners’ $450 million, 6.15 percent senior notes due October 1, 2016, are reflected in current maturities of long-term debt in our Consolidated Balance Sheet.

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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.

F. EQUITY

Dividends -Dividends paid on our common stock to shareholders of record at the close of business on February 1, 2016, and May 2, 2016, were $0.615 per share in each instance. A dividend of $0.615 per share was declared for shareholders of record at the close of business on August 8, 2016, payable August 14, 2016.

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

G. ACCUMULATED OTHER COMPREHENSIVE LOSS

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

	Unrealized Gains (Losses) on Risk- Management Assets/Liabilities (a)			Pension and Postretirement Benefit Plan Obligations (a) (b)			Unrealized Gains (Losses) on Risk- Management Assets/Liabilities of Unconsolidated Affiliates (a)			Accumulated Other Comprehensive Loss (a)
	(Thousands of dollars)
January 1, 2016	$	(42,199	)	$	(84,543	)	$	(500	)	$	(127,242	)
Other comprehensive income (loss) before reclassifications	(27,813		)	6			(2,950		)	(30,757		)
Amounts reclassified from accumulated other comprehensive loss	(4,346		)	3,099			—			(1,247		)
Net current period other comprehensive income (loss) attributable to ONEOK	(32,159		)	3,105			(2,950		)	(32,004		)
June 30, 2016	$	(74,358	)	$	(81,438	)	$	(3,450	)	$	(159,246	)

(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 loss in our Consolidated Statements of Income for the periods indicated:

Details about Accumulated Other Comprehensive Loss Components	Three Months Ended						Six Months Ended						Affected Line Item in the Consolidated Statements of Income
	June 30,						June 30,
	2016			2015			2016			2015
	(Thousands of dollars)
Unrealized gains (losses) on risk-management assets/liabilities
Commodity contracts	$	14,049		$	17,078		$	28,548		$	31,250		Commodity sales revenues
Interest-rate contracts	(4,802		)	(4,598		)	(9,500		)	(8,315		)	Interest expense
	9,247			12,480			19,048			22,935			Income before income taxes
	(1,193		)	(1,439		)	(2,469		)	(2,664		)	Income tax expense
	8,054			11,041			16,579			20,271			Net income
Noncontrolling interests	5,953			8,523			12,233			15,595			Less: Net income attributable to noncontrolling interests
	$	2,101		$	2,518		$	4,346		$	4,676		Net income attributable to ONEOK
Pension and postretirement benefit plan obligations (a)
Amortization of net loss	$	(2,997	)	$	(4,423	)	$	(5,995	)	$	(8,846	)
Amortization of unrecognized prior service cost	415			392			830			784
	(2,582		)	(4,031		)	(5,165		)	(8,062		)	Income before income taxes
	1,033			1,613			2,066			3,225			Income tax expense
	$	(1,549	)	$	(2,418	)	$	(3,099	)	$	(4,837	)	Net income attributable to ONEOK
Total reclassifications for the period attributable to ONEOK	$	552		$	100		$	1,247		$	(161	)	Net income attributable to ONEOK

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

H. 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 June 30, 2016
	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	$	86,171	211,075	$	0.41
Diluted EPS from continuing operations
Effect of dilutive securities	—		1,543
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	86,171	212,618	$	0.41

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	Three Months Ended June 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	$	76,645	210,204	$	0.36
Diluted EPS from continuing operations
Effect of dilutive securities	—		273
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	76,645	210,477	$	0.36

	Six Months Ended June 30, 2016
	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	$	170,569	210,928	$	0.81
Diluted EPS from continuing operations
Effect of dilutive securities	—		735
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	170,569	211,663	$	0.81

	Six Months Ended June 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	$	137,589	210,059	$	0.65
Diluted EPS from continuing operations
Effect of dilutive securities	—		427
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	137,589	210,486	$	0.65

I. 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						Six Months Ended
	June 30,						June 30,
	2016			2015			2016			2015
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	1,622		$	1,887		$	3,244		$	3,774
Interest cost	4,947			4,546			9,894			9,092
Expected return on assets	(5,077		)	(5,213		)	(10,154		)	(10,426		)
Amortization of unrecognized prior service cost	—			23			—			46
Amortization of net loss	2,736			3,987			5,473			7,974
Net periodic benefit cost	$	4,228		$	5,230		$	8,457		$	10,460

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	Postretirement Benefits
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2016			2015			2016			2015
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	149		$	186		$	298		$	372
Interest cost	601			587			1,202			1,173
Expected return on assets	(531		)	(564		)	(1,062		)	(1,128		)
Amortization of unrecognized prior service cost	(415		)	(415		)	(830		)	(830		)
Amortization of net loss	261			436			522			872
Net periodic benefit cost	$	65		$	230		$	130		$	459

J. 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				Six Months Ended
	June 30,				June 30,
	2016		2015		2016		2015
	(Thousands of dollars)
Northern Border Pipeline	$	15,723	$	15,273	$	34,397	$	34,975
Overland Pass Pipeline Company	13,608		9,623		26,912		16,510
Other	3,041		5,144		3,977		9,476
Equity in net earnings from investments	$	32,372	$	30,040	$	65,286	$	60,961

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				Six Months Ended
	June 30,				June 30,
	2016		2015		2016		2015
	(Thousands of dollars)
Income Statement
Operating revenues	$	142,631	$	125,738	$	279,203	$	255,319
Operating expenses	$	66,674	$	55,959	$	125,373	$	113,538
Net income	$	69,420	$	62,643	$	141,457	$	129,002
Distributions paid to ONEOK Partners	$	62,024	$	41,354	$	108,577	$	80,783

ONEOK Partners incurred expenses in transactions with unconsolidated affiliates of $34.7 million and $25.9 million for the three months ended June 30, 2016 and 2015, respectively, and $68.3 million and $45.8 million for the six months ended June 30, 2016 and 2015, respectively, primarily related to Overland Pass Pipeline Company and Northern Border Pipeline. Accounts payable to ONEOK Partners’ equity-method investees at June 30, 2016, and December 31, 2015, were $12.2 million and $8.0 million, respectively.

Northern Border Pipeline -The Northern Border Pipeline partnership agreement provides that distributions to Northern Border Pipeline’s partners are to be made on a pro rata basis according to each partner’s percentage interest. The Northern Border Pipeline Management Committee determines the amount and timing of such distributions. Any changes to, or suspension of, the cash distribution policy of Northern Border Pipeline requires the unanimous approval of the Northern Border Pipeline Management Committee. Cash distributions are equal to 100 percent of distributable cash flow as determined from Northern Border Pipeline’s financial statements based upon EBITDA, less interest expense and maintenance capital expenditures. Loans or other advances from Northern Border Pipeline to its partners or affiliates are prohibited under its credit agreement.

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Overland Pass Pipeline Company - The Overland Pass Pipeline Company limited liability company agreement provides that distributions to Overland Pass Pipeline Company’s members are to be made on a pro rata basis according to each member’s percentage interest. The Overland Pass Pipeline Company Management Committee determines the amount and timing of such distributions. Any changes to, or suspension of, the cash distributions from Overland Pass Pipeline Company requires the unanimous approval of the Overland Pass Pipeline Company Management Committee. Cash distributions are equal to 100 percent of available cash as defined in the limited liability company agreement.

Roadrunner Gas Transmission - In March 2015, ONEOK Partners entered into a 50-50 joint venture 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 six months ended June 30, 2016, ONEOK Partners made contributions of approximately $20 million to Roadrunner, and expects to contribute approximately $45 million to Roadrunner during the remainder of 2016.

The Roadrunner limited liability company agreement provides that distributions to members are made on a pro rata basis according to each member’s ownership interest. The Roadrunner Management Committee determines the amount and timing of such distributions. Any changes to, or suspension of, the cash distributions from Roadrunner requires approval of the Roadrunner Management Committee. Voting rights for the Roadrunner Management Committee are allocated on a pro rata basis according to each member’s ownership interest. Cash distributions are equal to 100 percent of available cash, as defined in the limited liability company agreement.

K. ONEOK PARTNERS

Ownership Interestin ONEOK Partners - Our ownership interest in ONEOK Partners is shown in the table below at June 30, 2016:

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.

Consolidation - We determined ONEOK Partners is a VIE due to the limited partners’ lack of substantive voting rights under the Partnership Agreement. Substantive voting rights under a master limited partnership are either kick-out rights or participating rights, as defined by FASB Accounting Standards Codification 810-10, that can be exercised with a simple majority of the vote of the limited partners. Prior to the adoption of ASU 2015-02, ONEOK Partners was not considered a VIE and was consolidated by us under the presumption that a general partner consolidates its limited partnership. See Note A for more information on ASU 2015-02.

We have determined that we are the primary beneficiary of ONEOK Partners as we have the power, through our general partner interest, to direct the operations of ONEOK Partners that impact its economic performance and the right to receive the benefits of ONEOK Partners through our general partner and limited partner interests. These interests are significant due to our 41.2 percent ownership interest in ONEOK Partners, the largest ownership interest by an individual entity, and our incentive distribution rights.

As we are the primary beneficiary of ONEOK Partners, 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 from ONEOK Partners. Distributions are declared quarterly by the board of ONEOK Partners’ general partner based on the terms of the Partnership Agreement. See Note N for more information on ONEOK Partners’ results.

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The following table shows the carrying amount and classification of ONEOK Partners’ assets and liabilities in our Consolidated Balance Sheets:

	June 30,		December 31,
	2016		2015
	(Thousands of dollars)
Assets
Total current assets	$	1,096,107	$	883,164
Net property, plant and equipment	12,372,176		12,256,791
Total investments and other assets	1,749,593		1,787,631
Total assets	$	15,217,876	$	14,927,586
Liabilities
Total current liabilities	$	2,140,793	$	1,580,300
Long-term debt, excluding current maturities	6,691,950		6,695,312
Total deferred credits and other liabilities	183,200		154,631
Total liabilities	$	9,015,943	$	8,430,243

ONEOK receives distributions from ONEOK Partners through its general partner and limited partner interests, but otherwise the assets of ONEOK Partners cannot be used to settle obligations of ONEOK. ONEOK does not guarantee the debt, commercial paper or other similar commitments of ONEOK Partners, and the obligations of ONEOK Partners may only be settled using the assets of ONEOK Partners. ONEOK Partners does not guarantee the debt or other similar commitments of ONEOK.

Equity Issuances -In August 2015, ONEOK Partners completed the sale to us in a private placement of 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 proceeds of approximately $749 million. 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.

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 June 30, 2016, ONEOK Partners had approximately $138 million of registered common units available for issuance through its “at-the-market” equity program.

During the three and six months ended June 30, 2016, no common units were sold through ONEOK Partners’ “at-the-market” equity program.

During the three months ended June 30, 2015, ONEOK Partners sold 5.5 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 $208.1 million, which were used for general partnership purposes, including repayment of commercial paper borrowings.

During the six months ended June 30, 2015, ONEOK Partners sold 7.2 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 $279.7 million, which were used for general partnership purposes, including repayment of commercial paper borrowings.

During the year ended December 31, 2015, ONEOK Partners sold 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 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.

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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.

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 July 2016, a cash distribution of $0.79 per unit ($3.16 per unit on an annualized basis) was declared for the second quarter 2016 and will be paid on August 14, 2016, to unitholders of record at the close of business on August 8, 2016.

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2016		2015		2016		2015
	(Thousands, except per unit amounts)
Distribution per unit	$	0.79	$	0.79	$	1.58	$	1.58
General partner distributions	$	6,660	$	5,955	$	13,320	$	11,869
Incentive distributions	100,538		89,889		201,076		179,168
Distributions to general partner	107,198		95,844		214,396		191,037
Limited partner distributions to ONEOK	90,323		73,302		180,646		146,604
Limited partner distributions to noncontrolling interest	135,479		128,583		270,959		255,794
Total distributions paid	$	333,000	$	297,729	$	666,001	$	593,435

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2016		2015		2016		2015
	(Thousands, except per unit amounts)
Distribution per unit	$	0.79	$	0.79	$	1.58	$	1.58
General partner distributions	$	6,660	$	6,081	$	13,320	$	12,036
Incentive distributions	100,538		91,794		201,076		181,683
Distributions to general partner	107,198		97,875		214,396		193,719
Limited partner distributions to ONEOK	90,323		73,302		180,646		146,604
Limited partner distributions to noncontrolling interest	135,479		132,862		270,959		261,445
Total distributions declared	$	333,000	$	304,039	$	666,001	$	601,768

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. For the three months ended June 30, 2016 and 2015, $100.8 million and $86.7 million, respectively, of ONEOK Partners’ operating expenses were incurred with us. For the

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six months ended June 30, 2016 and 2015, $189.9 million and $176.3 million, respectively, of ONEOK Partners’ operating expenses were incurred with us.

ONEOK Partners has an operating agreement with Roadrunner, that provides for reimbursement or payment to it for management services and certain operating costs. Charges to Roadrunner included in operating income in our Consolidated Statements of Income for the three and six months ended June 30, 2016 and 2015, were not material.

L. COMMITMENTS AND CONTINGENCIES

Environmental Matters and Pipeline Safety - The operation of pipelines, plants and other facilities for the gathering, processing, transportation and storage of natural gas, NGLs, condensate and other products is subject to numerous and complex laws and regulations pertaining to health, safety and the environment. As an owner and/or operator of these facilities, ONEOK Partners must comply with United States laws and regulations at the federal, state and local levels that relate to air and water quality, hazardous and solid waste management and disposal, and other environmental matters. The cost of planning, designing, constructing and operating pipelines, plants and other facilities must incorporate compliance with environmental laws and regulations and safety standards. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and potentially criminal enforcement measures, including citizen suits, which can include the assessment of monetary penalties, the imposition of remedial requirements and the issuance of injunctions or restrictions on operation. Management believes that, based on currently known information, compliance with these laws and regulations will not have a material adverse effect on our or ONEOK Partners’ results of operations, financial condition or cash flows.

Legal Proceedings -Gas Index Pricing Litigation - In May 2016, the United States District Court for the District of Nevada (“the Court”) entered an order granting summary judgment in favor of us and our affiliate ONEOK Energy Services Company, L.P. (“OESC”) in Reorganized FLI, Inc. previously reported in our Annual Report. The Court determined that the plaintiff’s claim is barred by a release obtained in a prior lawsuit against us and OESC. Upon entry of a final judgment,Reorganized FLI, Inc. may pursue an appeal of this determination to the Ninth Circuit Court of Appeals.

In March 2016, we reached an agreement in principle to settle the claims alleged against us and our affiliates, OESC and Kansas Gas Marketing Company, in the following putative class action lawsuits, previously reported in our Annual Report, that claimed damages resulting from alleged market manipulation or false reporting of prices to gas index publications by us and others: Learjet, Arandell, HeartlandRegional Medical Center, and NewPage. The amount we expect to pay to settle these cases is not material to our results of operations, financial position or cash flows and is expected to be paid with cash on hand.

This agreement in principle to settle does not apply to the Sinclair case, previously reported in our Annual Report. We expect that future charges, if any, from the ultimate resolution of these matters will not be material to our results of operations, financial position or cash flows.

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.

M. DISCONTINUED OPERATIONS

In 2014, we completed the wind down of our former energy services business. We executed agreements to release a significant portion of our nonaffiliated natural gas transportation and storage contracts to third parties that resulted in noncash charges.

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

	Six Months Ended
	June 30,
	2016			2015
	(Millions of dollars)
Beginning balance	$	36.3		$	73.8
Settlements	(11.6		)	(22.4		)
Accretion	0.3			0.6
Ending balance	$	25.0		$	52.0

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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 $25 million, which consists of approximately $7 million to be paid in the remainder of 2016, $10 million in 2017, $4 million in 2018 and $4 million over the period 2019 through 2023.

Results of Operations of Discontinued Operations - The results of operations for our former 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 six months ended June 30, 2016 and 2015, includes accretion expense, net of tax benefit, on the released contracts for our former energy services business.

Statement of Financial Position of Discontinued Operations - At June 30, 2016, and December 31, 2015, 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.

N. 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 -The accounting policies of the segments are described in Note A of the Notes to Consolidated Financial Statements in our Annual Report. Our chief operating decision maker reviews the financial performance of each of the three segments of ONEOK Partners, as well as our financial performance, on a regular basis. Beginning in 2016, adjusted EBITDA by segment, a non-GAAP financial measure, is utilized in this evaluation. We believe this non-GAAP financial measure is useful to investors because it is used by many companies in our industry as a measurement of financial performance and is commonly employed by financial analysts and others to evaluate our financial performance and to compare our financial performance with the performance of other publicly traded partnerships within our industry. Adjusted EBITDA is defined as net income adjusted for interest expense, depreciation and amortization, noncash impairment charges, income taxes and AFUDC and other noncash items. Adjusted EBITDA should not be considered an alternative to net income, earnings per unit or any other measure of financial performance presented in accordance with GAAP. Additionally, this calculation may not be comparable with similarly titled measures of other companies. Prior period segment disclosures have been recast to reflect this change.

Customers -The primary customers of the Natural Gas Gathering and Processing segment are crude oil and natural gas producers, which include both large integrated and independent exploration and production companies. The Natural Gas Liquids segment’s customers are primarily NGL and natural gas gathering and processing companies; large integrated 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 are primarily local natural gas distribution companies, electric-generation companies, large industrial companies, municipalities, irrigation customers and marketing companies.

For the three months ended June 30, 2016, ONEOK Partners had no single customer from which it received 10 percent or more of our consolidated revenues. For the three months ended June 30, 2015, and the six months ended June 30, 2016, and June 30, 2015, ONEOK Partners had one customer, BP p.l.c. or its affiliates, from which it received $224.6 million, $396.5 million and $409.5 million, respectively, in total revenues from all of its operating segments, or approximately 11 percent, 10 percent and 10 percent of our consolidated revenues, respectively.

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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 June 30, 2016	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)		Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	293,071		$	1,754,122		$	86,401	$	513		$	2,134,107
Intersegment revenues	183,688			117,871			1,668		(303,227		)	—
Total revenues	476,759			1,871,993			88,069		(302,714		)	2,134,107
Cost of sales and fuel (exclusive of items shown separately below)	299,991			1,525,234			5,112		(303,014		)	1,527,323
Operating costs	69,304			83,769			29,189		9,577			191,839
Depreciation and amortization	46,413			40,696			11,398		740			99,247
(Gain) loss on sale of assets	(240		)	(71		)	725		(1		)	413
Operating income	$	61,291		$	222,365		$	41,645	$	(10,016	)	$	315,285
Equity in net earnings from investments	$	2,576		$	13,904		$	15,892	$	—		$	32,372
Capital expenditures	$	84,674		$	20,779		$	29,278	$	2,112		$	136,843

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $297.5 million, of which $258.4 million related to sales within the segment, cost of sales and fuel of $112.7 million and operating income of $120.8 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $56.6 million, cost of sales and fuel of $5.7 million and operating income of $23.8 million.

Three Months Ended June 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	$	279,498		$	1,769,580	$	78,429	$	545		$	2,128,052
Intersegment revenues	180,564			79,295		1,683		(261,542		)	—
Total revenues	460,062			1,848,875		80,112		(260,997		)	2,128,052
Cost of sales and fuel (exclusive of items shown separately below)	322,927			1,535,492		6,005		(261,331		)	1,603,093
Operating costs	63,550			77,410		25,240		(850		)	165,350
Depreciation and amortization	35,952			39,433		10,814		788			86,987
(Gain) loss on sale of assets	(195		)	73		—		—			(122		)
Operating income	$	37,828		$	196,467	$	38,053	$	396		$	272,744
Equity in net earnings from investments	$	4,922		$	9,693	$	15,425	$	—		$	30,040
Capital expenditures	$	205,434		$	59,087	$	15,613	$	5,467		$	285,601

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $227.5 million, of which $186.4 million related to sales within the segment, cost of sales and fuel of $98.9 million and operating income of $73.6 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $64.1 million, cost of sales and fuel of $7.0 million and operating income of $25.7 million.

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Six Months Ended June 30, 2016	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)			Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	610,117		$	3,125,547		$	171,875		$	1,027		$	3,908,566
Intersegment revenues	298,653			233,836			2,167			(534,656		)	—
Total revenues	908,770			3,359,383			174,042			(533,629		)	3,908,566
Cost of sales and fuel (exclusive of items shown separately below)	566,291			2,682,184			9,044			(534,458		)	2,723,061
Operating costs	138,910			156,951			56,702			16,291			368,854
Depreciation and amortization	88,264			81,402			22,577			1,482			193,725
(Gain) loss on sale of assets	(1,485		)	(7		)	(2,239		)	(62		)	(3,793		)
Operating income	$	116,790		$	438,853		$	87,958		$	(16,882	)	$	626,719
Equity in net earnings from investments	$	5,391		$	27,251		$	32,644		$	—		$	65,286
Investments in unconsolidated affiliates	$	68,854		$	471,415		$	373,544		$	—		$	913,813
Total assets	$	5,222,225		$	8,289,089		$	1,856,128		$	455,458		$	15,822,900
Noncontrolling interests in consolidated subsidiaries	$	—		$	159,049		$	—		$	3,095,699		$	3,254,748
Capital expenditures	$	226,171		$	54,986		$	47,226		$	4,871		$	333,254

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $579.3 million, of which $489.2 million related to sales within the segment, cost of sales and fuel of $219.5 million and operating income of $236.4 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $111.4 million, cost of sales and fuel of $11.3 million and operating income of $46.9 million.

Six Months Ended June 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	$	567,514		$	3,204,393	$	160,359		$	1,092		$	3,933,358
Intersegment revenues	348,171			140,574		3,302			(492,047		)	—
Total revenues	915,685			3,344,967		163,661			(490,955		)	3,933,358
Cost of sales and fuel (exclusive of items shown separately below)	653,858			2,764,357		20,431			(491,689		)	2,946,957
Operating costs	132,760			159,656		52,482			(530		)	344,368
Depreciation and amortization	71,749			78,727		21,570			896			172,942
(Gain) loss on sale of assets	(196		)	81		(1		)	—			(116		)
Operating income	$	57,514		$	342,146	$	69,179		$	368		$	469,207
Equity in net earnings from investments	$	9,161		$	16,673	$	35,127		$	—		$	60,961
Investments in unconsolidated affiliates	$	252,468		$	485,381	$	408,558		$	—		$	1,146,407
Total assets	$	5,007,456		$	8,139,590	$	1,848,779		$	655,355		$	15,651,180
Noncontrolling interests in consolidated subsidiaries	$	4,065		$	162,494	$	—		$	3,315,292		$	3,481,851
Capital expenditures	$	460,735		$	132,553	$	25,205		$	10,955		$	629,448

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $437.3 million, of which $351.7 million related to sales within the segment, cost of sales and fuel of $184.6 million and operating income of $138.5 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $133.4 million, cost of sales and fuel of $15.4 million and operating income of $53.1 million.

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	Three Months Ended						Six Months Ended
	June 30,						June 30,
(Unaudited)	2016			2015			2016			2015
	(Thousands of dollars)
Segment Adjusted EBITDA:
Natural Gas Gathering and Processing	$	110,298		$	78,062		$	210,333		$	138,580
Natural Gas Liquids	276,611			244,591			546,780			437,246
Natural Gas Pipelines	68,542			65,234			142,881			135,946
Other	(2,768		)	(2,228		)	(5,682		)	(5,701		)
Depreciation and amortization	(99,247		)	(86,987		)	(193,725		)	(172,942		)
Interest expense, net of capitalized interest	(118,976		)	(102,384		)	(237,223		)	(199,134		)
Income taxes	(52,458		)	(48,222		)	(102,524		)	(85,650		)
AFUDC and other	(1,916		)	2,954			(4,843		)	(1,488		)
Income from continuing operations	180,086			151,020			355,997			246,857
Income (loss) from discontinued operations, net of tax	(227		)	(140		)	(1,179		)	(284		)
Net income	$	179,859		$	150,880		$	354,818		$	246,573

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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

Please refer to the “Financial Results and Operating Information” and “Liquidity and Capital Resources” sections of Management’s Discussion and Analysis of Financial Condition and Results of Operations in this Quarterly Report for additional information.

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 June 30, 2016, in ONEOK Partners (NYSE: OKS), one of the largest publicly traded master limited partnerships.

ONEOK Partners has a predominantly fee-based business in each of its three reportable segments and expects its consolidated earnings to be approximately 85 percent fee-based in 2016. Despite the lower crude oil, natural gas and NGL price environment and reduced capital spending by producers, we continue to expect demand for midstream nondiscretionary services and infrastructure development to be primarily driven by producers who need to connect production with end-use markets where current infrastructure is insufficient or nonexistent. We expect additional demand for ONEOK Partners’ services to support increased demand for NGL products from ethylene producers and NGL exporters and increased demand for natural gas from power plants previously fueled by coal and natural gas exports to Mexico.

We expect the Natural Gas Liquids segment’s earnings to be approximately 90 percent fee-based in 2016. ONEOK Partners connected seven third-party natural gas processing plants and its Lonesome Creek processing plant to the natural gas liquids system in 2015, three third-party natural gas processing plants in the first half of 2016 and expects to connect two additional third-party natural gas processing plants and its Bear Creek processing plant during the remainder of 2016, favorably impacting the Natural Gas Liquids segment’s fee-based volume growth. In this segment, ONEOK Partners is well-positioned to capture future increases in ethane transportation and fractionation volumes due to increased demand in the petrochemical industry from the completion of the ethylene production projects and NGL export activity without significant additional infrastructure needs or capital spending on ONEOK Partners’ system.

Ethane rejection levels by natural gas processors delivering to ONEOK Partners’ natural gas liquids gathering system decreased to approximately 150 MBbl/d during the second quarter 2016, compared with an average of more than 175 MBbl/d during the second half of 2015 and first quarter 2016, primarily in the Mid-Continent region. While the volume of ethane recovered increased during the second quarter 2016, a portion of the fees associated with those volumes gathered and fractionated was previously being earned under contracts with minimum volume obligations. We expect ethane rejection levels to continue to fluctuate for the remainder of 2016 as the market begins to balance ethane supply and demand and with changes in the price differentials between ethane and natural gas. We expect ethane rejection levels to decrease as ethylene producers and NGL exporters increase their capacity to consume and export additional ethane feedstock volumes. Ethane demand is expected to ramp up as new world-scale ethylene production projects, petrochemical plant modifications, plant expansions and export facilities near completion and begin coming on line in early 2017. We expect future ethane recoveries to have a favorable impact on our financial results.

In 2015, the Natural Gas Gathering and Processing segment restructured many POP with fee contracts associated with a significant amount of its gathered volumes to increase the fee-based component in the contracts. These restructured contracts and increased natural gas gathered and processed volumes favorably impacted results in the first half of 2016, and we expect to continue to receive the benefit of the improved earnings from these contracts and volumes throughout 2016. In the first half of 2016, the Natural Gas Gathering and Processing segment’s fee revenues averaged $0.72 per MMBtu, compared with an average of $0.37 per MMBtu in the first half of 2015. As a result of these restructured contracts, we expect the Natural Gas Gathering and Processing segment’s earnings to be more than 75 percent fee-based in 2016. To mitigate the impact of its remaining commodity price exposure, ONEOK Partners has hedged a significant portion of the Natural Gas Gathering and Processing segment’s commodity price risk for 2016 and 2017.

Although drilling activity continued to slow in the first half of 2016, many of ONEOK Partners’ customers continue to drill and complete new wells in the most productive areas of the Williston Basin. A significant portion of ONEOK Partners’ Williston Basin gathering and processing assets are located in these areas, which typically produce at higher initial production rates compared with other areas and have higher natural gas to oil ratios and have slower natural gas decline rates than crude oil.

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ONEOK Partners’ natural gas volumes gathered and processed and NGL volumes gathered and fractionated increased in the first half of 2016, compared with the first half of 2015, due primarily to the completion of six compressor stations during 2015 and the addition of the 200 MMcf/d Lonesome Creek plant in the fourth quarter 2015, which allowed ONEOK Partners to capture a significant portion of natural gas volumes previously being flared by producers in the Williston Basin. Additionally, we expect to benefit from production from new wells completed in the second half of 2016 and new wells on ONEOK Partners’ dedicated acreage in the Williston Basin that have been drilled previously but have not yet been completed.

We expect the Natural Gas Pipelines segment’s earnings to be approximately 96 percent fee-based in 2016. This segment continues to develop new projects to grow ONEOK Partners’ fee-based earnings, such as ONEOK Partners’ Roadrunner joint venture, which is a pipeline fully subscribed with 25-year firm, fee-based agreements. We expect additional demand for ONEOK Partners’ services to deliver natural gas to power plants previously fueled by coal and to support increased demand for natural gas exports to Mexico. Additionally, the Natural Gas Pipelines segment’s contracts are primarily with large creditworthy companies and include fixed fee or firm demand charge agreements that provide a minimum level of revenues regardless of commodity prices or volumetric throughput.

While commodity prices increased relative to the first quarter 2016, commodity prices in the first half of 2016 were relatively unchanged from year-end 2015 and lower compared with the first half of 2015. WTI crude oil prices averaged approximately $40.00 per barrel in the first half of 2016, compared with prices averaging approximately $50.00 per barrel in the first half of 2015. NYMEX natural gas prices averaged approximately $2.10 per MMBtu in the first half of 2016, compared with prices averaging approximately $2.80 per MMBtu in the first half of 2015. OPIS Conway propane prices averaged $0.40 per gallon in the first half of 2016, compared with prices averaging $0.45 per gallon in the first half of 2015.

We expect the lower commodity price environment to continue throughout 2016, impacting ONEOK Partners’ net realized prices for natural gas, NGLs and condensate, and our financial results. If the low commodity price environment persists for a prolonged period or prices decline further, volumes across ONEOK Partners’ assets may grow more slowly than in the past or decline.

Change in Presentation of Financial Results - Beginning in 2016, we present financial results using adjusted EBITDA by segment, a non-GAAP financial measure. We believe this non-GAAP financial measure is useful to investors because it aids in comparing our financial performance with that of other companies with similar operations and is commonly employed to evaluate our financial performance. We have added adjusted EBITDA to the presentation of consolidated financial results and the financial results of each reporting segment. See additional discussion in the “Adjusted EBITDA” section.

ONEOK Partners’ Growth Projects - Crude oil and natural gas producers continue to drill for crude oil and NGL-rich natural gas in many regions where ONEOK Partners operates, including in the Bakken Shale and Three Forks formations in the Williston Basin; in the Cana-Woodford Shale, Woodford Shale, Springer Shale, STACK and SCOOP areas in the Mid-Continent region; and in the Permian Basin. ONEOK Partners’ current projects are expected to expand its natural gas gathering and processing and natural gas liquids gathering infrastructure in the Williston Basin to capture natural gas from new wells and additional natural gas currently being flared by producers, and to supply ethane produced by its Stateline de-ethanizers to customers exporting to Canada. In the Natural Gas Pipelines segment, through the Roadrunner joint venture, the Roadrunner pipeline transports natural gas from the Permian Basin in West Texas to the Mexican border near El Paso, Texas, and is fully subscribed with 25-year firm, fee-based agreements. Phase I of the Roadrunner pipeline was completed in March 2016. The Roadrunner pipeline connects with ONEOK Partners’ existing natural gas pipeline and storage infrastructure in Texas and, together with the WesTex intrastate natural gas transmission pipeline expansion project, creates a platform for future opportunities to deliver natural gas supply to Mexico. Phase II of the Roadrunner pipeline, which is currently under construction and expected to be complete in the fourth quarter 2016, will provide additional delivery capacity to these markets in Mexico. The execution of these capital investments aligns with ONEOK Partners’ strategy to generate consistent growth and sustainable earnings through long-term fee-based projects. ONEOK Partners’ contractual commitments from crude oil and natural gas producers, natural gas processors and electric generators are expected to provide incremental cash flows and long-term fee-based earnings.

In 2016, ONEOK Partners expects lower capital spending, compared with 2015, due to the completion of projects and spending reductions to align with customer needs. If the current commodity price environment persists for a prolonged period, it may further impact the timing or demand for additional infrastructure projects or growth opportunities in the future.

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

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Dividends/Distributions -We declared a quarterly dividend of $0.615 per share ($2.46 per share on an annualized basis) in July 2016. ONEOK Partners declared a cash distribution of $0.79 per unit ($3.16 per unit on an annualized basis) in July 2016 for the second quarter 2016. The quarterly dividend and distribution will be paid August 14, 2016, to shareholders and unitholders of record at the close of business on August 8, 2016.

ONEOK Partners Debt Issuance - In January 2016, ONEOK Partners entered into the $1.0 billion senior unsecured Term Loan Agreement with a syndicate of banks that matures in January 2019 and drew the full $1.0 billion available in the first quarter 2016. See Note E of the Notes to Consolidated Financial Statements in this Quarterly Report for additional information.

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						Six Months Ended						Three Months					Six Months
	June 30,						June 30,						2016 vs. 2015					2016 vs. 2015
Financial Results	2016			2015			2016			2015			Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
Revenues
Commodity sales	$	1,633.3		$	1,722.3		$	2,916.8		$	3,158.0		$	(89.0	)	(5	%)	$	(241.2	)	(8	%)
Services	500.8			405.8			991.8			775.4			95.0			23	%	216.4			28	%
Total revenues	2,134.1			2,128.1			3,908.6			3,933.4			6.0			—	%	(24.8		)	(1	%)
Cost of sales and fuel (exclusive of depreciation and items shown separately below)	1,527.3			1,603.1			2,723.1			2,947.0			(75.8		)	(5	%)	(223.9		)	(8	%)
Operating costs	191.9			165.4			368.9			344.4			26.5			16	%	24.5			7	%
Depreciation and amortization	99.2			87.0			193.7			172.9			12.2			14	%	20.8			12	%
(Gain) loss on sale of assets	0.4			(0.1		)	(3.8		)	(0.1		)	(0.5		)	*		3.7			*
Operating income	$	315.3		$	272.7		$	626.7		$	469.2		$	42.6		16	%	$	157.5		34	%
Equity in net earnings from investments	$	32.4		$	30.0		$	65.3		$	61.0		$	2.4		8	%	$	4.3		7	%
Interest expense, net of capitalized interest	$	(119.0	)	$	(102.4	)	$	(237.2	)	$	(199.1	)	$	16.6		16	%	$	38.1		19	%
Adjusted EBITDA	$	452.7		$	385.7		$	894.3		$	706.1		$	67.0		17	%	$	188.2		27	%
Capital expenditures	$	136.8		$	285.6		$	333.3		$	629.4		$	(148.8	)	(52	)%	$	(296.1	)	(47	)%

* Percentage change is greater than 100 percent.

See Reconciliation of Adjusted EBITDA to Net Income in the “Adjusted EBITDA” section.

Due to the nature of ONEOK Partners’ contracts, changes in commodity prices and volumes affect both commodity sales and cost of sales and fuel in our Consolidated Statements of Income and therefore the impact is largely offset between the two line items.

Operating income increased for the three and six months ended June 30, 2016, compared with the same periods in 2015, due primarily to higher natural gas gathered and NGL volumes from ONEOK Partners’ completed capital projects in the Natural Gas Gathering and Processing and Natural Gas Liquids segments and new plant connections and decreased ethane rejection in the Natural Gas Liquids segment, and higher fees resulting from contract restructuring in the Natural Gas Gathering and Processing segment. These increases were offset partially by lower net realized NGL and natural gas prices in the Natural Gas Gathering and Processing segment, higher depreciation expense due to projects completed in 2015, higher costs associated with the impact of the non-cash mark-to-market of a share-based deferred compensation plan and higher employee-related costs associated with incentive and medical benefit plans.

Equity in net earnings from investments increased for the three and six months ended June 30, 2016, compared with the same periods in 2015, due primarily to higher volumes delivered to Overland Pass Pipeline from ONEOK Partners’ Bakken NGL Pipeline.

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Interest expense increased for the three months ended June 30, 2016, compared with the same period in 2015, primarily as a result of higher interest costs incurred associated with ONEOK Partners’ borrowing under the Term Loan Agreement during the first quarter 2016, higher short-term borrowing rates and lower capitalized interest due to lower spending on capital-growth projects and higher interest costs incurred associated with our $500 million debt issuance in August 2015. Interest expense increased for the six months ended June 30, 2016, compared with the same period in 2015, primarily as a result of the items discussed above and higher interest costs incurred associated with ONEOK Partners’ issuance of $800 million of senior notes in March 2015.

Adjusted EBITDA increased for the three and six months ended June 30, 2016, compared with the same periods in 2015, due primarily to higher natural gas gathered and NGL volumes from ONEOK Partners’ completed capital-growth projects in the Natural Gas Gathering and Processing and Natural Gas Liquids segments and new plant connections and decreased ethane rejection in the Natural Gas Liquids segment, and higher fees resulting from contract restructuring in the Natural Gas Gathering and Processing segment. These increases were offset partially by lower net realized NGL and natural gas prices in the Natural Gas Gathering and Processing segment.

Capital expenditures decreased for the three and six months ended June 30, 2016, compared with the same periods in 2015, due to projects placed in service in 2015, spending reductions to align with customer needs and lower well connect activities in the Natural Gas Gathering and Processing segment due to a reduction in drilling and completion activity.

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 contracted producers in North Dakota, Montana, Wyoming, Kansas and Oklahoma. It provides exploration and production companies with gathering and processing services that allow them to move their raw (unprocessed) natural gas to market. Raw natural gas is gathered, compressed and transported through pipelines to its processing facilities. In order for the raw natural gas to be accepted by the downstream market, it must have contaminants, such as water, nitrogen and carbon dioxide, removed as well as NGLs separated for further processing. Processed natural gas, usually referred to as residue natural gas, is then recompressed and delivered to natural gas pipelines and end users. The separated NGLs are in a mixed, unfractionated form and are sold and delivered through natural gas liquids pipelines to fractionation facilities for further separation.

This segment gathers and processes natural gas in the Williston Basin, which is located in portions of North Dakota and Montana, including the oil-producing, NGL-rich Bakken Shale and Three Forks formation, and is its most active region with continued volume growth and additional gathering and processing infrastructure needs. The Mid-Continent region is located in Western Oklahoma, which includes the NGL-rich Cana-Woodford Shale, STACK, SCOOP, Woodford Shale, Springer Shale and the Mississippian Lime formation; and Southwest Kansas, which includes the Hugoton Basin, Central Kansas Uplift Basin and the Mississippian Lime formation. The Powder River Basin is primarily located in Wyoming, which includes the NGL-rich Frontier, Turner, Sussex and Niobrara Shales where ONEOK Partners’ Sage Creek system provides gathering and processing services to customers in the southeast portion of Wyoming.

Revenues for this segment are derived primarily from POP contracts with fee-based components and fee-only 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. Over time as these contracts are renewed or restructured, ONEOK Partners has generally increased the fee components and reduced the percent of proceeds retained from the sale of the commodities. As a result, ONEOK Partners’ mix of commodity and fee-based earnings continues to change as volumes naturally decline on older contracts where it retains a higher percent of proceeds and volumes increase on contracts with higher fee components. Additionally, under certain POP with fee contracts the fee revenues may increase or decrease if production volumes, delivery pressures or commodity prices change relative to specified thresholds. With a fee-only contract, ONEOK Partners is paid a fee for the services it provides, based on volumes gathered, processed, treated and/or compressed.

ONEOK Partners has restructured many of its contracts to significantly increase its fees, and as a result of these restructured contracts, we expect the Natural Gas Gathering and Processing segment’s earnings to be more than 75 percent fee-based in 2016. These restructured contracts and increased natural gas gathered and processed volumes favorably impacted ONEOK Partners’ results for the three and six months ended June 30, 2016, and we expect to continue to receive the benefit of improved earnings from these contracts. ONEOK Partners’ NGLs, natural gas and crude oil commodity price sensitivity in this segment has continued to decrease in 2016 as a result of these restructured contracts. Additionally, ONEOK Partners uses commodity

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derivative instruments and physical-forward contracts to reduce its near-term sensitivity to fluctuations in the natural gas, crude oil and NGL commodity prices under POP with fee contracts. ONEOK Partners will continue to seek opportunities to increase its fee-based earnings and reduce its commodity price exposure.

We expect ONEOK Partners’ natural gas gathered and processed volumes in the Williston Basin to grow in 2016, compared with 2015, despite expected reductions in producer drilling activity, due to the following:

• the opportunity to capture additional natural gas currently being flared by producers through natural gas compression and processing capacity placed in service in late 2015 and projects that are expected to be completed in 2016;

• the connection of wells that have been drilled but not yet completed;

• producers focusing their drilling in the most productive areas in which ONEOK Partners has significant gathering and processing assets, which typically produce at higher initial production rates compared with other areas and have higher natural gas to oil ratios and have slower natural gas decline rates than crude oil;

• the use by producers of more efficient drilling rigs; and

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

In the Mid-Continent region, ONEOK Partners’ producer customers continue to focus their drilling and completion activities in the core Cana-Woodford, STACK and SCOOP areas of Oklahoma, and recent wells have shown strong results; however, several large multi-well pads previously scheduled to be completed in late 2015 and early 2016 have been delayed until late 2016 or early 2017. As a result, ONEOK Partners’ 2016 volumes in the Mid-Continent could decline.

Growth Projects - The Natural Gas Gathering and Processing segment is investing in growth projects in NGL-rich areas in the Williston Basin, STACK, SCOOP, Cana-Woodford Shale, Woodford Shale and Springer Shale areas that ONEOK Partners expects will enable it to meet the needs of crude oil and natural gas producers in those areas. Nearly all of the new natural gas production in these areas is from horizontally drilled wells in nonconventional 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 2015, ONEOK Partners completed the following projects:

Completed Projects	Location	Capacity	Approximate Costs (a)	Completion Date
			(In millions)
Rocky Mountain Region
Lonesome Creek processing plant and infrastructure	Williston Basin	200 MMcf/d	$600	November 2015
Sage Creek infrastructure	Powder River Basin	Various	$35	December 2015
Natural gas compression	Williston Basin	100 MMcf/d	$75	December 2015

(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
Stateline de-ethanizers	Williston Basin	26 MBbl/d	$80-$85	Third quarter 2016
Bear Creek processing plant and infrastructure	Williston Basin	80 MMcf/d	$230-$270	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			$1,155-$1,695

(a) - Excludes AFUDC.

As a result of reductions in crude oil and natural gas drilling by producers due to the decline in crude oil, natural gas and NGL prices and the expectation of slower supply growth or declines, in 2015 ONEOK Partners suspended capital expenditures for certain natural gas processing plants and field infrastructure. ONEOK Partners could resume its suspended capital-growth projects when market conditions improve and its customers’ needs change. If the current commodity price environment

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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.

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

Selected Financial Results - The Natural Gas Gathering and Processing segment’s financial results for the three and six months ended June 30, 2016, reflect the benefits from the completed projects in the table above. The lower commodity price environment continues to impact ONEOK Partners’ 2016 financial results but the impact has been mitigated partially by restructured contracts, which became effective primarily in the fourth quarter 2015 and first quarter 2016. Additionally, with current market conditions, crude oil and natural gas producers are focusing their drilling activities in the most productive areas that are most economical to develop and have higher production volumes, which offsets partially the reduction in drilling activity.

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

	Three Months Ended						Six Months Ended						Three Months					Six Months
	June 30,						June 30,						2016 vs. 2015					2016 vs. 2015
Financial Results	2016			2015			2016			2015			Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
NGL sales	$	152.4		$	156.2		$	247.0		$	304.4		$	(3.8	)	(2	%)	$	(57.4	)	(19	%)
Condensate sales	14.9			15.6			27.6			27.6			(0.7		)	(4	%)	—			—	%
Residue natural gas sales	136.6			203.0			294.3			424.4			(66.4		)	(33	%)	(130.1		)	(31	%)
Gathering, compression, dehydration and processing fees and other revenue	172.9			85.3			339.9			159.3			87.6			*		180.6			*
Cost of sales and fuel (exclusive of depreciation and items shown separately below)	(300.0		)	(323.0		)	(566.3		)	(653.9		)	(23.0		)	(7	%)	(87.6		)	(13	%)
Operating costs	(69.3		)	(63.5		)	(138.9		)	(132.8		)	5.8			9	%	6.1			5	%
Equity in net earnings from investments	2.6			4.9			5.4			9.2			(2.3		)	(47	%)	(3.8		)	(41	%)
Other	0.2			(0.4		)	1.3			0.4			0.6			*		0.9			*
Adjusted EBITDA	$	110.3		$	78.1		$	210.3		$	138.6		$	32.2		41	%	$	71.7		52	%
Capital expenditures	$	84.7		$	205.4		$	226.2		$	460.7		$	(120.7	)	(59	%)	$	(234.5	)	(51	%)

* Percentage change is greater than 100 percent.

See Reconciliation of Adjusted EBITDA to Net Income in the “Adjusted EBITDA” section.

Adjusted EBITDA increased $32.2 million for the three months ended June 30, 2016, compared with the same period in 2015, primarily as a result of the following:

• an increase of $36.6 million due primarily to restructured contracts resulting in higher average fee rates and a lower percentage of proceeds retained from the sale of commodities under the POP with fee contracts; and

• an increase of $33.5 million due primarily to natural gas volume growth in the Williston Basin, offset partially by volume declines in the Mid-Continent region; offset partially by

• a decrease of $28.6 million due primarily to lower net realized NGL and natural gas prices;

• an increase of $5.8 million in operating costs due primarily to higher employee-related costs associated with incentive and medical benefit plans and ONEOK Partners’ completed capital projects; and

• a decrease of $1.8 million due primarily to decreased ethane rejection to maintain downstream NGL product specifications.

Adjusted EBITDA increased $71.7 million for the six months ended June 30, 2016, compared with the same period in 2015, primarily as a result of the following:

• an increase of $78.5 million due primarily to restructured contracts resulting in higher average fee rates and a lower percentage of proceeds retained from the sale of commodities under the POP with fee contracts; and

• an increase of $64.7 million due primarily to natural gas volume growth in the Williston Basin, offset partially by volume declines in the Mid-Continent region; offset partially by

• a decrease of $58.5 million due primarily to lower net realized NGL and natural gas prices;

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• an increase of $6.1 million in operating costs due primarily to higher employee-related costs associated with incentive and medical benefit plans and ONEOK Partners’ completed capital projects; and

• a decrease of $4.0 million due primarily to decreased ethane rejection to maintain downstream NGL product specifications.

Capital expenditures decreased for the three and six months ended June 30, 2016, compared with the same periods in 2015, due to projects placed in service in 2015, spending reductions to align with customer needs and lower well connect activities due to a reduction in drilling and completion activity.

See “Capital Expenditures” in “Liquidity and Capital Resources” for additional detail of our projected capital expenditures.

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				Six Months Ended
	June 30,				June 30,
Operating Information (a)	2016		2015		2016		2015
Natural gas gathered (BBtu/d)	2,039		1,926		2,083		1,867
Natural gas processed (BBtu/d) (b)	1,882		1,677		1,915		1,651
NGL sales (MBbl/d)	158		127		157		117
Residue natural gas sales (BBtu/d)	854		864		897		823
Realized composite NGL net sales price ($/gallon) (c) (d)	$	0.24	$	0.38	$	0.22	$	0.38
Realized condensate net sales price ($/Bbl) (c) (e)	$	37.20	$	35.46	$	35.23	$	32.89
Realized residue natural gas net sales price ($/MMBtu) (c) (e)	$	2.86	$	3.38	$	2.73	$	3.65
Average fee rate ($/MMBtu)	$	0.76	$	0.39	$	0.72	$	0.37

(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, natural gas processed and NGL sales increased during the three months ended June 30, 2016, compared with the same period in 2015, due to the completion of growth projects in the Williston Basin, offset partially by planned facility maintenance and weather events in the Williston Basin and natural gas volume declines in the Mid-Continent region.

Natural gas gathered, natural gas processed, NGL sales and residue natural gas sales increased during the six months ended June 30, 2016, compared with the same period in 2015, due to the completion of growth projects in the Williston Basin, offset partially by planned facility maintenance and weather events in the Williston Basin and natural gas volume declines in the Mid-Continent region.

The quantity and composition of NGLs and natural gas have varied as new plants were placed in service and to ensure natural gas and natural gas liquids pipeline specifications were met. Beginning in June 2015, ONEOK Partners reduced the level of ethane rejection in the Rocky Mountain region to address downstream NGL product specifications.

	Three Months Ended		Six Months Ended
	June 30,		June 30,
Equity Volume Information (a)	2016	2015	2016	2015
NGL sales - including ethane (MBbl/d)	16.0	21.1	16.2	19.0
Condensate sales (MBbl/d)	2.6	3.1	2.6	3.1
Residue natural gas sales (BBtu/d)	77.7	155.5	80.7	144.3

(a) - Includes volumes for consolidated entities only.

Commodity Price Risk - See discussion regarding ONEOK Partners’ commodity price risk under “Commodity Price Risk” in Item 3, Quantitative and Qualitative Disclosures about Market Risk in this Quarterly Report.

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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 and delivers those products to the two primary market centers, one in the Mid-Continent in Conway, Kansas, and the other in the Gulf Coast in Mont Belvieu, Texas. It 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 to its natural gas liquids fractionation, storage and pipeline assets.

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 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 customers, such as petrochemical manufacturers, heating fuel users, ethanol producers, refineries, exporters and propane distributors.

Earnings 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. This segment also purchases NGLs and condensate from third parties, as well as from the Natural Gas Gathering and Processing segment. The segment’s fee-based services have increased due primarily to new supply connections, expansion of existing connections and the completion of capital projects. The segment’s business activities are categorized as exchange and storage services, transportation services, and optimization and marketing, which are defined as follows:

• ONEOK Partners’ exchange and storage services utilize its assets to gather, fractionate and/or treat, and transport unfractionated NGLs, 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 that provide a minimum level of revenues regardless of volumetric throughput. Although ONEOK Partners’ exchange services activities are primarily fee-based, it also captures certain product price differentials as volumes are fractionated. ONEOK Partners’ storage activities consist primarily of fee-based NGL storage services at its Mid-Continent and Gulf Coast storage facilities.

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

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

Excess NGL supply continues to result in narrow NGL location price differentials between the Mid-Continent and Gulf Coast market centers. We expect these narrow price differentials to persist between the Conway, Kansas, and Mont Belvieu, Texas, market centers, as a result of NGL production increases from various NGL-rich shale areas throughout the country, until demand for NGLs increases from petrochemicals and exporters, which we anticipate to begin in 2017.

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 and Rocky Mountain regions during 2015 and into 2016, which reduced natural gas liquids volumes gathered, fractionated, transported and sold across ONEOK Partners’ assets. 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. Ethane rejection levels by natural gas processors delivering to ONEOK Partners’ natural gas liquids gathering system decreased to approximately 150 MBbl/d during the second quarter 2016, compared with an average of more than 175 MBbl/d during the second half of 2015

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and first quarter 2016, primarily in the Mid-Continent region. While the volume of ethane recovered increased during the second quarter 2016, a portion of the fees associated with those volumes gathered and fractionated was previously being earned under contracts with minimum volume obligations. We expect ethane rejection levels to continue to fluctuate for the remainder of 2016 as the market begins to balance ethane supply and demand and with changes in the price differentials between ethane and natural gas. We expect ethane rejection levels to decrease as ethylene producers and NGL exporters increase their capacity to consume and export additional ethane feedstock volumes. Ethane demand is expected to ramp up as new world-scale ethylene production projects, petrochemical plant modifications, plant expansions and export facilities near completion and begin coming on line in early 2017.

Despite the ethane rejection across ONEOK Partners’ system, beginning in June 2015, the Natural Gas Gathering and Processing segment reduced its level of ethane rejection in the Williston Basin to alleviate downstream NGL product specification issues, which offsets partially the financial impact of ethane rejection. We expect this decreased ethane rejection to continue throughout 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.

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 ethane and propane, also is increasing.

In April 2015, ONEOK Partners completed the NGL Pipeline and Hutchinson Fractionator infrastructure project for approximately $120 million, excluding AFUDC.

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

Projects in Progress	Location	Capacity	Approximate Costs (a)	Expected Completion Date
			(In millions)
Bear Creek NGL infrastructure	Williston Basin	40 miles	$35-$45	Third quarter 2016
Bakken NGL Pipeline expansion - Phase II	Rocky Mountain Region	25 MBbl/d	$100	Third quarter 2018
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 the expectation of continued slower supply growth or declines due to the lower 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. ONEOK Partners could resume its suspended capital-growth projects when 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.

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

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

	Three Months Ended						Six Months Ended						Three Months					Six Months
	June 30,						June 30,						2016 vs. 2015					2016 vs. 2015
Financial Results	2016			2015			2016			2015			Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
NGL and condensate sales	$	1,497.3		$	1,509.0		$	2,614.4		$	2,712.1		$	(11.7	)	(1	%)	$	(97.7	)	(4	%)
Exchange service and storage revenues	337.2			299.0			657.6			548.6			38.2			13	%	109.0			20	%
Transportation revenues	37.5			40.9			87.4			84.3			(3.4		)	(8	%)	3.1			4	%
Cost of sales and fuel (exclusive of depreciation and items shown separately below)	(1,525.2		)	(1,535.5		)	(2,682.2		)	(2,764.4		)	(10.3		)	(1	%)	(82.2		)	(3	%)
Operating costs	(83.8		)	(77.4		)	(157.0		)	(159.7		)	6.4			8	%	(2.7		)	(2	%)
Equity in net earnings from investments	13.9			9.7			27.3			16.7			4.2			43	%	10.6			63	%
Other	(0.3		)	(1.1		)	(0.7		)	(0.4		)	0.8			73	%	(0.3		)	(75	%)
Adjusted EBITDA	$	276.6		$	244.6		$	546.8		$	437.2		$	32.0		13	%	$	109.6		25	%
Capital expenditures	$	20.8		$	59.1		$	55.0		$	132.6		$	(38.3	)	(65	%)	$	(77.6	)	(59	%)

See Reconciliation of Adjusted EBITDA to Net Income in the “Adjusted EBITDA” section.

Adjusted EBITDA increased $32.0 million for the three months ended June 30, 2016, compared with the same period in 2015, primarily as a result of the following:

• an increase of $27.7 million in exchange services, which includes:

◦ a $22.4 million increase due to increased volumes from recently connected natural gas processing plants in the Williston Basin and Mid-Continent region, offset partially by lower short-term contracted volumes in the Gulf Coast region; and

◦ a $21.7 million increase from decreased ethane rejection in the Williston Basin and Mid-Continent region, which increased NGL volumes gathered and fractionated; offset partially by

◦ a $15.4 million decrease in revenues from minimum volume obligations as earnings were realized through the increased volumes and decreased ethane rejection described above;

• an increase of $8.1 million in optimization and marketing activities, which resulted from a $5.4 million increase due primarily to wider marketing product price differentials and a $2.7 million increase due primarily to higher optimization volumes;

• an increase of $4.2 million in equity in net earnings from investments due primarily to higher volumes delivered to Overland Pass Pipeline from ONEOK Partners’ Bakken NGL Pipeline;

• an increase of $2.6 million related to higher isomerization volumes, resulting from wider NGL product price differentials between normal butane and iso-butane; offset partially by

• an increase of $6.4 million in operating costs due primarily to higher employee-related costs associated with incentive and medical benefit plans; and

• a decrease of $5.6 million due to the impact of operational measurement losses in 2016 and operational measurement gains in 2015.

Adjusted EBITDA increased $109.6 million for the six months ended June 30, 2016, compared with the same period in 2015, primarily as a result of the following:

• an increase of $88.7 million in exchange services, which includes:

◦ a $64.0 million increase due to increased volumes from recently connected natural gas processing plants in the Williston Basin and Mid-Continent region, offset partially by lower short-term contracted volumes in the Gulf Coast region;

◦ a $38.7 million increase from decreased ethane rejection in the Williston Basin and Mid-Continent region, which increased NGL volumes gathered and fractionated; and

◦ a $5.7 million increase due to higher fee rates; offset partially by

◦ a $18.7 million decrease in revenues from minimum volume obligations as earnings were realized through the increased volumes and decreased ethane rejection described above;

• an increase of $10.6 million in equity in net earnings from investments due primarily to higher volumes delivered to Overland Pass Pipeline from ONEOK Partners’ Bakken NGL Pipeline;

• an increase of $4.2 million in optimization and marketing activities, which resulted from a $7.1 million increase due

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primarily to higher optimization volumes, offset partially by a $2.9 million decrease due primarily to narrower marketing product price differentials;

• an increase of $3.0 million in higher storage activities; and

• a decrease of $2.7 million in operating costs due to lower operating costs resulting from ongoing cost reduction efforts and lower rates charged by service providers, offset partially by higher employee-related costs associated with incentive and medical benefit plans.

Capital expenditures decreased for the three and six months ended June 30, 2016, compared with the same periods in 2015, due primarily to spending reductions to align with customer needs.

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
Operating Information	2016		2015		2016		2015
NGL sales (MBbl/d)	767		723		742		643
NGLs transported-gathering lines (MBbl/d) (a)	809		784		780		746
NGLs fractionated (MBbl/d) (b)	608		554		579		515
NGLs transported-distribution lines (MBbl/d) (a)	515		420		495		404
Average Conway-to-Mont Belvieu OPIS price differential - ethane in ethane/propane mix ($/gallon)	$	0.04	$	0.02	$	0.03	$	0.01

(a) - Includes volumes for consolidated entities only.

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

NGLs transported on gathering lines increased for the three and six months ended June 30, 2016, compared with the same periods in 2015, due to increased volumes from new plant connections and decreased ethane rejection in the Mid-Continent region and the Williston Basin, offset partially by decreased volumes on the West Texas LPG system.

NGLs fractionated increased for the three and six months ended June 30, 2016, compared with the same periods in 2015, due to increased volumes from new plant connections and decreased ethane rejection in the Mid-Continent region and the Williston Basin.

While the volume of ethane recovered increased for the three and six months ended June 30, 2016, a portion of the fees associated with those volumes gathered and fractionated was previously being earned under contracts with minimum volume obligations.

NGLs transported on distribution lines increased for the three and six months ended June 30, 2016, compared with the same periods in 2015, due primarily to higher gathered and fractionated volumes as discussed above and due to increased volumes transported for ONEOK Partners’ optimization activities.

Natural Gas Pipelines

Overview - The Natural Gas Pipelines segment provides transportation and storage services to end users through its wholly owned assets, its 50 percent ownership in Northern Border Pipeline and its 50 percent ownership in Roadrunner. Phase I of the Roadrunner pipeline was completed in March 2016, and Phase II is currently under construction and is expected to be complete in the fourth quarter 2016.

Interstate Pipelines - ONEOK Partners’ interstate pipelines are regulated by the FERC and are located in North Dakota, Minnesota, Wisconsin, Illinois, Indiana, Kentucky, Tennessee, Oklahoma, Texas and New Mexico. ONEOK Partners’ interstate pipeline companies include:

• Midwestern Gas Transmission, which is a bidirectional 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, that have access to both the Utica Shale and Marcellus Shale;

• Viking Gas Transmission, which is a bidirectional system that 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

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• OkTex Pipeline, which has interconnections with several pipelines in Oklahoma, Texas and New Mexico.

Intrastate Pipelines - ONEOK Partners’ 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. ONEOK Partners’ intrastate natural gas pipeline assets in Oklahoma serve end-use markets, such as local distribution companies and power generation companies. In Texas, ONEOK Partners’ intrastate natural gas pipelines are connected to the major natural gas producing formations in the Texas Panhandle, including the Granite Wash formation and the Delaware and Cline producing formations in the Permian Basin. These pipelines are capable of transporting natural gas throughout the western portion of Texas, including the Waha Hub where other pipelines may be accessed for transportation to western markets, exports to Mexico, the Houston Ship Channel market to the east and the Mid-Continent market to the north. ONEOK Partners’ intrastate natural gas pipeline assets also have access to the natural gas producing formations in south central Kansas.

Through its Roadrunner joint venture, Roadrunner transports natural gas from the Permian Basin in West Texas to the Mexican border near El Paso, Texas, and is fully subscribed with 25-year firm, fee-based agreements. The Roadrunner pipeline connects with ONEOK Partners’ existing natural gas pipeline and storage infrastructure in Texas and, together with its WesTex intrastate natural gas pipeline expansion project, creates a platform for future opportunities to deliver natural gas supply to Mexico. Phase II of the Roadrunner pipeline, which is currently under construction and is expected to be complete in the fourth quarter 2016, will provide additional delivery capacity to these markets in Mexico.

Transportation Rates - Transportation contracts for ONEOK Partners’ regulated natural gas services are based upon rates stated in the respective tariffs. The tariffs provide both the general terms and conditions for the facilities and the maximum allowed rates customers can be charged by type of service, which may be discounted to meet competition if necessary. The rates are established at FERC or the appropriate state jurisdictional agencies. The earnings are primarily fee-based from the following types of services:

• Firm service - Customers reserve a fixed quantity of pipeline capacity for a specified period of time, which obligates the customer to pay for services regardless of usage. Under this type of contract, the customer pays a fixed fee and incremental fees, known as commodity charges, which are based on the actual volumes of natural gas they transport or store. In addition, ONEOK Partners may retain a percentage of fuel in-kind based on the volumes of natural gas transported. Under the firm service contract, the customer generally is guaranteed access to the capacity they reserve.

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

Storage - ONEOK Partners owns natural gas storage facilities located in Texas and Oklahoma that are connected to its intrastate natural gas pipelines. It also has underground natural gas storage facilities in Kansas. In Texas and Kansas, natural gas storage operations 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 not subject to rate regulation by the state and have market-based rate authority from the FERC for certain types of services.

Storage Rates - The earnings are primarily fee-based from the following types of services:

• Firm service - Customers reserve a specific quantity of storage capacity, including injection and withdrawal rights, and generally pay fixed fees based on the quantity of capacity reserved plus an injection and withdrawal fee. Firm storage contracts typically have terms longer than one year.

• Park-and-loan service - An interruptible service offered to customers providing the ability to park (inject) or loan (withdraw) natural gas into or out of storage, typically for monthly or seasonal terms. Customers reserve the right to park or loan natural gas based on a specified quantity, including injection and withdrawal rights when capacity is available.

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

Growth Projects	Location	Capacity	Approximate Costs (a)	Completion Date (c)
			(In millions)
WesTex pipeline expansion	Permian Basin	260 MMcf/d	$55-$70	Fourth quarter 2016
Roadrunner Gas Transmission Pipeline - Equity-Method Investment
Phase I - Completed (b)	Permian Basin	170 MMcf/d	$200	March 2016
Phase II (b)	Permian Basin	400 MMcf/d	$205-$220	Fourth quarter 2016
Phase III (b)	Permian Basin	70 MMcf/d	$30-$40	2019
Roadrunner Gas Transmission Pipeline Total			$435-$460

(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.

(c) - Represents expected completion date for projects still in progress.

Roadrunner - In 2015, Roadrunner entered into a $230 million senior secured credit facility for the construction and operation of the pipeline. The senior secured credit facility expires seven years after the Roadrunner Phase II in-service date, which is expected to be completed in the fourth quarter 2016. In addition, Roadrunner executed interest-rate swaps to hedge the variability of its interest payments during the term of the credit facility. Roadrunner’s credit facility is nonrecourse to ONEOK and ONEOK Partners, and neither ONEOK nor ONEOK Partners guarantees Roadrunner’s debts or obligations under the credit facility. ONEOK Partners contributed approximately $20 million to Roadrunner in the six months ended June 30, 2016, and approximately $30 million in the year ended December 31, 2015. ONEOK Partners expects to contribute an additional $45 million to Roadrunner during the remainder of 2016.

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

	Three Months Ended						Six Months Ended						Three Months					Six Months
	June 30,						June 30,						2016 vs. 2015					2016 vs. 2015
Financial Results	2016			2015			2016			2015			Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
Transportation revenues	$	68.7		$	62.2		$	136.5		$	129.8		$	6.5		10	%	$	6.7		5	%
Storage revenues	15.2			15.2			30.7			28.1			—			—	%	2.6			9	%
Natural gas sales and other revenues	4.1			2.7			6.8			5.7			1.4			52	%	1.1			19	%
Cost of sales and fuel (exclusive of depreciation and items shown separately below)	(5.1		)	(6.0		)	(9.0		)	(20.4		)	(0.9		)	(15	%)	(11.4		)	(56	%)
Operating costs	(29.2		)	(25.2		)	(56.7		)	(52.4		)	4.0			16	%	4.3			8	%
Equity in net earnings from investments	15.9			15.4			32.6			35.1			0.5			3	%	(2.5		)	(7	%)
Other	(1.1		)	0.9			2.0			10.0			(2.0		)	*		(8.0		)	(80	%)
Adjusted EBITDA	$	68.5		$	65.2		$	142.9		$	135.9		$	3.3		5	%	$	7.0		5	%
Capital expenditures	$	29.3		$	15.6		$	47.2		$	25.2		$	13.7		88	%	$	22.0		87	%

* Percentage change is greater than 100 percent.

See Reconciliation of Adjusted EBITDA to Net Income in the “Adjusted EBITDA” section.

Adjusted EBITDA increased $3.3 million for the three months ended June 30, 2016, compared with the same period in 2015, primarily as a result of the following:

• an increase of $7.1 million from higher transportation revenues, due primarily to increased firm demand charge volumes contracted; offset partially by

• an increase of $4.0 million in operating costs due primarily to increased employee-related costs associated with incentive and medical benefit plans.

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Adjusted EBITDA increased $7.0 million for the six months ended June 30, 2016, compared with the same period in 2015, primarily as a result of the following:

• an increase of $9.1 million from higher transportation services, due primarily to increased firm demand charge volumes contracted; and

• an increase of $6.0 million due to higher natural gas storage services as a result of increased rates and the sale of excess natural gas in storage in 2016; offset partially by

• an increase of $4.3 million in operating costs due primarily to increased employee-related costs associated with incentive and medical benefit plans.

Capital expenditures increased for the three and six months ended June 30, 2016, compared with the same periods in 2015, due primarily to the WesTex pipeline expansion and compressor station expansion 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						Six Months Ended
	June 30,						June 30,
Operating Information (a)	2016			2015			2016			2015
Natural gas transportation capacity contracted (MDth/d)	6,193			5,714			6,175			5,826
Transportation capacity contracted	93		%	90		%	93		%	92		%
Average natural gas price
Mid-Continent region ($/MMBtu)	$	1.93		$	2.48		$	1.87		$	2.55

(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, ONEOK Partners expects crude oil and natural gas producers to demand incremental services in the future to transport their production to market. The abundance of natural 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. Overall, ONEOK Partners expects its fee-based earnings in this segment to remain relatively stable. Growth will continue in the Permian Basin as ONEOK Partners completes construction of its Roadrunner joint venture and its WesTex pipeline expansion.

Northern Border Pipeline, in which ONEOK Partners has a 50 percent ownership interest, has contracted substantially all of its long-haul transportation capacity through the third quarter 2017. Roadrunner, in which ONEOK Partners has a 50 percent ownership interest, has contracted all of its capacity for both Phase I and Phase II through the first quarter 2041.

Adjusted EBITDA

Adjusted EBITDA is a non-GAAP measure of our financial performance. Adjusted EBITDA is defined as net income adjusted for interest expense, depreciation and amortization, noncash impairment charges, income taxes and AFUDC and other noncash items. We believe this non-GAAP financial measure is useful to investors because it is used by many companies in our industry as a measurement of financial performance and is commonly employed by financial analysts and others to evaluate our financial performance and to compare our financial performance with the performance of other publicly traded companies within our industry. Adjusted EBITDA should not be considered an alternative to net income, earnings per unit or any other measure of financial performance presented in accordance with GAAP. Additionally, this calculation may not be comparable with similarly titled measures of other companies.

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A reconciliation of Adjusted EBITDA for the three and six months ended June 30, 2016 and 2015, to net income, which is the nearest comparable GAAP financial measure, is as follows:

	Three Months Ended						Six Months Ended
	June 30,						June 30,
(Unaudited)	2016			2015			2016			2015
Reconciliation of Adjusted EBITDA to Net Income	(Thousands of dollars)
Segment Adjusted EBITDA:
Natural Gas Gathering and Processing	$	110,298		$	78,062		$	210,333		$	138,580
Natural Gas Liquids	276,611			244,591			546,780			437,246
Natural Gas Pipelines	68,542			65,234			142,881			135,946
Other	(2,768		)	(2,228		)	(5,682		)	(5,701		)
Total	452,683			385,659			894,312			706,071
Depreciation and amortization	(99,247		)	(86,987		)	(193,725		)	(172,942		)
Interest expense, net of capitalized interest	(118,976		)	(102,384		)	(237,223		)	(199,134		)
Income taxes	(52,458		)	(48,222		)	(102,524		)	(85,650		)
AFUDC and other	(1,916		)	2,954			(4,843		)	(1,488		)
Income from continuing operations	180,086			151,020			355,997			246,857
Income (loss) from discontinued operations, net of tax	(227		)	(140		)	(1,179		)	(284		)
Net income	$	179,859		$	150,880		$	354,818		$	246,573

CONTINGENCIES

Gas Index Pricing Litigation - In May 2016, the Court entered an order granting summary judgment in favor of us and our affiliate ONEOK Energy Services Company, L.P., (“OESC”) in Reorganized FLI, Inc. (formerly J.P. Morgan Trust Company) v. ONEOK, Inc., et al. (filed in the District Court of Wyandotte County, Kansas, in October 2005, transferred to MDL 166 in the United States District Court for the District of Nevada). The Court determined that the plaintiff’s claim is barred by a release obtained in a prior lawsuit against us and OESC. Upon entry of a final judgment,Reorganized FLI, Inc. may pursue an appeal of this determination to the Ninth Circuit Court of Appeals.

In March 2016, we reached an agreement in principle to settle the claims alleged against us and our affiliates, OESC and Kansas Gas Marketing Company, in the following putative class action lawsuits that claimed damages resulting from alleged market manipulation or false reporting of prices to gas index publications by us and others: Learjet, Inc., et al. v. ONEOK, Inc., et al. (filed in the District Court of Wyandotte, Kansas, in November 2005, transferred to MDL-1566 in the United States District Court for the District of Nevada); Arandell Corporation, et al. v. Xcel Energy, Inc., et al. (filed in the Circuit Court for Dane County, Wisconsin, in December 2006, transferred to MDL-1566 in the United States District Court for the District of Nevada); Heartland Regional Medical Center, et al. v. ONEOK, Inc., et al. (filed in the Circuit Court of Buchanan County, Missouri, in March 2007, transferred to MDL-1566 in the United States District Court for the District of Nevada); and NewPage Wisconsin System v. CMS Energy Resource Management Company, et al. (filed in the Circuit Court for Wood County, Wisconsin, in March 2009, transferred to MDL-1566 in the United States District Court for the District of Nevada and now consolidated with the Arandell case). The amount we expect to pay to settle these cases is not material to our results of operations, financial position or cash flows and is expected to be paid with cash on hand.

This agreement in principle to settle does not apply to Sinclair Oil Corporation v. ONEOK Energy Services Corporation, L.P., et al. (filed in the United States District Court for the District of Wyoming in September 2005, transferred to MDL-1566 in the United States District Court for the District of Nevada). We expect that future charges, if any, from the ultimate resolution of this matter will not be material to our results of operations, financial position or cash flows.

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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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 partner interests in ONEOK Partners. The cash distributions that we expect to receive from ONEOK Partners are expected to provide sufficient resources to fund our operations, debt service and quarterly cash dividends. At June 30, 2016, we had $177.1 million of cash on hand. Our next long-term debt maturity is in 2022.

We expect future cash expenditures associated with the released transportation and storage capacity from the wind down of our former energy services business to be approximately $25 million, with approximately $7 million to be paid in the remainder of 2016, $10 million in 2017, $4 million in 2018 and $4 million over the period 2019 through 2023.

ONEOK Partners - ONEOK Partners 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. As of June 30, 2016, ONEOK Partners had $3.7 million of cash on hand and available capacity under its Partnership Credit Agreement of $1.8 billion. In addition, in the first quarter 2016, ONEOK Partners drew the full $1.0 billion available under its Term Loan Agreement that matures in January 2019.

ONEOK Partners 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 equity, as necessary. Capital expenditures are funded by operating cash flows, short- and long-term debt and issuances of equity. 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 significant decline in commodity prices has increased the cost of debt and equity financing for ONEOK Partners and others in the industry. While lower commodity prices and industry uncertainty may result in increased financing costs, ONEOK Partners expects to utilize its commercial paper program, Partnership Credit Agreement, Term Loan Agreement and cash from operations to fund its announced capital-growth expenditures, refinance its senior notes maturities and meet its working capital needs through 2016 and well into 2017. However, ONEOK Partners may access the capital markets to issue debt or equity securities prior to that time as it considers prudent to provide liquidity for new capital projects, to maintain investment-grade credit ratings or for other partnership purposes.

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 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 of $177.1 million as of June 30, 2016, and access to our $300 million ONEOK Credit Agreement. At June 30, 2016, 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, the ONEOK Partners Credit Agreement and its “at-the-market” equity program.

ONEOK Partners had working capital (defined as current assets less current liabilities) deficits of $1 billion and $697 million as of June 30, 2016, and December 31, 2015, respectively. Although working capital is influenced by several 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, ONEOK Partners’ working capital deficit at June 30, 2016, was driven primarily by its capital-growth projects and

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current maturities of its long-term debt. ONEOK Partners’ working capital deficit at December 31, 2015, was driven primarily by its capital-growth projects. 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. We do not expect ONEOK Partners’ working capital deficit to have an adverse impact to our or ONEOK Partners’ cash flows or operations. The consolidated working capital balance is impacted primarily by ONEOK Partners’ working capital balance.

ONEOK Credit Agreement - In January 2016, we extended the term of our ONEOK Credit Agreement by one year to January 2020. At June 30, 2016, ONEOK had $1.1 million of letters of credit issued under the ONEOK Credit Agreement and approximately $177.1 million of cash and cash equivalents. We had $298.9 million of credit available at June 30, 2016, 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 the 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 June 30, 2016, our ratio of indebtedness to Consolidated EBITDA, was 2.2 to 1, and we were 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, we 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 interest at LIBOR plus 145 basis points, and the annual facility fee is 30 basis points.

ONEOK Partners Credit Agreement - At June 30, 2016, ONEOK Partners had $576 million of commercial paper outstanding, $14 million of letters of credit issued and no borrowings outstanding under the ONEOK Partners Credit Agreement. At June 30, 2016, ONEOK Partners had approximately $3.7 million of cash and cash equivalents and approximately $1.8 billion of credit available under the ONEOK Partners Credit Agreement.

In January 2016, ONEOK Partners extended the term of the ONEOK Partners Credit Agreement by one year to January 2020. The ONEOK Partners Credit Agreement 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. 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. 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 June 30, 2016, ONEOK Partners’ ratio of indebtedness to adjusted EBITDA was 4.2 to 1, and it was in compliance with all covenants under the ONEOK Partners Credit Agreement. At June 30, 2016, ONEOK Partners could have issued $1.5 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, the Term Loan Agreement and ONEOK Partners’ senior notes are nonrecourse to ONEOK, and ONEOK does not guarantee ONEOK Partners’ debt, commercial paper or other similar commitments.

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Long-term Financing - In addition to our principal sources of short-term liquidity discussed above, we expect ONEOK Partners to fund its longer-term financing requirements by issuing common units or long-term notes. Other options to obtain financing include, but are not limited to, loans from financial institutions, 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’ investment-grade credit ratings, general financial condition, and expectations regarding its future earnings and projected cash flows, 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, 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 Issuances and Maturities - In January 2016, ONEOK Partners entered into the $1.0 billion senior unsecured delayed-draw Term Loan Agreement with a syndicate of banks. During the first quarter 2016, ONEOK Partners drew the full $1.0 billion available under the agreement and used the proceeds to repay its $650 million, 3.25 percent senior notes, which matured in February 2016, to repay amounts outstanding under its commercial paper program and for general partnership purposes. The Term Loan Agreement matures in January 2019 and bears interest at LIBOR plus a margin that is based on the credit ratings assigned to ONEOK Partners’ senior, unsecured, long-term indebtedness. Based on ONEOK Partners’ current applicable credit rating, borrowings on the Term Loan Agreement will accrue at LIBOR plus 130 basis points. The Term Loan Agreement contains an option, which may be exercised up to two times, to extend the term of the loan, in each case, for an additional one-year term subject to approval of the banks. The Term Loan Agreement allows prepayment of all or any portion outstanding, without penalty or premium, and contains substantially the same covenants as those contained in the ONEOK Partners Credit Agreement.

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 expects to repay its $450 million, 6.15 percent senior notes due October 1, 2016, with a combination of cash on hand and short-term borrowings.

ONEOK Partners Equity Issuances - In August 2015, ONEOK Partners completed the sale to us in a private placement of 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 proceeds of approximately $749 million. 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.

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 June 30, 2016, ONEOK Partners had approximately $138 million of registered common units available for issuance through its “at-the-market” equity program.

During the three and six months ended June 30, 2016, no common units were sold through ONEOK Partners’ “at-the-market” equity program.

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During the three months ended June 30, 2015, ONEOK Partners sold 5.5 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 $208.1 million, which were used for general partnership purposes, including repayment of commercial paper borrowings.

During the six months ended June 30, 2015, ONEOK Partners sold 7.2 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 $279.7 million, which were used for general partnership purposes, including repayment of commercial paper borrowings.

During the year ended December 31, 2015, ONEOK Partners sold 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 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.

Interest-rate Swaps - As of June 30, 2016, ONEOK Partners had interest-rate swaps with notional amounts totaling $1.0 billion to hedge the variability of its LIBOR-based interest payments. In June 2016, ONEOK Partners entered into forward-starting interest-rate swaps with notional amounts totaling $750 million to hedge the variability of interest payments on a portion of its forecasted debt issuances that may result from changes in the benchmark interest rate before the debt is issued. At June 30, 2016, and December 31, 2015, ONEOK Partners had forward-starting interest-rate swaps with notional amounts totaling $1.2 billion and $400 million, respectively, to hedge the variability of interest payments on a portion of its forecasted debt issuances. All of ONEOK Partners’ interest-rate swaps are designated as cash flow hedges.

Capital Expenditures - ONEOK Partners’ capital expenditures are financed typically through operating cash flows, short- and long-term debt and the issuance of equity. ONEOK Partners’ capital expenditures were $332.3 million and $628.4 million for the six months ended June 30, 2016 and 2015, respectively.

The following table sets forth ONEOK Partners’ 2016 projected capital expenditures, excluding acquisitions, contributions to its equity-method investments, and AFUDC:

2016 Projected Capital Expenditures
	(Millions of dollars)
Natural Gas Gathering and Processing	$	345
Natural Gas Liquids	125
Natural Gas Pipelines	110
Other	20
Total projected capital expenditures	$	600

Credit Ratings - ONEOK and ONEOK Partners’ credit ratings as of June 30, 2016, 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

ONEOK Partners’ commercial paper program is rated Prime-2 by Moody’s and A-2 by S&P. ONEOK Partners’ credit ratings, which are investment-grade, may be affected by a material change in its 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.

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, and 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 2020. An adverse credit rating change alone is not a default under the ONEOK Credit Agreement or the ONEOK Partners Credit Agreement. A

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downgrade in ONEOK Partners’ credit ratings would likely 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.

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.

For the three and six months ended June 30, 2016, and 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 cash distributions, short-term liquidity needs and capital projects. ONEOK Partners expects increases in cash flows from operations in the remainder of 2016, compared with the first half of 2016, due primarily to the completion of its growth projects and new plant connections that ONEOK Partners expects will provide increasing volumes in the Natural Gas Gathering and Processing and Natural Gas Liquids segments. See discussion under “Short-term Liquidity” and “Long-term Financing” for more information.

Energy Commodity Prices - Although ONEOK Partners is subject to commodity price volatility, its commodity price exposure has been reduced due primarily to contract restructuring in the Natural Gas Gathering and Processing segment. ONEOK Partners has also hedged a significant portion of the Natural Gas Gathering and Processing segment’s commodity price risk for 2016 and 2017. 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. While lower commodity prices and industry uncertainty may result in increased financing costs, we believe ONEOK Partners has secured sufficient access to the financial resources and liquidity necessary to meet its requirements for working capital, debt service payments and capital expenditures through 2016 and well into 2017. We believe that its available credit and cash and cash equivalents are adequate to meet liquidity requirements associated with commodity price volatility. See Note C of the Notes to Consolidated Financial Statements and the discussion under “Commodity Price Risk” in Part I, Item 3, Quantitative and Qualitative Disclosures About Market Risk, 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 I of the Notes to Consolidated Financial Statements in this Quarterly Report for additional information.

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.

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

							Variances
	Six Months Ended						2016 vs. 2015
	June 30,						Increase (Decrease)
	2016			2015
	(Millions of dollars)
Total cash provided by (used in):
Operating activities	$	531.6		$	333.9		$	197.7
Investing activities	(298.5		)	(655.8		)	357.3
Financing activities	(149.6		)	374.9			(524.5		)
Change in cash and cash equivalents	83.5			53.0			30.5
Change in cash and cash equivalents included in discontinued operations	(0.2		)	0.4			(0.6		)
Change in cash and cash equivalents from continuing operations	83.3			53.4			29.9
Cash and cash equivalents at beginning of period	97.6			172.8			(75.2		)
Cash and cash equivalents at end of period	$	180.9		$	226.2		$	(45.3	)

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 $686.4 million for the six months ended June 30, 2016, compared with $518.4 million for the same period in 2015. The increase is due primarily to higher natural gas gathered and NGL volumes from ONEOK Partners’ completed capital-growth projects in the Natural Gas Gathering and Processing and Natural Gas Liquids segments and higher fees resulting from contract restructuring in the Natural Gas Gathering and Processing segment, offset partially by lower commodity prices, as discussed in “Financial Results and Operating Information.”

The changes in operating assets and liabilities decreased operating cash flows by $154.8 million for the six months ended June 30, 2016, compared with a decrease of $184.5 million for the same period in 2015. This change is due primarily to the change in accounts receivable, accounts payable, and other accruals and deferrals resulting from the timing of receipt of cash from customers and payments to vendors, suppliers, and other third parties; and the change in natural gas and NGLs in storage, which vary from period to period and vary with changes in commodity prices.

Investing Cash Flows - Cash used in investing activities decreased to $298.5 million for the six months ended June 30, 2016, compared with $655.8 million for the same period in 2015, due primarily to ONEOK Partners’ lower capital spending, compared with 2015, as a result of spending reductions to align with customer needs and projects placed in service in 2015, offset partially by proceeds received from ONEOK Partners’ sale of assets and higher distributions from unconsolidated affiliates.

Financing Cash Flows - Cash used in financing activities was $149.6 million for the six months ended June 30, 2016, compared with cash provided by financing activities of $374.9 million for the six months ended June 30, 2015. This change is due primarily to repayment of ONEOK Partners’ $650 million, 3.25 percent senior notes, which matured February 1, 2016. ONEOK Partners received long-term debt proceeds in the six months ended June 30, 2016, related to its $1.0 billion Term Loan Agreement, compared with proceeds from debt and equity issuances in the same period in 2015, related to its $800 million senior notes offering and approximately $280 million from equity issuances through its “at-the-market” equity program.

REGULATORY, ENVIRONMENTAL AND SAFETY MATTERS

Environmental Matters -ONEOK Partners is subject to multiple environmental, historical preservation and wildlife preservation 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

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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.

Additional information about our regulatory, environmental and safety matters can be found in “Regulatory, Environmental and Safety Matters” under Part I, Item 1, Business, in our Annual Report.

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;

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• 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;

• 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;

• conflicts of interest between us, ONEOK Partners and related parties of ONEOK Partners;

• 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;

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• 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.

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 are consistent with those discussed in Part II, Item 7A, Quantitative and Qualitative Disclosures About Market Risk, in our Annual Report.

COMMODITY PRICE RISK

As part of its hedging strategy, ONEOK Partners uses commodity derivative financial instruments and physical-forward contracts described in “Financial Results and Operating Information” under the Natural Gas Gathering and Processing segment section in Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations, to minimize the impact of near-term price fluctuations related to natural gas, NGLs and condensate.

ONEOK Partners is exposed to basis risk between the various production and market locations where it receives and sells commodities. Although ONEOK Partners’ businesses are predominately fee-based, in the Natural Gas Gathering and Processing segment, ONEOK Partners is exposed to commodity price risk as a result of receiving commodities as a portion of its compensation for services associated with its POP with fee contracts. ONEOK Partners has restructured a portion of its POP with fee contracts to include significantly higher fees, which reduces its equity volumes and the related commodity price exposure. However, under certain POP with fee contracts, ONEOK Partners’ fee revenues may increase or decrease if production volumes, delivery pressures or commodity prices change relative to specified thresholds.

The following tables set forth hedging information for the Natural Gas Gathering and Processing segment’s forecasted equity volumes for the periods indicated:

	Six Months Ending December 31, 2016
	Volumes Hedged	Average Price			Percentage Hedged
NGLs - excluding ethane (MBbl/d) - Conway/Mont Belvieu	8.8	$	0.48	/ gallon	82%
Condensate (MBbl/d) - WTI-NYMEX	1.8	$	58.68	/ Bbl	86%
Natural gas (BBtu/d) - NYMEX and basis	79.1	$	2.81	/ MMBtu	93%

	Year Ending December 31, 2017
	Volumes Hedged	Average Price			Percentage Hedged
NGLs - excluding ethane (MBbl/d) - Conway/Mont Belvieu	8.0	$	0.51	/ gallon	67%
Condensate (MBbl/d) - WTI-NYMEX	1.8	$	44.88	/ Bbl	74%
Natural gas (BBtu/d) - NYMEX and basis	73.1	$	2.66	/ MMBtu	74%

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We expect ONEOK Partners’ natural gas liquids and natural gas commodity price sensitivity within this segment to decrease in 2016, compared with 2015, as a result of the restructured contracts effective primarily in the fourth quarter 2015 and first quarter 2016. 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 June 30, 2016. Condensate sales are typically based on the price of crude oil. We estimate the following for ONEOK Partners’ forecasted equity volumes, including the effects of hedging information set forth above, and assuming normal operating conditions:

• a $0.01 per-gallon change in the composite price of NGLs would change adjusted EBITDA for the six months ending December 31, 2016, and for the year ending December 31, 2017, by approximately $0.3 million and $1.0 million, respectively;

• a $1.00 per-barrel change in the price of crude oil would change adjusted EBITDA for the six months ending December 31, 2016, and for the year ending December 31, 2017, by approximately $0.1 million and $0.4 million, respectively; and

• a $0.10 per-MMBtu change in the price of residue natural gas would change adjusted EBITDA for the six months ending December 31, 2016, and for the year ending December 31, 2017, by approximately $0.1 million and $0.9 million, respectively.

These estimates do not include any effects on demand for ONEOK Partners’ services or natural gas 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, impacting gathering and processing financial results for certain contracts.

The following tables set forth hedging information related to purchased put options to reduce commodity price sensitivity associated with certain POP with fee contracts:

	Six Months Ending December 31, 2016
	Volumes Hedged	Average Strike Price			Fair Value Asset at June 30, 2016
					(Millions of dollars)
Propane (MBbl/d) - Conway/Mont Belvieu	16.3	$	0.40	/ gallon	$	0.2
Natural gas (BBtu/d) - NYMEX	232.8	$	2.35	/ MMBtu	$	0.9

	Twelve Months Ending December 31, 2017
	Volumes Hedged	Average Strike Price			Fair Value Asset at June 30, 2016
					(Millions of dollars)
Natural gas (BBtu/d) - NYMEX	147.9	$	2.45	/ MMBtu	$	5.2

See Note C of the Notes to Consolidated Financial Statements in this Quarterly Report for information on ONEOK Partners’ hedging activities.

INTEREST-RATE RISK

We and ONEOK Partners are exposed to interest-rate risk through the ONEOK Credit Agreement, the ONEOK Partners Credit Agreement, ONEOK Partners’ commercial paper program and long-term debt issuances. Future increases in LIBOR, corporate commercial paper rates or corporate bond rates could expose us and ONEOK Partners to increased interest costs on future borrowings. 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. As of June 30, 2016, ONEOK Partners had interest-rate swaps with notional amounts totaling $1.0 billion to hedge the variability of ONEOK Partners’ LIBOR-based interest payments. In June 2016, ONEOK Partners entered into forward-starting interest-rate swaps with notional amounts totaling $750 million to hedge the variability of interest payments on a portion of its forecasted debt issuances that may result from changes in the benchmark interest rate before the debt is issued. At June 30, 2016, and December 31, 2015, ONEOK Partners had forward-starting interest-rate swaps with notional amounts totaling $1.2 billion and $400 million, respectively, to hedge the variability of interest payments on a portion of its forecasted debt issuances. All of ONEOK Partners’ interest-rate swaps are designated as cash flow hedges. At June 30, 2016, ONEOK Partners had $70.1 million of derivative liabilities related to these interest-rate swaps. At December 31, 2015, ONEOK Partners had derivative liabilities of $9.9 million related to these interest-rate swaps.

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

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. Certain of ONEOK Partners’ counterparties to the Natural Gas Gathering and Processing segment’s commodity 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.

Customer concentration - For the six months ended June 30, 2016, one customer, BP p.l.c or its affiliates, represented more than 10 percent of our consolidated revenues, and 20 customers individually represented 1 percent or more of our consolidated revenues, the majority of which are investment-grade customers, as rated by S&P or Moody’s, or our comparable internal ratings, or secured by letters of credit or other collateral.

Natural Gas Gathering and Processing - The Natural Gas Gathering and Processing segment’s customers are crude oil and natural gas producers, which include both large integrated and independent exploration and production companies. ONEOK Partners is not typically exposed to material credit risk with exploration and production customers under POP with fee contracts as it receives proceeds from the sale of commodities and remits a portion of those proceeds back to the crude oil and natural gas producers. For the six months ended June 30, 2016, 99 percent of the downstream commodity sales in the Natural Gas Gathering and Processing segment were made to investment-grade customers, as rated by S&P or Moody’s, or our comparable internal ratings, or secured by letters of credit or other collateral.

Natural Gas Liquids - The Natural Gas Liquids segment’s customers are primarily NGL and natural gas gathering and processing companies; large integrated and independent crude oil and natural gas production companies; propane distributors; ethanol producers; and petrochemical, refining and NGL marketing companies. ONEOK Partners earns fee-based revenue from NGL and natural gas gathering and processing customers and natural gas liquids pipeline transportation customers. ONEOK Partners is not typically exposed to material credit risk on the majority of its exchange services fee revenues, as ONEOK Partners purchases NGLs from its gathering and processing customers and deducts fees from the amounts it remits. ONEOK Partners also earns sales revenue on the downstream sales of NGL products. For the six months ended June 30, 2016, approximately 85 percent of this segment’s commodity sales were made to investment-grade customers, as rated by S&P or Moody’s, or our comparable internal ratings, or secured by letters of credit or other collateral. In addition, the majority of the Natural Gas Liquids segment’s pipeline tariffs provide ONEOK Partners the ability to require security from shippers.

Natural Gas Pipelines - The Natural Gas Pipelines segment’s customers are primarily local natural gas distribution companies, electric-generation facilities, large industrial companies, municipalities, irrigation customers and marketing companies. For the six months ended June 30, 2016, approximately 90 percent of the revenues in this segment were from investment-grade customers, as rated by S&P or Moody’s, or our comparable internal ratings, or secured by letters of credit or other collateral. In addition, the majority of the Natural Gas Pipeline segment’s pipeline tariffs provide ONEOK Partners the ability to require security from shippers.

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 Rule 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 June 30, 2016, 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

In May 2016, the Court entered an order granting summary judgment in favor of us and our affiliate ONEOK Energy Services Company, L.P., (“OESC”) in Reorganized FLI, Inc. (formerly J.P. Morgan Trust Company) v. ONEOK, Inc., et al. (filed in the District Court of Wyandotte County, Kansas, in October 2005, transferred to MDL 166 in the United States District Court for the District of Nevada). The Court determined that the plaintiff’s claim is barred by a release obtained in a prior lawsuit against us and OESC. Upon entry of a final judgment,Reorganized FLI, Inc. may pursue an appeal of this determination to the Ninth Circuit Court of Appeals.

In March 2016, we reached an agreement in principle to settle the claims alleged against us and our affiliates, OESC and Kansas Gas Marketing Company, in the following putative class action lawsuits that claimed damages resulting from alleged market manipulation or false reporting of prices to gas index publications by us and others: Learjet, Inc., et al. v. ONEOK, Inc., et al. (filed in the District Court of Wyandotte, Kansas, in November 2005, transferred to MDL-1566 in the United States District Court for the District of Nevada); Arandell Corporation, et al. v. Xcel Energy, Inc., et al. (filed in the Circuit Court for Dane County, Wisconsin, in December 2006, transferred to MDL-1566 in the United States District Court for the District of Nevada); Heartland Regional Medical Center, et al. v. ONEOK, Inc., et al. (filed in the Circuit Court of Buchanan County, Missouri, in March 2007, transferred to MDL-1566 in the United States District Court for the District of Nevada); and NewPage Wisconsin System v. CMS Energy Resource Management Company, et al. (filed in the Circuit Court for Wood County, Wisconsin, in March 2009, transferred to MDL-1566 in the United States District Court for the District of Nevada and now consolidated with the Arandell case). The amount we expect to pay to settle these cases is not material to our results of operations, financial position or cash flows and is expected to be paid with cash on hand.

This agreement in principle to settle does not apply to Sinclair Oil Corporation v. ONEOK Energy Services Corporation, L.P., et al. (filed in the United States District Court for the District of Wyoming in September 2005, transferred to MDL-1566 in the United States District Court for the District of Nevada). We expect that future charges, if any, from the ultimate resolution of this matter will not be material to our results of operations, financial position or cash flows.

Additional information about our legal proceedings is included under Part I, 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.

63

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

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)).

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 six months ended June 30, 2016 and 2015; (iii) Consolidated Statements of Comprehensive Income for the three and six months ended June 30, 2016 and 2015; (iv) Consolidated Balance Sheets at June 30, 2016, and December 31, 2015; (v) Consolidated Statements of Cash Flows for the six months ended June 30, 2016 and 2015; (vi) Consolidated Statements of Changes in Equity for the six months ended June 30, 2016 and 2015; 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.

64

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: August 3, 2016	By:	/s/ Derek S. Reiners
		Derek S. Reiners
		Senior Vice President,
		Chief Financial Officer and Treasurer
		(Principal Financial Officer)

65

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: August 3, 2016

/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: August 3, 2016

/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 June 30, 2016, 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

August 3, 2016

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 June 30, 2016, 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

August 3, 2016

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.

XML

Document And Entity Information - shares	6 Months Ended
	Jun. 30, 2016	Jul. 25, 2016
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		210,426,799
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q2
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2016

XML

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Revenues
Commodity sales	$ 1,633,272	$ 1,722,254	$ 2,916,783	$ 3,157,970
Services	500,835	405,798	991,783	775,388
Total revenues	2,134,107	2,128,052	3,908,566	3,933,358
Cost of sales and fuel (exclusive of items shown separately below)	1,527,323	1,603,093	2,723,061	2,946,957
Operations and maintenance	167,667	140,869	322,812	295,200
Depreciation and amortization	99,247	86,987	193,725	172,942
General taxes	24,172	24,481	46,042	49,168
(Gain) loss on sale of assets	413	(122)	(3,793)	(116)
Operating income	315,285	272,744	626,719	469,207
Equity in net earnings from investments (Note J)	32,372	30,040	65,286	60,961
Allowance for equity funds used during construction	0	742	208	1,541
Other income	4,804	60	5,109	2,670
Other expense	(941)	(1,960)	(1,578)	(2,738)
Interest expense (net of capitalized interest of $2,572, $9,927, $5,459 and $17,157, respectively)	(118,976)	(102,384)	(237,223)	(199,134)
Income before income taxes	232,544	199,242	458,521	332,507
Income taxes	(52,458)	(48,222)	(102,524)	(85,650)
Income from continuing operations	180,086	151,020	355,997	246,857
Income (loss) from discontinued operations, net of tax (Note M)	(227)	(140)	(1,179)	(284)
Net income	179,859	150,880	354,818	246,573
Less: Net income attributable to noncontrolling interests	93,915	74,375	185,428	109,268
Net income attributable to ONEOK	85,944	76,505	169,390	137,305
Amounts attributable to ONEOK:
Income from continuing operations	86,171	76,645	170,569	137,589
Income (loss) from discontinued operations	(227)	(140)	(1,179)	(284)
Net income attributable to ONEOK	$ 85,944	$ 76,505	$ 169,390	$ 137,305
Basic earnings per share:
Income from continuing operations (Note H)	$ 0.41	$ 0.36	$ 0.81	$ 0.65
Income (loss) from discontinued operations	0.00	0.00	(0.01)	0.00
Net income	0.41	0.36	0.80	0.65
Diluted earnings per share:
Income from continuing operations (Note H)	0.41	0.36	0.81	0.65
Income (loss) from discontinued operations	(0.01)	0.00	(0.01)	0.00
Net income	$ 0.40	$ 0.36	$ 0.80	$ 0.65
Average shares (thousands)
Basic	211,075	210,204	210,928	210,059
Diluted	212,618	210,477	211,663	210,486
Dividends declared per share of common stock	$ 0.615	$ 0.605	$ 1.23	$ 1.21

XML

CONSOLIDATED STATEMENTS OF INCOME (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Interest Costs, Capitalized During Period	$ 2,572	$ 9,927	$ 5,459	$ 17,157

XML

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Statement of Comprehensive Income [Abstract]
Net income	$ 179,859	$ 150,880	$ 354,818	$ 246,573
Other comprehensive income (loss), net of tax
Unrealized gains (losses) on derivatives, net of tax of $13,295, $(2,726), $16,334 and $(1,047), respectively	(73,923)	15,255	(90,817)	4,377
Realized (gains) losses on derivatives in net income, net of tax of $1,193, $1,439, $2,469 and $2,664, respectively	(8,054)	(11,041)	(16,579)	(20,271)
Unrealized holding gains (losses) on available-for-sale securities, net of tax of $0, $0, $0 and $648, respectively	0	0	0	(955)
Change in pension and postretirement benefit plan liability, net of tax of $(1,035), $(1,600), $(2,070) and $(3,199), respectively	1,552	2,441	3,105	4,879
Other comprehensive income (loss) on investments in unconsolidated affiliates, net of tax of $848, $0, $1,732 and $0, respectively	(4,714)	0	(9,631)	0
Total other comprehensive income (loss), net of tax	(85,139)	6,655	(113,922)	(11,970)
Comprehensive income	94,720	157,535	240,896	234,603
Less: Comprehensive income attributable to noncontrolling interest	33,408	76,472	103,510	96,279
Comprehensive income attributable to ONEOK	$ 61,312	$ 81,063	$ 137,386	$ 138,324

XML

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME Parenthetical - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Other comprehensive income (loss), net of tax
Unrealized gains (losses) on derivatives, tax	$ 13,295	$ (2,726)	$ 16,334	$ (1,047)
Realized (gains) losses on derivatives in net income, tax	1,193	1,439	2,469	2,664
Unrealized holding gains (losses) on available-for-sale securities, tax	0	0	0	648
Change in pension and postretirement benefit plan liability, tax	(1,035)	(1,600)	(2,070)	(3,199)
Other comprehensive income (loss) on investments in unconsolidated affiliates, tax	$ 848	$ 0	$ 1,732	$ 0

XML

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Current assets
Cash and cash equivalents	$ 180,854	$ 97,619
Accounts receivable, net	672,059	593,979
Materials and supplies	85,127	76,696
Natural gas and natural gas liquids in storage	245,946	128,084
Commodity imbalances	38,300	38,681
Other current assets	58,200	39,946
Assets of discontinued operations (Note M)	702	205
Total current assets	1,281,188	975,210
Property, plant and equipment
Property, plant and equipment	14,811,606	14,530,460
Accumulated depreciation and amortization	2,326,984	2,156,471
Net property, plant and equipment	12,484,622	12,373,989
Investments and other assets
Investments in unconsolidated affiliates	913,813	948,221
Goodwill and intangible assets	1,011,309	1,017,258
Other assets	118,980	112,598
Assets of discontinued operations (Note M)	12,988	18,835
Total investments and other assets	2,057,090	2,096,912
Total assets	15,822,900	15,446,111
Current liabilities
Current maturities of long-term debt (Note E)	460,650	110,650
Short-term borrowings (Note D)	576,307	546,340
Accounts payable	697,833	615,982
Commodity imbalances	105,544	74,460
Accrued interest	119,774	129,043
Other current liabilities	202,954	132,556
Liabilities of discontinued operations (Note M)	25,359	29,235
Total current liabilities	2,188,421	1,638,266
Long-term debt, excluding current maturities (Note E)	8,320,277	8,323,582
Deferred credits and other liabilities
Deferred income taxes	1,518,328	1,436,715
Other deferred credits	293,153	264,248
Liabilities of discontinued operations (Note M)	10,544	16,964
Total deferred credits and other liabilities	1,822,025	1,717,927
Commitments and contingencies (Note L)
ONEOK shareholders' equity:
Common stock, $0.01 par value: authorized 600,000,000 shares; issued 245,811,180 shares and outstanding 210,418,903 shares at June 30, 2016; issued 245,811,180 shares and outstanding 209,731,028 shares at December 31, 2015	2,458	2,458
Paid-in capital	1,294,583	1,378,444
Accumulated other comprehensive loss (Note G)	(159,246)	(127,242)
Retained earnings	0	0
Treasury stock, at cost: 35,392,277 shares at June 30, 2016, and 36,080,152 shares at December 31, 2015	(900,366)	(917,862)
Total ONEOK shareholders' equity	237,429	335,798
Noncontrolling interests in consolidated subsidiaries	3,254,748	3,430,538
Total equity	3,492,177	3,766,336
Total liabilities and equity	$ 15,822,900	$ 15,446,111

XML

CONSOLIDATED BALANCE SHEETS Parenthetical - $ / shares	Jun. 30, 2016	Dec. 31, 2015
Equity (Note F)
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)	210,418,903	209,731,028
Treasury stock, shares (in shares)	35,392,277	36,080,152

XML

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Operating Activities
Net income	$ 354,818	$ 246,573
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	193,725	172,942
Equity in net earnings from investments	(65,286)	(60,961)
Distributions received from unconsolidated affiliates	72,204	61,969
Deferred income taxes	105,567	84,306
Share-based compensation expense	23,194	7,884
Pension and postretirement benefit expense, net of contributions	6,172	7,372
Allowance for equity funds used during construction	(208)	(1,541)
(Gain) loss on sale of assets	(3,793)	(116)
Changes in assets and liabilities:
Accounts receivable	(85,435)	59,120
Natural gas and natural gas liquids in storage	(117,862)	(16,003)
Accounts payable	103,976	(136,119)
Commodity imbalances, net	31,465	20,497
Settlement of exit activities liabilities	(11,590)	(22,385)
Accrued interest	(9,269)	10,206
Risk management assets and liabilities	(60,016)	(66,148)
Other assets and liabilities, net	(6,056)	(33,676)
Cash provided by operating activities	531,606	333,920
Investing Activities
Capital expenditures (less allowance for equity funds used during construction)	(333,254)	(629,448)
Contributions to unconsolidated affiliates	(19,830)	(33,222)
Distributions received from unconsolidated affiliates in excess of cumulative earnings	36,373	18,814
Proceeds from sale of assets	18,232	691
Other	0	(12,607)
Cash used in investing activities	(298,479)	(655,772)
Financing Activities
Borrowing (repayment) of short-term borrowings, net	29,967	(184,812)
Issuance of long-term debt, net of discounts	1,000,000	798,896
Debt financing costs	(2,770)	(7,850)
Repayment of long-term debt	(654,151)	(3,875)
Issuance of common stock	11,101	10,298
Issuance of common units, net of issuance costs	0	275,098
Dividends paid	(258,508)	(252,416)
Distributions to noncontrolling interests	(275,259)	(260,488)
Cash provided by (used in) financing activities	(149,620)	374,851
Change in cash and cash equivalents	83,507	52,999
Change in cash and cash equivalents included in discontinued operations	(272)	382
Change in cash and cash equivalents from continuing operations	83,235	53,381
Cash and cash equivalents at beginning of period	97,619	172,812
Cash and cash equivalents at end of period	$ 180,854	$ 226,193

XML

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, 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	246,573	$ 0	0	0	137,305	0	109,268
Other comprehensive income (loss) (Note G)	(11,970)	$ 0	0	1,019	0	0	(12,989)
Common stock issued (in shares)		0
Common stock issued	12,350	$ 0	(4,300)	0	0	16,650	0
Common stock dividends - $1.23 and $1.21 per share (Note F)	(252,416)	0	0	0	(252,416)	0	0
Issuance of common units of ONEOK Partners (Note K)	258,548	0	26,294	0	0	0	232,254
Distributions to noncontrolling interests	(260,488)	0	0	0	0	0	(260,488)
Other	879	0	739	0	102	0	38
Stockholders' equity, ending balance at Jun. 30, 2015	3,999,359	$ 2,458	1,564,316	(135,334)	23,119	(937,051)	3,481,851
Common stock issued, ending balance (in shares) at Jun. 30, 2015		245,811,180
Stockholders' equity, beginning balance at Dec. 31, 2015	3,766,336	$ 2,458	1,378,444	(127,242)	0	(917,862)	3,430,538
Common stock issued, beginning balance (in shares) at Dec. 31, 2015		245,811,180
Net income	354,818	$ 0	0	0	169,390	0	185,428
Other comprehensive income (loss) (Note G)	(113,922)	$ 0	0	(32,004)	0	0	(81,918)
Common stock issued (in shares)		0
Common stock issued	15,462	$ 0	(2,034)	0	0	17,496	0
Common stock dividends - $1.23 and $1.21 per share (Note F)	(258,508)	0	(89,118)	0	(169,390)	0	0
Distributions to noncontrolling interests	(275,259)	0	0	0	0	0	(275,259)
Other	3,250	0	7,291	0	0	0	(4,041)
Stockholders' equity, ending balance at Jun. 30, 2016	$ 3,492,177	$ 2,458	$ 1,294,583	$ (159,246)	$ 0	$ (900,366)	$ 3,254,748
Common stock issued, ending balance (in shares) at Jun. 30, 2016		245,811,180

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CONSOLIDATED STATEMENT OF CHANGES IN EQUITY Parenthetical - $ / shares	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Mar. 31, 2016	Jun. 30, 2016	Jun. 30, 2015
Statement of Stockholders' Equity [Abstract]
Common Stock, Dividends, Per Share, Cash Paid	$ 0.615	$ 0.615	$ 1.230	$ 1.210

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

6 Months Ended

Jun. 30, 2016

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

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 statement of the results for the interim periods presented. All such adjustments are of a normal recurring nature. The 2015 year-end consolidated balance sheet data was derived from our audited financial statements but does not include all disclosures required by GAAP. Certain reclassifications have been made in the prior-year financial statements to conform to the current-year presentation. These unaudited consolidated financial statements should be read in conjunction with our audited consolidated financial statements in our Annual Report.

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

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

Consolidation - Our consolidated financial statements include our accounts and the accounts of our subsidiaries over which we have control or are the primary beneficiary. Management’s judgment is required when:

• determining whether an entity is a variable interest entity (VIE);

• determining whether we are the primary beneficiary of a VIE; and

• identifying events that require reconsideration of whether an entity is a VIE.

As a result of adopting ASU 2015-02 described below, we have concluded that ONEOK Partners is a VIE and that we are the primary beneficiary. Therefore, we continue to consolidate ONEOK Partners. See Note K for additional information.

We record noncontrolling interests in consolidated subsidiaries on our Consolidated Balance Sheets to recognize the portion of ONEOK Partners that we do not own. We reflect our ownership interest in ONEOK Partners’ accumulated other comprehensive income (loss) in our consolidated accumulated other comprehensive income (loss). The remaining portion is reflected as an adjustment to noncontrolling interests in consolidated subsidiaries.

Recently Issued Accounting Standards Update - 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 was effective for public companies for fiscal years beginning after December 15, 2015. We adopted this guidance in the first quarter 2016, and there was no impact, but it could impact us in the future if we complete any acquisitions with subsequent measurement period adjustments.

In May 2015, the FASB issued ASU 2015-07, “Fair Value Measurement (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent),” which removes the requirement to categorize within the fair value hierarchy all investments for which fair value is measured using the net asset value per share practical expedient. The amendment also removes the requirement to make certain disclosures for all investments that are eligible to be measured at fair value using the net asset value per share practical expedient. This guidance was effective for public companies for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. We adopted this guidance in the first quarter 2016. The impact of adopting this guidance was not material.

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 account for the arrangement as a service contract. This guidance was effective for public companies for fiscal years beginning after December 15, 2015. We adopted this guidance in the first quarter 2016. The impact of adopting this guidance was not material.

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 was effective for public companies for fiscal years beginning after December 15, 2015. We adopted this guidance in the first quarter 2016. As a result of adopting this guidance, we no longer consolidate ONEOK Partners under the presumption that a general partner should consolidate a limited partnership. We concluded, however, that ONEOK Partners is a VIE and ONEOK is the primary beneficiary, and we therefore consolidate ONEOK Partners under the variable interest model of consolidation. There was no financial statement impact due to the change in consolidation methodology. See Note K for additional information.

In June 2016, the FASB issued ASU 2016-13, “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments,” which requires a financial asset (or a group of financial assets) measured at amortized cost basis to be presented net of the allowance for credit losses to reflect the net carrying value at the amount expected to be collected on the financial asset; and the initial allowance for credit losses for purchased financial assets, including available-for-sale debt securities, to be added to the purchase price rather than being reported as a credit loss expense. This guidance is effective for public companies for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. Early adoption is permitted for the fiscal years beginning after December 15, 2018. We expect to adopt this guidance in the first quarter 2020, and we are evaluating the impact on us.

In March 2016, the FASB issued ASU 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting,” which provides simplified accounting for share-based payment transactions in relation to income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. This guidance is effective for public companies for annual periods beginning after December 15, 2016, and interim periods within those annual periods, with early adoption permitted. We expect to adopt this guidance in the first quarter 2017, and we are evaluating the impact on us.

In March 2016, the FASB issued ASU 2016-06, “Derivatives and Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments,” which clarifies the requirements for assessing whether a contingent call (put) option that can accelerate the payment of principal on a debt instrument is clearly and closely related to its debt host. Under the amendments in the update, assessments must be performed in accordance with the four-step decision sequence to conclude which call (put) options should be bifurcated and accounted for separately as derivatives. This guidance is effective for public companies for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years, with early adoption permitted. We expect to adopt this guidance in the first quarter 2017, and we are evaluating the impact on us.

In March 2016, the FASB issued ASU 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships,” which clarifies that a change in the counterparty to a derivative instrument that has been designated as the hedging instrument under Topic 815 does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge accounting criteria continue to be met. This guidance is effective for public companies for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. Early adoption is permitted. We expect to adopt this guidance in the first quarter 2017, and we are evaluating the impact on us.

In February 2016, the FASB issued ASU 2016-02, “Leases (Topic 842),” which requires the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases under previous GAAP. It also requires qualitative disclosures along with specific quantitative disclosures by lessees and lessors to meet the objective of enabling users of financial statements to assess the amount, timing and uncertainty of cash flows arising from leases. This guidance is effective for public companies for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early adoption is permitted. We expect to adopt this guidance in the first quarter 2019, and we are evaluating the impact on us.

In January 2016, the FASB issued ASU 2016-01, “Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities,” which requires all equity investments other than those accounted for using the equity method of accounting or those that result in consolidation of the investee to be measured at fair value with changes in fair value recognized in net income, eliminates the available-for-sale classification for equity securities with readily determinable fair values and eliminates the cost method for equity investments without readily determinable fair values. Additionally, this guidance eliminates the requirement to disclose the methods and significant assumptions used to estimate the fair value of financial instruments carried at amortized cost and requires the use of the exit price when measuring the fair value of such instruments for disclosure purposes. This guidance will be effective for public companies in fiscal years beginning after December 15, 2017, including interim periods within those fiscal years. Early adoption is only permitted for certain portions of the ASU. We expect to adopt this guidance in the first quarter 2018, and we are evaluating the impact on us.

In July 2015, the FASB issued ASU 2015-11, “Inventory (Topic 330): Simplifying the Measurement of Inventory,” which requires that inventory, excluding inventory measured using last-in, first-out (LIFO) or the retail inventory method, be measured at the lower of cost or net realizable value. This guidance will be effective for public companies for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. We expect to adopt this guidance in the first quarter 2017, and we are evaluating the impact on us.

In August 2014, the FASB issued ASU 2014-15, “Presentation of Financial Statements - Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a 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 (Topic 606),” 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. The FASB has issued additional ASUs, which provide further guidance and clarification on implementation issues. We expect to adopt this guidance beginning in the first quarter 2018, and we are evaluating the impact on us.

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FAIR VALUE MEASUREMENTS

6 Months Ended

Jun. 30, 2016

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

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 our 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 derivatives by discounting the projected future cash flows from the derivative assets and liabilities to present value using interest-rate yields to calculate present-value discount factors derived from LIBOR, Eurodollar futures and the LIBOR interest-rate swaps market. 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 executed derivative contracts , the ultimate market prices realized could differ from our estimates, and the differences could be material.

The fair value of 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-rate 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 internally developed 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 the periods indicated:

	June 30, 2016
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Derivative assets
Commodity contracts
Financial contracts	$	13,966		$	—		$	3,205		$	17,171		$	(10,970	)	$	6,201
Physical contracts	—			—			68			68			—			68
Total derivative assets	$	13,966		$	—		$	3,273		$	17,239		$	(10,970	)	$	6,269
Derivative liabilities
Commodity contracts
Financial contracts	$	(15,352	)	$	—		$	(12,365	)	$	(27,717	)	$	27,717		$	—
Physical contracts	—			—			(4,929		)	(4,929		)	—			(4,929		)
Interest-rate contracts	—			(70,111		)	—			(70,111		)	—			(70,111		)
Total derivative liabilities	$	(15,352	)	$	(70,111	)	$	(17,294	)	$	(102,757	)	$	27,717		$	(75,040	)

(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 us. At June 30, 2016, we had no cash held and posted $33.5 million of cash with various counterparties, including $16.7 million of cash collateral that is offsetting derivative net liability positions under master-netting arrangements in the table above. The remaining $16.8 million of cash collateral in excess of derivative net liability positions is included in other current assets in our Consolidated Balance Sheets.

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

	December 31, 2015
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Derivative assets
Commodity contracts
Financial contracts	$	38,921		$	—		$	7,253		$	46,174		$	(42,414	)	$	3,760
Physical contracts	—			—			3,591			3,591			—			3,591
Total derivative assets	$	38,921		$	—		$	10,844		$	49,765		$	(42,414	)	$	7,351
Derivative liabilities
Commodity contracts
Financial contracts	$	(4,513	)	$	—		$	(3,513	)	$	(8,026	)	$	8,026		$	—
Interest-rate contracts	—			(9,936		)	—			(9,936		)	—			(9,936		)
Total derivative liabilities	$	(4,513	)	$	(9,936	)	$	(3,513	)	$	(17,962	)	$	8,026		$	(9,936	)

(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 us. At December 31, 2015, we held $34.4 million of cash from various counterparties that is offsetting derivative net asset positions in the table above under master-netting arrangements and had no cash collateral posted.

(b) - Included in other current 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 the periods indicated:

	Three Months Ended						Six Months Ended
	June 30,						June 30,
Derivative Assets (Liabilities)	2016			2015			2016			2015
	(Thousands of dollars)
Net assets at beginning of period	$	34		$	7,040		$	7,331		$	9,285
Total realized/unrealized gains (losses):
Included in earnings (a)	318			(159		)	(427		)	110
Included in other comprehensive income (loss)	(14,373		)	3,506			(20,925		)	992
Net assets (liabilities) at end of period	$	(14,021	)	$	10,387		$	(14,021	)	$	10,387

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

Realized/unrealized gains (losses) include the realization of derivative contracts through maturity. During the three and six months ended June 30, 2016 and 2015, 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 six months ended June 30, 2016 and 2015, there were no transfers between levels.

Other Financial Instruments -The approximate fair value of cash and cash equivalents, accounts receivable, accounts payable and short-term borrowings 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 short-term borrowings are classified as Level 2 since the estimated fair value of the short-term borrowings 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 $9.0 billion and $7.4 billion at June 30, 2016, and December 31, 2015, respectively. The book value of our consolidated long-term debt, including current maturities, was $8.8 billion and $8.4 billion at June 30, 2016, and December 31, 2015, 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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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

6 Months Ended

Jun. 30, 2016

Derivatives, Fair Value [Line Items]

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

RISK-MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

Risk-Management Activities - We are 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. We use 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 commodity price and interest-rate fluctuations; and to achieve more predictable cash flows. We follow established policies and procedures to assess risk and approve, monitor and report risk-management activities. We have not used these instruments for trading purposes. We 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. We use 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;

• 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; and

• Options - 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.

We may also use other instruments including collars to mitigate commodity price risk. 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 as a portion of its compensation for services associated with its POP with fee contracts. Under certain POP with fee contracts, ONEOK Partners’ fee revenues may increase or decrease if production volumes, delivery pressures or commodity prices change relative to specified thresholds. The Natural Gas Gathering and Processing segment also is exposed to basis risk between the various production and market locations where it receives and sells commodities. As part of our hedging strategy, we use 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. The Natural Gas Liquids segment also is 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. We utilize 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, our 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, we use physical-forward sales or purchases to reduce the impact of price fluctuations related to natural gas. At June 30, 2016, and December 31, 2015, there were no financial derivative instruments with respect to ONEOK Partners’ natural gas pipeline operations.

Interest-rate risk - We 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. As of June 30, 2016, ONEOK Partners had interest-rate swaps with notional amounts totaling $1.0 billion to hedge the variability of ONEOK Partners’ LIBOR-based interest payments. In June 2016, ONEOK Partners entered into forward-starting interest-rate swaps with notional amounts totaling $750 million to hedge the variability of interest payments on a portion of its forecasted debt issuances that may result from changes in the benchmark interest rate before the debt is issued. At June 30, 2016, and December 31, 2015, ONEOK Partners had forward-starting interest-rate swaps with notional amounts totaling $1.2 billion and $400 million, respectively, to hedge the variability of interest payments on a portion of its forecasted debt issuances. All of ONEOK Partners’ interest-rate swaps are designated as cash flow hedges.

Accounting Treatment -All derivative instruments are recorded 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 our exposure to fluctuations in natural gas, NGLs and condensate prices, we periodically enter 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, these derivative instruments are designated as a hedge of exposure to changes in fair values or cash flows. All relationships between hedging instruments and hedged items are formally documented, as well as risk-management objectives and strategies for undertaking various hedge transactions, and methods for assessing and testing correlation and hedge ineffectiveness. The forecasted transaction that has been designated as the hedged item in a cash flow hedge relationship is specifically identified. The effectiveness of hedging relationships are assessed quarterly by performing an effectiveness analysis on the fair value and cash flow hedging relationships to determine whether the hedge relationships are highly effective on a retrospective and prospective basis. Normal purchases and normal sales transactions that are expected to result in physical delivery and, through election, are exempt from derivative accounting treatment are also documented.

The realized revenues and purchase costs of 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 B for a discussion of the inputs associated with our fair value measurements. The following table sets forth the fair values of derivative instruments for the periods indicated:

	June 30, 2016					December 31, 2015
	Assets (a)		(Liabilities) (a)			Assets (b)		(Liabilities) (b)
	(Thousands of dollars)
Derivatives designated as hedging instruments
Commodity contracts
Financial contracts	$	14,591	$	(25,028	)	$	39,255	$	(1,440	)
Physical contracts	68		(4,929		)	3,591		—
Interest-rate contracts	—		(70,111		)	—		(9,936		)
Total derivatives designated as hedging instruments	14,659		(100,068		)	42,846		(11,376		)
Derivatives not designated as hedging instruments
Commodity contracts
Financial contracts	2,580		(2,689		)	6,919		(6,586		)
Total derivatives not designated as hedging instruments	2,580		(2,689		)	6,919		(6,586		)
Total derivatives	$	17,239	$	(102,757	)	$	49,765	$	(17,962	)

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

(b) - Included on a net basis in other current 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 held for the periods indicated:

		June 30, 2016					December 31, 2015
	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	—		(41.2		)	—		(27.1		)
- Natural gas (Bcf)	Put options	89.7		—			—		—
- Crude oil and NGLs (MMBbl)	Futures, forwards and swaps	—		(5.5		)	—		(2.3		)
- Propane (MMBbl)	Put options	1.5		—			—		—
Basis
- Natural gas (Bcf)	Futures and swaps	—		(41.2		)	—		(27.1		)
Interest-rate contracts (Millions of dollars)	Swaps	$	2,150.0	$	—		$	400.0	$	—
Derivatives not designated as hedging instruments:
Fixed price
- NGLs (MMBbl)	Futures, forwards and swaps	0.8		(1.0		)	0.6		(0.6		)

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 actual exposure to market or credit risk.

Cash Flow Hedges - At June 30, 2016, our Consolidated Balance Sheet reflected a net loss of $159.2 million in accumulated other comprehensive loss. The portion of accumulated other comprehensive loss attributable to commodity derivative financial instruments is an unrealized loss of $8.8 million, net of tax, which will be realized within the next 18 months as the forecasted transactions affect earnings. If commodity prices remain at current levels, we will realize approximately $5.8 million in net losses over the next 12 months and approximately $3.0 million in net losses thereafter. The amount deferred in accumulated other comprehensive loss attributable to settled interest-rate swaps is a loss of $47.0 million, net of tax, which will be recognized over the life of the long-term, fixed-rate debt, including losses of $6.3 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 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 the 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					Six Months Ended
	June 30,					June 30,
	2016			2015		2016			2015
	(Thousands of dollars)
Commodity contracts	$	(58,654	)	$	1,072	$	(46,976	)	$	11,091
Interest-rate contracts	(28,564		)	16,909		(60,175		)	(5,667		)
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	$	(87,218	)	$	17,981	$	(107,151	)	$	5,424

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 Loss into Net Income (Effective Portion)	Three Months Ended						Six Months Ended
		June 30,						June 30,
		2016			2015			2016			2015
		(Thousands of dollars)
Commodity contracts	Commodity sales revenues	$	14,049		$	17,078		$	28,548		$	31,250
Interest-rate contracts	Interest expense	(4,802		)	(4,598		)	(9,500		)	(8,315		)
Total gain (loss) reclassified from accumulated other comprehensive loss into net income on derivatives (effective portion)		$	9,247		$	12,480		$	19,048		$	22,935

Ineffectiveness related to our cash flow hedges for the three and six months ended June 30, 2016 and 2015, was not material. 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 six months ended June 30, 2016 and 2015, there were no gains or losses due to the discontinuance of cash flow hedge treatment.

Credit Risk - We monitor the creditworthiness of our counterparties and compliance with policies and limits established by our Risk Oversight and Strategy Committee. We maintain credit policies with regard to our 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. We have counterparties whose credit is not rated, and for those customers, we use internally developed credit ratings.

From time to time, ONEOK Partners may enter into financial derivative instruments that 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 at June 30, 2016.

The counterparties to our derivative contracts consist primarily of major energy companies, financial institutions and commercial and industrial end users. This concentration of counterparties may affect our 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 our 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 June 30, 2016, the net credit exposure from our derivative assets is primarily with investment-grade companies in the financial services sector.

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SHORT-TERM BORROWINGS (Notes)

6 Months Ended

Jun. 30, 2016

Short-term Debt [Abstract]

SHORT-TERM BORROWINGS

SHORT-TERM BORROWINGS

ONEOK Credit Agreement - In January 2016, we extended the term of the ONEOK Credit Agreement by one year to January 2020. 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 June 30, 2016, ONEOK’s ratio of indebtedness to Consolidated EBITDA was 2.2 to 1, and ONEOK was in compliance with all covenants under the ONEOK Credit Agreement.

The ONEOK Credit Agreement 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 interest at LIBOR plus 145 basis points, and the annual facility fee is 30 basis points.

At June 30, 2016, ONEOK had $1.1 million in letters of credit issued and no borrowings under the ONEOK Credit Agreement.

ONEOK Partners Credit Agreement - In January 2016, ONEOK Partners extended the term of the ONEOK Partners Credit Agreement by one year to January 2020. The ONEOK Partners Credit Agreement 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.

ONEOK Partners had $14 million of letters of credit issued, no borrowings outstanding and approximately $1.8 billion capacity available at June 30, 2016, 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. 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 June 30, 2016, ONEOK Partners’ ratio of indebtedness to adjusted EBITDA was 4.2 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.

ONEOK Partners Commercial Paper Program -At June 30, 2016, ONEOK Partners had $576 million of commercial paper outstanding under its $2.4 billion commercial paper program with weighted-average interest rates of 1.17 percent. Amounts outstanding under ONEOK Partners’ commercial paper program reduce the borrowing capacity under the ONEOK Partners Credit Agreement.

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LONG-TERM DEBT

6 Months Ended

Jun. 30, 2016

Long-term Debt, Unclassified [Abstract]

LONG-TERM DEBT

LONG-TERM DEBT

The following table sets forth our long-term debt for the periods indicated:

	June 30,			December 31,
	2016			2015
	(Thousands of dollars)
ONEOK
$700,000 at 4.25% due 2022	$	547,397		$	547,397
$500,000 at 7.5% due 2023	500,000			500,000
$100,000 at 6.5% due 2028	87,190			87,516
$100,000 at 6.875% due 2028	100,000			100,000
$400,000 at 6.0% due 2035	400,000			400,000
Total ONEOK senior notes payable	1,634,587			1,634,913
ONEOK Partners
$650,000 at 3.25% due 2016	—			650,000
$450,000 at 6.15% due 2016	450,000			450,000
$400,000 at 2.0% due 2017	400,000			400,000
$425,000 at 3.2% due 2018	425,000			425,000
$1,000,000 term loan, variable rate, due 2019	1,000,000			—
$500,000 at 8.625% due 2019	500,000			500,000
$300,000 at 3.8% due 2020	300,000			300,000
$900,000 at 3.375% due 2022	900,000			900,000
$425,000 at 5.0% due 2023	425,000			425,000
$500,000 at 4.9% due 2025	500,000			500,000
$600,000 at 6.65% due 2036	600,000			600,000
$600,000 at 6.85% due 2037	600,000			600,000
$650,000 at 6.125% due 2041	650,000			650,000
$400,000 at 6.2% due 2043	400,000			400,000
Guardian Pipeline
Average 7.85% due 2022	48,082			51,907
Total ONEOK Partners long-term debt	7,198,082			6,851,907
Total long-term debt	8,832,669			8,486,820
Unamortized portion of terminated swaps	21,045			21,904
Unamortized debt issuance costs and discounts	(72,787		)	(74,492		)
Current maturities	(460,650		)	(110,650		)
Long-term debt, excluding current maturities	$	8,320,277		$	8,323,582

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.

ONEOK Partners Debt Issuances and Maturities - In January 2016, ONEOK Partners entered into the $1.0 billion senior unsecured delayed-draw Term Loan Agreement with a syndicate of banks. The Term Loan Agreement matures in January 2019 and bears interest at LIBOR plus a margin that is based on the credit ratings assigned to ONEOK Partners’ senior, unsecured, long-term indebtedness. Based on ONEOK Partners’ current applicable credit rating, borrowings on the Term Loan Agreement accrue at LIBOR plus 130 basis points. At June 30, 2016 the interest rate was 1.74 percent. The Term Loan Agreement contains an option, which may be exercised up to two times, to extend the term of the loan, in each case, for an additional one-year term, subject to approval of the banks. The Term Loan Agreement allows prepayment of all or any portion outstanding without penalty or premium and contains substantially the same covenants as the ONEOK Partners Credit Agreement. During the first quarter 2016, ONEOK Partners drew the full $1.0 billion available under the agreement and used the proceeds to repay its $650 million, 3.25 percent senior notes, to repay amounts outstanding under its commercial paper program and for general partnership purposes. At June 30, 2016, ONEOK Partners’ $450 million, 6.15 percent senior notes due October 1, 2016, are reflected in current maturities of long-term debt in our Consolidated Balance Sheet.

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.

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EQUITY

6 Months Ended

Jun. 30, 2016

Equity [Abstract]

Stockholders' Equity Note Disclosure [Text Block]

EQUITY

Dividends -Dividends paid on our common stock to shareholders of record at the close of business on February 1, 2016, and May 2, 2016, were $0.615 per share in each instance. A dividend of $0.615 per share was declared for shareholders of record at the close of business on August 8, 2016, payable August 14, 2016.

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

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

6 Months Ended

Jun. 30, 2016

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

ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

ACCUMULATED OTHER COMPREHENSIVE LOSS

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

	Unrealized Gains (Losses) on Risk- Management Assets/Liabilities (a)			Pension and Postretirement Benefit Plan Obligations (a) (b)			Unrealized Gains (Losses) on Risk- Management Assets/Liabilities of Unconsolidated Affiliates (a)			Accumulated Other Comprehensive Loss (a)
	(Thousands of dollars)
January 1, 2016	$	(42,199	)	$	(84,543	)	$	(500	)	$	(127,242	)
Other comprehensive income (loss) before reclassifications	(27,813		)	6			(2,950		)	(30,757		)
Amounts reclassified from accumulated other comprehensive loss	(4,346		)	3,099			—			(1,247		)
Net current period other comprehensive income (loss) attributable to ONEOK	(32,159		)	3,105			(2,950		)	(32,004		)
June 30, 2016	$	(74,358	)	$	(81,438	)	$	(3,450	)	$	(159,246	)

(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 loss in our Consolidated Statements of Income for the periods indicated:

Details about Accumulated Other Comprehensive Loss Components	Three Months Ended						Six Months Ended						Affected Line Item in the Consolidated Statements of Income
	June 30,						June 30,
	2016			2015			2016			2015
	(Thousands of dollars)
Unrealized gains (losses) on risk-management assets/liabilities
Commodity contracts	$	14,049		$	17,078		$	28,548		$	31,250		Commodity sales revenues
Interest-rate contracts	(4,802		)	(4,598		)	(9,500		)	(8,315		)	Interest expense
	9,247			12,480			19,048			22,935			Income before income taxes
	(1,193		)	(1,439		)	(2,469		)	(2,664		)	Income tax expense
	8,054			11,041			16,579			20,271			Net income
Noncontrolling interests	5,953			8,523			12,233			15,595			Less: Net income attributable to noncontrolling interests
	$	2,101		$	2,518		$	4,346		$	4,676		Net income attributable to ONEOK
Pension and postretirement benefit plan obligations (a)
Amortization of net loss	$	(2,997	)	$	(4,423	)	$	(5,995	)	$	(8,846	)
Amortization of unrecognized prior service cost	415			392			830			784
	(2,582		)	(4,031		)	(5,165		)	(8,062		)	Income before income taxes
	1,033			1,613			2,066			3,225			Income tax expense
	$	(1,549	)	$	(2,418	)	$	(3,099	)	$	(4,837	)	Net income attributable to ONEOK
Total reclassifications for the period attributable to ONEOK	$	552		$	100		$	1,247		$	(161	)	Net income attributable to ONEOK

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

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EARNINGS PER SHARE

6 Months Ended

Jun. 30, 2016

Earnings Per Share [Abstract]

EARNINGS PER SHARE

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 June 30, 2016
	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	$	86,171	211,075	$	0.41
Diluted EPS from continuing operations
Effect of dilutive securities	—		1,543
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	86,171	212,618	$	0.41

	Three Months Ended June 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	$	76,645	210,204	$	0.36
Diluted EPS from continuing operations
Effect of dilutive securities	—		273
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	76,645	210,477	$	0.36

	Six Months Ended June 30, 2016
	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	$	170,569	210,928	$	0.81
Diluted EPS from continuing operations
Effect of dilutive securities	—		735
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	170,569	211,663	$	0.81

	Six Months Ended June 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	$	137,589	210,059	$	0.65
Diluted EPS from continuing operations
Effect of dilutive securities	—		427
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	137,589	210,486	$	0.65

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EMPLOYEE BENEFIT PLANS

6 Months Ended

Jun. 30, 2016

Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]

EMPLOYEE BENEFIT PLANS

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						Six Months Ended
	June 30,						June 30,
	2016			2015			2016			2015
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	1,622		$	1,887		$	3,244		$	3,774
Interest cost	4,947			4,546			9,894			9,092
Expected return on assets	(5,077		)	(5,213		)	(10,154		)	(10,426		)
Amortization of unrecognized prior service cost	—			23			—			46
Amortization of net loss	2,736			3,987			5,473			7,974
Net periodic benefit cost	$	4,228		$	5,230		$	8,457		$	10,460

	Postretirement Benefits
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2016			2015			2016			2015
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	149		$	186		$	298		$	372
Interest cost	601			587			1,202			1,173
Expected return on assets	(531		)	(564		)	(1,062		)	(1,128		)
Amortization of unrecognized prior service cost	(415		)	(415		)	(830		)	(830		)
Amortization of net loss	261			436			522			872
Net periodic benefit cost	$	65		$	230		$	130		$	459

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UNCONSOLIDATED AFFILIATES

6 Months Ended

Jun. 30, 2016

Equity Method Investments and Joint Ventures [Abstract]

UNCONSOLIDATED AFFILIATES

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				Six Months Ended
	June 30,				June 30,
	2016		2015		2016		2015
	(Thousands of dollars)
Northern Border Pipeline	$	15,723	$	15,273	$	34,397	$	34,975
Overland Pass Pipeline Company	13,608		9,623		26,912		16,510
Other	3,041		5,144		3,977		9,476
Equity in net earnings from investments	$	32,372	$	30,040	$	65,286	$	60,961

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				Six Months Ended
	June 30,				June 30,
	2016		2015		2016		2015
	(Thousands of dollars)
Income Statement
Operating revenues	$	142,631	$	125,738	$	279,203	$	255,319
Operating expenses	$	66,674	$	55,959	$	125,373	$	113,538
Net income	$	69,420	$	62,643	$	141,457	$	129,002
Distributions paid to ONEOK Partners	$	62,024	$	41,354	$	108,577	$	80,783

ONEOK Partners incurred expenses in transactions with unconsolidated affiliates of $34.7 million and $25.9 million for the three months ended June 30, 2016 and 2015, respectively, and $68.3 million and $45.8 million for the six months ended June 30, 2016 and 2015, respectively, primarily related to Overland Pass Pipeline Company and Northern Border Pipeline. Accounts payable to ONEOK Partners’ equity-method investees at June 30, 2016, and December 31, 2015, were $12.2 million and $8.0 million, respectively.

Northern Border Pipeline -The Northern Border Pipeline partnership agreement provides that distributions to Northern Border Pipeline’s partners are to be made on a pro rata basis according to each partner’s percentage interest. The Northern Border Pipeline Management Committee determines the amount and timing of such distributions. Any changes to, or suspension of, the cash distribution policy of Northern Border Pipeline requires the unanimous approval of the Northern Border Pipeline Management Committee. Cash distributions are equal to 100 percent of distributable cash flow as determined from Northern Border Pipeline’s financial statements based upon EBITDA, less interest expense and maintenance capital expenditures. Loans or other advances from Northern Border Pipeline to its partners or affiliates are prohibited under its credit agreement.

Overland Pass Pipeline Company - The Overland Pass Pipeline Company limited liability company agreement provides that distributions to Overland Pass Pipeline Company’s members are to be made on a pro rata basis according to each member’s percentage interest. The Overland Pass Pipeline Company Management Committee determines the amount and timing of such distributions. Any changes to, or suspension of, the cash distributions from Overland Pass Pipeline Company requires the unanimous approval of the Overland Pass Pipeline Company Management Committee. Cash distributions are equal to 100 percent of available cash as defined in the limited liability company agreement.

Roadrunner Gas Transmission - In March 2015, ONEOK Partners entered into a 50-50 joint venture 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 six months ended June 30, 2016, ONEOK Partners made contributions of approximately $20 million to Roadrunner, and expects to contribute approximately $45 million to Roadrunner during the remainder of 2016.

The Roadrunner limited liability company agreement provides that distributions to members are made on a pro rata basis according to each member’s ownership interest. The Roadrunner Management Committee determines the amount and timing of such distributions. Any changes to, or suspension of, the cash distributions from Roadrunner requires approval of the Roadrunner Management Committee. Voting rights for the Roadrunner Management Committee are allocated on a pro rata basis according to each member’s ownership interest. Cash distributions are equal to 100 percent of available cash, as defined in the limited liability company agreement.

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ONEOK PARTNERS

6 Months Ended

Jun. 30, 2016

Related Party Transactions [Abstract]

ONEOK PARTNERS

ONEOK PARTNERS

Ownership Interestin ONEOK Partners - Our ownership interest in ONEOK Partners is shown in the table below at June 30, 2016:

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.

Consolidation - We determined ONEOK Partners is a VIE due to the limited partners’ lack of substantive voting rights under the Partnership Agreement. Substantive voting rights under a master limited partnership are either kick-out rights or participating rights, as defined by FASB Accounting Standards Codification 810-10, that can be exercised with a simple majority of the vote of the limited partners. Prior to the adoption of ASU 2015-02, ONEOK Partners was not considered a VIE and was consolidated by us under the presumption that a general partner consolidates its limited partnership. See Note A for more information on ASU 2015-02.

We have determined that we are the primary beneficiary of ONEOK Partners as we have the power, through our general partner interest, to direct the operations of ONEOK Partners that impact its economic performance and the right to receive the benefits of ONEOK Partners through our general partner and limited partner interests. These interests are significant due to our 41.2 percent ownership interest in ONEOK Partners, the largest ownership interest by an individual entity, and our incentive distribution rights.

As we are the primary beneficiary of ONEOK Partners, 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 from ONEOK Partners. Distributions are declared quarterly by the board of ONEOK Partners’ general partner based on the terms of the Partnership Agreement. See Note N for more information on ONEOK Partners’ results.

The following table shows the carrying amount and classification of ONEOK Partners’ assets and liabilities in our Consolidated Balance Sheets:

	June 30,		December 31,
	2016		2015
	(Thousands of dollars)
Assets
Total current assets	$	1,096,107	$	883,164
Net property, plant and equipment	12,372,176		12,256,791
Total investments and other assets	1,749,593		1,787,631
Total assets	$	15,217,876	$	14,927,586
Liabilities
Total current liabilities	$	2,140,793	$	1,580,300
Long-term debt, excluding current maturities	6,691,950		6,695,312
Total deferred credits and other liabilities	183,200		154,631
Total liabilities	$	9,015,943	$	8,430,243

ONEOK receives distributions from ONEOK Partners through its general partner and limited partner interests, but otherwise the assets of ONEOK Partners cannot be used to settle obligations of ONEOK. ONEOK does not guarantee the debt, commercial paper or other similar commitments of ONEOK Partners, and the obligations of ONEOK Partners may only be settled using the assets of ONEOK Partners. ONEOK Partners does not guarantee the debt or other similar commitments of ONEOK.

Equity Issuances -In August 2015, ONEOK Partners completed the sale to us in a private placement of 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 proceeds of approximately $749 million. 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.

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 June 30, 2016, ONEOK Partners had approximately $138 million of registered common units available for issuance through its “at-the-market” equity program.

During the three and six months ended June 30, 2016, no common units were sold through ONEOK Partners’ “at-the-market” equity program.

During the three months ended June 30, 2015, ONEOK Partners sold 5.5 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 $208.1 million, which were used for general partnership purposes, including repayment of commercial paper borrowings.

During the six months ended June 30, 2015, ONEOK Partners sold 7.2 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 $279.7 million, which were used for general partnership purposes, including repayment of commercial paper borrowings.

During the year ended December 31, 2015, ONEOK Partners sold 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 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.

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.

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 July 2016, a cash distribution of $0.79 per unit ($3.16 per unit on an annualized basis) was declared for the second quarter 2016 and will be paid on August 14, 2016, to unitholders of record at the close of business on August 8, 2016.

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2016		2015		2016		2015
	(Thousands, except per unit amounts)
Distribution per unit	$	0.79	$	0.79	$	1.58	$	1.58
General partner distributions	$	6,660	$	5,955	$	13,320	$	11,869
Incentive distributions	100,538		89,889		201,076		179,168
Distributions to general partner	107,198		95,844		214,396		191,037
Limited partner distributions to ONEOK	90,323		73,302		180,646		146,604
Limited partner distributions to noncontrolling interest	135,479		128,583		270,959		255,794
Total distributions paid	$	333,000	$	297,729	$	666,001	$	593,435

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2016		2015		2016		2015
	(Thousands, except per unit amounts)
Distribution per unit	$	0.79	$	0.79	$	1.58	$	1.58
General partner distributions	$	6,660	$	6,081	$	13,320	$	12,036
Incentive distributions	100,538		91,794		201,076		181,683
Distributions to general partner	107,198		97,875		214,396		193,719
Limited partner distributions to ONEOK	90,323		73,302		180,646		146,604
Limited partner distributions to noncontrolling interest	135,479		132,862		270,959		261,445
Total distributions declared	$	333,000	$	304,039	$	666,001	$	601,768

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. For the three months ended June 30, 2016 and 2015, $100.8 million and $86.7 million, respectively, of ONEOK Partners’ operating expenses were incurred with us. For the six months ended June 30, 2016 and 2015, $189.9 million and $176.3 million, respectively, of ONEOK Partners’ operating expenses were incurred with us.

ONEOK Partners has an operating agreement with Roadrunner, that provides for reimbursement or payment to it for management services and certain operating costs. Charges to Roadrunner included in operating income in our Consolidated Statements of Income for the three and six months ended June 30, 2016 and 2015, were not material.

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COMMITMENTS AND CONTINGENCIES

6 Months Ended

Jun. 30, 2016

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES

Environmental Matters and Pipeline Safety - The operation of pipelines, plants and other facilities for the gathering, processing, transportation and storage of natural gas, NGLs, condensate and other products is subject to numerous and complex laws and regulations pertaining to health, safety and the environment. As an owner and/or operator of these facilities, ONEOK Partners must comply with United States laws and regulations at the federal, state and local levels that relate to air and water quality, hazardous and solid waste management and disposal, and other environmental matters. The cost of planning, designing, constructing and operating pipelines, plants and other facilities must incorporate compliance with environmental laws and regulations and safety standards. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and potentially criminal enforcement measures, including citizen suits, which can include the assessment of monetary penalties, the imposition of remedial requirements and the issuance of injunctions or restrictions on operation. Management believes that, based on currently known information, compliance with these laws and regulations will not have a material adverse effect on our or ONEOK Partners’ results of operations, financial condition or cash flows.

Legal Proceedings -Gas Index Pricing Litigation - In May 2016, the United States District Court for the District of Nevada (“the Court”) entered an order granting summary judgment in favor of us and our affiliate ONEOK Energy Services Company, L.P. (“OESC”) in Reorganized FLI, Inc. previously reported in our Annual Report. The Court determined that the plaintiff’s claim is barred by a release obtained in a prior lawsuit against us and OESC. Upon entry of a final judgment,Reorganized FLI, Inc. may pursue an appeal of this determination to the Ninth Circuit Court of Appeals.

In March 2016, we reached an agreement in principle to settle the claims alleged against us and our affiliates, OESC and Kansas Gas Marketing Company, in the following putative class action lawsuits, previously reported in our Annual Report, that claimed damages resulting from alleged market manipulation or false reporting of prices to gas index publications by us and others: Learjet, Arandell, HeartlandRegional Medical Center, and NewPage. The amount we expect to pay to settle these cases is not material to our results of operations, financial position or cash flows and is expected to be paid with cash on hand.

This agreement in principle to settle does not apply to the Sinclair case, previously reported in our Annual Report. We expect that future charges, if any, from the ultimate resolution of these matters will not be material to our results of operations, financial position or cash flows.

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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DISCONTINUED OPERATIONS

6 Months Ended

Jun. 30, 2016

Discontinued Operations [Abstract]

DISCONTINUED OPERATIONS

DISCONTINUED OPERATIONS

In 2014, we completed the wind down of our former energy services business. We executed agreements to release a significant portion of our nonaffiliated natural gas transportation and storage contracts to third parties that resulted in noncash charges.

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

	Six Months Ended
	June 30,
	2016			2015
	(Millions of dollars)
Beginning balance	$	36.3		$	73.8
Settlements	(11.6		)	(22.4		)
Accretion	0.3			0.6
Ending balance	$	25.0		$	52.0

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 $25 million, which consists of approximately $7 million to be paid in the remainder of 2016, $10 million in 2017, $4 million in 2018 and $4 million over the period 2019 through 2023.

Results of Operations of Discontinued Operations - The results of operations for our former 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 six months ended June 30, 2016 and 2015, includes accretion expense, net of tax benefit, on the released contracts for our former energy services business.

Statement of Financial Position of Discontinued Operations - At June 30, 2016, and December 31, 2015, 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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SEGMENTS

6 Months Ended

Jun. 30, 2016

Segment Reporting [Abstract]

SEGMENTS

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 -The accounting policies of the segments are described in Note A of the Notes to Consolidated Financial Statements in our Annual Report. Our chief operating decision maker reviews the financial performance of each of the three segments of ONEOK Partners, as well as our financial performance, on a regular basis. Beginning in 2016, adjusted EBITDA by segment, a non-GAAP financial measure, is utilized in this evaluation. We believe this non-GAAP financial measure is useful to investors because it is used by many companies in our industry as a measurement of financial performance and is commonly employed by financial analysts and others to evaluate our financial performance and to compare our financial performance with the performance of other publicly traded partnerships within our industry. Adjusted EBITDA is defined as net income adjusted for interest expense, depreciation and amortization, noncash impairment charges, income taxes and AFUDC and other noncash items. Adjusted EBITDA should not be considered an alternative to net income, earnings per unit or any other measure of financial performance presented in accordance with GAAP. Additionally, this calculation may not be comparable with similarly titled measures of other companies. Prior period segment disclosures have been recast to reflect this change.

Customers -The primary customers of the Natural Gas Gathering and Processing segment are crude oil and natural gas producers, which include both large integrated and independent exploration and production companies. The Natural Gas Liquids segment’s customers are primarily NGL and natural gas gathering and processing companies; large integrated 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 are primarily local natural gas distribution companies, electric-generation companies, large industrial companies, municipalities, irrigation customers and marketing companies.

For the three months ended June 30, 2016, ONEOK Partners had no single customer from which it received 10 percent or more of our consolidated revenues. For the three months ended June 30, 2015, and the six months ended June 30, 2016, and June 30, 2015, ONEOK Partners had one customer, BP p.l.c. or its affiliates, from which it received $224.6 million, $396.5 million and $409.5 million, respectively, in total revenues from all of its operating segments, or approximately 11 percent, 10 percent and 10 percent of our consolidated revenues, respectively.

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

Three Months Ended June 30, 2016	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)		Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	293,071		$	1,754,122		$	86,401	$	513		$	2,134,107
Intersegment revenues	183,688			117,871			1,668		(303,227		)	—
Total revenues	476,759			1,871,993			88,069		(302,714		)	2,134,107
Cost of sales and fuel (exclusive of items shown separately below)	299,991			1,525,234			5,112		(303,014		)	1,527,323
Operating costs	69,304			83,769			29,189		9,577			191,839
Depreciation and amortization	46,413			40,696			11,398		740			99,247
(Gain) loss on sale of assets	(240		)	(71		)	725		(1		)	413
Operating income	$	61,291		$	222,365		$	41,645	$	(10,016	)	$	315,285
Equity in net earnings from investments	$	2,576		$	13,904		$	15,892	$	—		$	32,372
Capital expenditures	$	84,674		$	20,779		$	29,278	$	2,112		$	136,843

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $297.5 million, of which $258.4 million related to sales within the segment, cost of sales and fuel of $112.7 million and operating income of $120.8 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $56.6 million, cost of sales and fuel of $5.7 million and operating income of $23.8 million.

Three Months Ended June 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	$	279,498		$	1,769,580	$	78,429	$	545		$	2,128,052
Intersegment revenues	180,564			79,295		1,683		(261,542		)	—
Total revenues	460,062			1,848,875		80,112		(260,997		)	2,128,052
Cost of sales and fuel (exclusive of items shown separately below)	322,927			1,535,492		6,005		(261,331		)	1,603,093
Operating costs	63,550			77,410		25,240		(850		)	165,350
Depreciation and amortization	35,952			39,433		10,814		788			86,987
(Gain) loss on sale of assets	(195		)	73		—		—			(122		)
Operating income	$	37,828		$	196,467	$	38,053	$	396		$	272,744
Equity in net earnings from investments	$	4,922		$	9,693	$	15,425	$	—		$	30,040
Capital expenditures	$	205,434		$	59,087	$	15,613	$	5,467		$	285,601

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $227.5 million, of which $186.4 million related to sales within the segment, cost of sales and fuel of $98.9 million and operating income of $73.6 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $64.1 million, cost of sales and fuel of $7.0 million and operating income of $25.7 million.

Six Months Ended June 30, 2016	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)			Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	610,117		$	3,125,547		$	171,875		$	1,027		$	3,908,566
Intersegment revenues	298,653			233,836			2,167			(534,656		)	—
Total revenues	908,770			3,359,383			174,042			(533,629		)	3,908,566
Cost of sales and fuel (exclusive of items shown separately below)	566,291			2,682,184			9,044			(534,458		)	2,723,061
Operating costs	138,910			156,951			56,702			16,291			368,854
Depreciation and amortization	88,264			81,402			22,577			1,482			193,725
(Gain) loss on sale of assets	(1,485		)	(7		)	(2,239		)	(62		)	(3,793		)
Operating income	$	116,790		$	438,853		$	87,958		$	(16,882	)	$	626,719
Equity in net earnings from investments	$	5,391		$	27,251		$	32,644		$	—		$	65,286
Investments in unconsolidated affiliates	$	68,854		$	471,415		$	373,544		$	—		$	913,813
Total assets	$	5,222,225		$	8,289,089		$	1,856,128		$	455,458		$	15,822,900
Noncontrolling interests in consolidated subsidiaries	$	—		$	159,049		$	—		$	3,095,699		$	3,254,748
Capital expenditures	$	226,171		$	54,986		$	47,226		$	4,871		$	333,254

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $579.3 million, of which $489.2 million related to sales within the segment, cost of sales and fuel of $219.5 million and operating income of $236.4 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $111.4 million, cost of sales and fuel of $11.3 million and operating income of $46.9 million.

Six Months Ended June 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	$	567,514		$	3,204,393	$	160,359		$	1,092		$	3,933,358
Intersegment revenues	348,171			140,574		3,302			(492,047		)	—
Total revenues	915,685			3,344,967		163,661			(490,955		)	3,933,358
Cost of sales and fuel (exclusive of items shown separately below)	653,858			2,764,357		20,431			(491,689		)	2,946,957
Operating costs	132,760			159,656		52,482			(530		)	344,368
Depreciation and amortization	71,749			78,727		21,570			896			172,942
(Gain) loss on sale of assets	(196		)	81		(1		)	—			(116		)
Operating income	$	57,514		$	342,146	$	69,179		$	368		$	469,207
Equity in net earnings from investments	$	9,161		$	16,673	$	35,127		$	—		$	60,961
Investments in unconsolidated affiliates	$	252,468		$	485,381	$	408,558		$	—		$	1,146,407
Total assets	$	5,007,456		$	8,139,590	$	1,848,779		$	655,355		$	15,651,180
Noncontrolling interests in consolidated subsidiaries	$	4,065		$	162,494	$	—		$	3,315,292		$	3,481,851
Capital expenditures	$	460,735		$	132,553	$	25,205		$	10,955		$	629,448

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $437.3 million, of which $351.7 million related to sales within the segment, cost of sales and fuel of $184.6 million and operating income of $138.5 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $133.4 million, cost of sales and fuel of $15.4 million and operating income of $53.1 million.

	Three Months Ended						Six Months Ended
	June 30,						June 30,
(Unaudited)	2016			2015			2016			2015
	(Thousands of dollars)
Segment Adjusted EBITDA:
Natural Gas Gathering and Processing	$	110,298		$	78,062		$	210,333		$	138,580
Natural Gas Liquids	276,611			244,591			546,780			437,246
Natural Gas Pipelines	68,542			65,234			142,881			135,946
Other	(2,768		)	(2,228		)	(5,682		)	(5,701		)
Depreciation and amortization	(99,247		)	(86,987		)	(193,725		)	(172,942		)
Interest expense, net of capitalized interest	(118,976		)	(102,384		)	(237,223		)	(199,134		)
Income taxes	(52,458		)	(48,222		)	(102,524		)	(85,650		)
AFUDC and other	(1,916		)	2,954			(4,843		)	(1,488		)
Income from continuing operations	180,086			151,020			355,997			246,857
Income (loss) from discontinued operations, net of tax	(227		)	(140		)	(1,179		)	(284		)
Net income	$	179,859		$	150,880		$	354,818		$	246,573

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

6 Months Ended

Jun. 30, 2016

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

Basis of Accounting, Policy [Policy Text Block]

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 statement of the results for the interim periods presented. All such adjustments are of a normal recurring nature. The 2015 year-end consolidated balance sheet data was derived from our audited financial statements but does not include all disclosures required by GAAP. Certain reclassifications have been made in the prior-year financial statements to conform to the current-year presentation. These unaudited consolidated financial statements should be read in conjunction with our audited consolidated financial statements in our Annual Report.

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

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

Consolidation, Policy [Policy Text Block]

Consolidation - Our consolidated financial statements include our accounts and the accounts of our subsidiaries over which we have control or are the primary beneficiary. Management’s judgment is required when:

• determining whether an entity is a variable interest entity (VIE);

• determining whether we are the primary beneficiary of a VIE; and

• identifying events that require reconsideration of whether an entity is a VIE.

As a result of adopting ASU 2015-02 described below, we have concluded that ONEOK Partners is a VIE and that we are the primary beneficiary. Therefore, we continue to consolidate ONEOK Partners. See Note K for additional information.

We record noncontrolling interests in consolidated subsidiaries on our Consolidated Balance Sheets to recognize the portion of ONEOK Partners that we do not own. We reflect our ownership interest in ONEOK Partners’ accumulated other comprehensive income (loss) in our consolidated accumulated other comprehensive income (loss). The remaining portion is reflected as an adjustment to noncontrolling interests in consolidated subsidiaries.

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 was effective for public companies for fiscal years beginning after December 15, 2015. We adopted this guidance in the first quarter 2016, and there was no impact, but it could impact us in the future if we complete any acquisitions with subsequent measurement period adjustments.

Accounting Standards Update 2015-07 [Member]

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Accounting Pronouncements, Policy [Policy Text Block]

In May 2015, the FASB issued ASU 2015-07, “Fair Value Measurement (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent),” which removes the requirement to categorize within the fair value hierarchy all investments for which fair value is measured using the net asset value per share practical expedient. The amendment also removes the requirement to make certain disclosures for all investments that are eligible to be measured at fair value using the net asset value per share practical expedient. This guidance was effective for public companies for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. We adopted this guidance in the first quarter 2016. The impact of adopting this guidance was not material.

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 account for the arrangement as a service contract. This guidance was effective for public companies for fiscal years beginning after December 15, 2015. We adopted this guidance in the first quarter 2016. 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 was effective for public companies for fiscal years beginning after December 15, 2015. We adopted this guidance in the first quarter 2016. As a result of adopting this guidance, we no longer consolidate ONEOK Partners under the presumption that a general partner should consolidate a limited partnership. We concluded, however, that ONEOK Partners is a VIE and ONEOK is the primary beneficiary, and we therefore consolidate ONEOK Partners under the variable interest model of consolidation. There was no financial statement impact due to the change in consolidation methodology. See Note K for additional information.

Accounting Standards Update 2016-13 [Member]

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Accounting Pronouncements, Policy [Policy Text Block]

In June 2016, the FASB issued ASU 2016-13, “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments,” which requires a financial asset (or a group of financial assets) measured at amortized cost basis to be presented net of the allowance for credit losses to reflect the net carrying value at the amount expected to be collected on the financial asset; and the initial allowance for credit losses for purchased financial assets, including available-for-sale debt securities, to be added to the purchase price rather than being reported as a credit loss expense. This guidance is effective for public companies for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. Early adoption is permitted for the fiscal years beginning after December 15, 2018. We expect to adopt this guidance in the first quarter 2020, and we are evaluating the impact on us.

Accounting Standards Update 2016-09 [Member]

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Accounting Pronouncements, Policy [Policy Text Block]

In March 2016, the FASB issued ASU 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting,” which provides simplified accounting for share-based payment transactions in relation to income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. This guidance is effective for public companies for annual periods beginning after December 15, 2016, and interim periods within those annual periods, with early adoption permitted. We expect to adopt this guidance in the first quarter 2017, and we are evaluating the impact on us.

Accounting Standards Update 2016-06 [Member]

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Accounting Pronouncements, Policy [Policy Text Block]

In March 2016, the FASB issued ASU 2016-06, “Derivatives and Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments,” which clarifies the requirements for assessing whether a contingent call (put) option that can accelerate the payment of principal on a debt instrument is clearly and closely related to its debt host. Under the amendments in the update, assessments must be performed in accordance with the four-step decision sequence to conclude which call (put) options should be bifurcated and accounted for separately as derivatives. This guidance is effective for public companies for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years, with early adoption permitted. We expect to adopt this guidance in the first quarter 2017, and we are evaluating the impact on us.

Accounting Standards Update 2016-05 [Member]

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Accounting Pronouncements, Policy [Policy Text Block]

In March 2016, the FASB issued ASU 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships,” which clarifies that a change in the counterparty to a derivative instrument that has been designated as the hedging instrument under Topic 815 does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge accounting criteria continue to be met. This guidance is effective for public companies for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. Early adoption is permitted. We expect to adopt this guidance in the first quarter 2017, and we are evaluating the impact on us.

Accounting Standards Update 2016-02 [Member]

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Accounting Pronouncements, Policy [Policy Text Block]

In February 2016, the FASB issued ASU 2016-02, “Leases (Topic 842),” which requires the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases under previous GAAP. It also requires qualitative disclosures along with specific quantitative disclosures by lessees and lessors to meet the objective of enabling users of financial statements to assess the amount, timing and uncertainty of cash flows arising from leases. This guidance is effective for public companies for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early adoption is permitted. We expect to adopt this guidance in the first quarter 2019, and we are evaluating the impact on us.

Accounting Standards Update 2016-01 [Member]

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Accounting Pronouncements, Policy [Policy Text Block]

In January 2016, the FASB issued ASU 2016-01, “Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities,” which requires all equity investments other than those accounted for using the equity method of accounting or those that result in consolidation of the investee to be measured at fair value with changes in fair value recognized in net income, eliminates the available-for-sale classification for equity securities with readily determinable fair values and eliminates the cost method for equity investments without readily determinable fair values. Additionally, this guidance eliminates the requirement to disclose the methods and significant assumptions used to estimate the fair value of financial instruments carried at amortized cost and requires the use of the exit price when measuring the fair value of such instruments for disclosure purposes. This guidance will be effective for public companies in fiscal years beginning after December 15, 2017, including interim periods within those fiscal years. Early adoption is only permitted for certain portions of the ASU. We expect to adopt this guidance in the first quarter 2018, and we are evaluating the impact on us.

Accounting Standards Update 2015-11 [Member]

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Accounting Pronouncements, Policy [Policy Text Block]

In July 2015, the FASB issued ASU 2015-11, “Inventory (Topic 330): Simplifying the Measurement of Inventory,” which requires that inventory, excluding inventory measured using last-in, first-out (LIFO) or the retail inventory method, be measured at the lower of cost or net realizable value. This guidance will be effective for public companies for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. We expect to adopt this guidance in the first quarter 2017, 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, “Presentation of Financial Statements - Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a 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 (Topic 606),” 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. The FASB has issued additional ASUs, which provide further guidance and clarification on implementation issues. We expect to adopt this guidance beginning in the first quarter 2018, and we are evaluating the impact on us.

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FAIR VALUE MEASUREMENTS FAIR VALUE MEASUREMENTS (Policies)

6 Months Ended

Jun. 30, 2016

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 our 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 derivatives by discounting the projected future cash flows from the derivative assets and liabilities to present value using interest-rate yields to calculate present-value discount factors derived from LIBOR, Eurodollar futures and the LIBOR interest-rate swaps market. 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 executed derivative contracts , the ultimate market prices realized could differ from our estimates, and the differences could be material.

The fair value of 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-rate 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 internally developed 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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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES (Policies)

6 Months Ended

Jun. 30, 2016

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES [Abstract]

Accounting treatment for derivative instruments

Accounting Treatment -All derivative instruments are recorded 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 our exposure to fluctuations in natural gas, NGLs and condensate prices, we periodically enter 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, these derivative instruments are designated as a hedge of exposure to changes in fair values or cash flows. All relationships between hedging instruments and hedged items are formally documented, as well as risk-management objectives and strategies for undertaking various hedge transactions, and methods for assessing and testing correlation and hedge ineffectiveness. The forecasted transaction that has been designated as the hedged item in a cash flow hedge relationship is specifically identified. The effectiveness of hedging relationships are assessed quarterly by performing an effectiveness analysis on the fair value and cash flow hedging relationships to determine whether the hedge relationships are highly effective on a retrospective and prospective basis. Normal purchases and normal sales transactions that are expected to result in physical delivery and, through election, are exempt from derivative accounting treatment are also documented.

The realized revenues and purchase costs of 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)

6 Months Ended

Jun. 30, 2016

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.

Consolidation - We determined ONEOK Partners is a VIE due to the limited partners’ lack of substantive voting rights under the Partnership Agreement. Substantive voting rights under a master limited partnership are either kick-out rights or participating rights, as defined by FASB Accounting Standards Codification 810-10, that can be exercised with a simple majority of the vote of the limited partners. Prior to the adoption of ASU 2015-02, ONEOK Partners was not considered a VIE and was consolidated by us under the presumption that a general partner consolidates its limited partnership. See Note A for more information on ASU 2015-02.

We have determined that we are the primary beneficiary of ONEOK Partners as we have the power, through our general partner interest, to direct the operations of ONEOK Partners that impact its economic performance and the right to receive the benefits of ONEOK Partners through our general partner and limited partner interests. These interests are significant due to our 41.2 percent ownership interest in ONEOK Partners, the largest ownership interest by an individual entity, and our incentive distribution rights.

As we are the primary beneficiary of ONEOK Partners, 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 from ONEOK Partners.

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.

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SEGMENTS SEGMENTS (Policies)

6 Months Ended

Jun. 30, 2016

Segment Accounting Policies [Abstract]

Segments Accounting Policies [Text Block]

Accounting Policies -The accounting policies of the segments are described in Note A of the Notes to Consolidated Financial Statements in our Annual Report. Our chief operating decision maker reviews the financial performance of each of the three segments of ONEOK Partners, as well as our financial performance, on a regular basis. Beginning in 2016, adjusted EBITDA by segment, a non-GAAP financial measure, is utilized in this evaluation. We believe this non-GAAP financial measure is useful to investors because it is used by many companies in our industry as a measurement of financial performance and is commonly employed by financial analysts and others to evaluate our financial performance and to compare our financial performance with the performance of other publicly traded partnerships within our industry. Adjusted EBITDA is defined as net income adjusted for interest expense, depreciation and amortization, noncash impairment charges, income taxes and AFUDC and other noncash items. Adjusted EBITDA should not be considered an alternative to net income, earnings per unit or any other measure of financial performance presented in accordance with GAAP. Additionally, this calculation may not be comparable with similarly titled measures of other companies. Prior period segment disclosures have been recast to reflect this change.

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FAIR VALUE MEASUREMENTS (Tables)

6 Months Ended

Jun. 30, 2016

Fair Value Disclosures [Abstract]

Recurring Fair Value Measurments

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

	June 30, 2016
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Derivative assets
Commodity contracts
Financial contracts	$	13,966		$	—		$	3,205		$	17,171		$	(10,970	)	$	6,201
Physical contracts	—			—			68			68			—			68
Total derivative assets	$	13,966		$	—		$	3,273		$	17,239		$	(10,970	)	$	6,269
Derivative liabilities
Commodity contracts
Financial contracts	$	(15,352	)	$	—		$	(12,365	)	$	(27,717	)	$	27,717		$	—
Physical contracts	—			—			(4,929		)	(4,929		)	—			(4,929		)
Interest-rate contracts	—			(70,111		)	—			(70,111		)	—			(70,111		)
Total derivative liabilities	$	(15,352	)	$	(70,111	)	$	(17,294	)	$	(102,757	)	$	27,717		$	(75,040	)

(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 us. At June 30, 2016, we had no cash held and posted $33.5 million of cash with various counterparties, including $16.7 million of cash collateral that is offsetting derivative net liability positions under master-netting arrangements in the table above. The remaining $16.8 million of cash collateral in excess of derivative net liability positions is included in other current assets in our Consolidated Balance Sheets.

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

	December 31, 2015
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Derivative assets
Commodity contracts
Financial contracts	$	38,921		$	—		$	7,253		$	46,174		$	(42,414	)	$	3,760
Physical contracts	—			—			3,591			3,591			—			3,591
Total derivative assets	$	38,921		$	—		$	10,844		$	49,765		$	(42,414	)	$	7,351
Derivative liabilities
Commodity contracts
Financial contracts	$	(4,513	)	$	—		$	(3,513	)	$	(8,026	)	$	8,026		$	—
Interest-rate contracts	—			(9,936		)	—			(9,936		)	—			(9,936		)
Total derivative liabilities	$	(4,513	)	$	(9,936	)	$	(3,513	)	$	(17,962	)	$	8,026		$	(9,936	)

(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 us. At December 31, 2015, we held $34.4 million of cash from various counterparties that is offsetting derivative net asset positions in the table above under master-netting arrangements and had no cash collateral posted.

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

Reconciliation of Level 3 Fair Value Measurements

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

	Three Months Ended						Six Months Ended
	June 30,						June 30,
Derivative Assets (Liabilities)	2016			2015			2016			2015
	(Thousands of dollars)
Net assets at beginning of period	$	34		$	7,040		$	7,331		$	9,285
Total realized/unrealized gains (losses):
Included in earnings (a)	318			(159		)	(427		)	110
Included in other comprehensive income (loss)	(14,373		)	3,506			(20,925		)	992
Net assets (liabilities) at end of period	$	(14,021	)	$	10,387		$	(14,021	)	$	10,387

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

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES (Tables)

6 Months Ended

Jun. 30, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair value of derivatives

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

	June 30, 2016					December 31, 2015
	Assets (a)		(Liabilities) (a)			Assets (b)		(Liabilities) (b)
	(Thousands of dollars)
Derivatives designated as hedging instruments
Commodity contracts
Financial contracts	$	14,591	$	(25,028	)	$	39,255	$	(1,440	)
Physical contracts	68		(4,929		)	3,591		—
Interest-rate contracts	—		(70,111		)	—		(9,936		)
Total derivatives designated as hedging instruments	14,659		(100,068		)	42,846		(11,376		)
Derivatives not designated as hedging instruments
Commodity contracts
Financial contracts	2,580		(2,689		)	6,919		(6,586		)
Total derivatives not designated as hedging instruments	2,580		(2,689		)	6,919		(6,586		)
Total derivatives	$	17,239	$	(102,757	)	$	49,765	$	(17,962	)

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

(b) - Included on a net basis in other current 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 held for the periods indicated:

		June 30, 2016					December 31, 2015
	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	—		(41.2		)	—		(27.1		)
- Natural gas (Bcf)	Put options	89.7		—			—		—
- Crude oil and NGLs (MMBbl)	Futures, forwards and swaps	—		(5.5		)	—		(2.3		)
- Propane (MMBbl)	Put options	1.5		—			—		—
Basis
- Natural gas (Bcf)	Futures and swaps	—		(41.2		)	—		(27.1		)
Interest-rate contracts (Millions of dollars)	Swaps	$	2,150.0	$	—		$	400.0	$	—
Derivatives not designated as hedging instruments:
Fixed price
- NGLs (MMBbl)	Futures, forwards and swaps	0.8		(1.0		)	0.6		(0.6		)

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					Six Months Ended
	June 30,					June 30,
	2016			2015		2016			2015
	(Thousands of dollars)
Commodity contracts	$	(58,654	)	$	1,072	$	(46,976	)	$	11,091
Interest-rate contracts	(28,564		)	16,909		(60,175		)	(5,667		)
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	$	(87,218	)	$	17,981	$	(107,151	)	$	5,424

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 Loss into Net Income (Effective Portion)	Three Months Ended						Six Months Ended
		June 30,						June 30,
		2016			2015			2016			2015
		(Thousands of dollars)
Commodity contracts	Commodity sales revenues	$	14,049		$	17,078		$	28,548		$	31,250
Interest-rate contracts	Interest expense	(4,802		)	(4,598		)	(9,500		)	(8,315		)
Total gain (loss) reclassified from accumulated other comprehensive loss into net income on derivatives (effective portion)		$	9,247		$	12,480		$	19,048		$	22,935

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LONG-TERM DEBT LONG-TERM DEBT (Tables)

6 Months Ended

Jun. 30, 2016

Debt Instrument [Line Items]

Schedule of Debt [Table Text Block]

The following table sets forth our long-term debt for the periods indicated:

	June 30,			December 31,
	2016			2015
	(Thousands of dollars)
ONEOK
$700,000 at 4.25% due 2022	$	547,397		$	547,397
$500,000 at 7.5% due 2023	500,000			500,000
$100,000 at 6.5% due 2028	87,190			87,516
$100,000 at 6.875% due 2028	100,000			100,000
$400,000 at 6.0% due 2035	400,000			400,000
Total ONEOK senior notes payable	1,634,587			1,634,913
ONEOK Partners
$650,000 at 3.25% due 2016	—			650,000
$450,000 at 6.15% due 2016	450,000			450,000
$400,000 at 2.0% due 2017	400,000			400,000
$425,000 at 3.2% due 2018	425,000			425,000
$1,000,000 term loan, variable rate, due 2019	1,000,000			—
$500,000 at 8.625% due 2019	500,000			500,000
$300,000 at 3.8% due 2020	300,000			300,000
$900,000 at 3.375% due 2022	900,000			900,000
$425,000 at 5.0% due 2023	425,000			425,000
$500,000 at 4.9% due 2025	500,000			500,000
$600,000 at 6.65% due 2036	600,000			600,000
$600,000 at 6.85% due 2037	600,000			600,000
$650,000 at 6.125% due 2041	650,000			650,000
$400,000 at 6.2% due 2043	400,000			400,000
Guardian Pipeline
Average 7.85% due 2022	48,082			51,907
Total ONEOK Partners long-term debt	7,198,082			6,851,907
Total long-term debt	8,832,669			8,486,820
Unamortized portion of terminated swaps	21,045			21,904
Unamortized debt issuance costs and discounts	(72,787		)	(74,492		)
Current maturities	(460,650		)	(110,650		)
Long-term debt, excluding current maturities	$	8,320,277		$	8,323,582

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Tables)

6 Months Ended

Jun. 30, 2016

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 loss for the period indicated:

	Unrealized Gains (Losses) on Risk- Management Assets/Liabilities (a)			Pension and Postretirement Benefit Plan Obligations (a) (b)			Unrealized Gains (Losses) on Risk- Management Assets/Liabilities of Unconsolidated Affiliates (a)			Accumulated Other Comprehensive Loss (a)
	(Thousands of dollars)
January 1, 2016	$	(42,199	)	$	(84,543	)	$	(500	)	$	(127,242	)
Other comprehensive income (loss) before reclassifications	(27,813		)	6			(2,950		)	(30,757		)
Amounts reclassified from accumulated other comprehensive loss	(4,346		)	3,099			—			(1,247		)
Net current period other comprehensive income (loss) attributable to ONEOK	(32,159		)	3,105			(2,950		)	(32,004		)
June 30, 2016	$	(74,358	)	$	(81,438	)	$	(3,450	)	$	(159,246	)

(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 loss in our Consolidated Statements of Income for the periods indicated:

Details about Accumulated Other Comprehensive Loss Components	Three Months Ended						Six Months Ended						Affected Line Item in the Consolidated Statements of Income
	June 30,						June 30,
	2016			2015			2016			2015
	(Thousands of dollars)
Unrealized gains (losses) on risk-management assets/liabilities
Commodity contracts	$	14,049		$	17,078		$	28,548		$	31,250		Commodity sales revenues
Interest-rate contracts	(4,802		)	(4,598		)	(9,500		)	(8,315		)	Interest expense
	9,247			12,480			19,048			22,935			Income before income taxes
	(1,193		)	(1,439		)	(2,469		)	(2,664		)	Income tax expense
	8,054			11,041			16,579			20,271			Net income
Noncontrolling interests	5,953			8,523			12,233			15,595			Less: Net income attributable to noncontrolling interests
	$	2,101		$	2,518		$	4,346		$	4,676		Net income attributable to ONEOK
Pension and postretirement benefit plan obligations (a)
Amortization of net loss	$	(2,997	)	$	(4,423	)	$	(5,995	)	$	(8,846	)
Amortization of unrecognized prior service cost	415			392			830			784
	(2,582		)	(4,031		)	(5,165		)	(8,062		)	Income before income taxes
	1,033			1,613			2,066			3,225			Income tax expense
	$	(1,549	)	$	(2,418	)	$	(3,099	)	$	(4,837	)	Net income attributable to ONEOK
Total reclassifications for the period attributable to ONEOK	$	552		$	100		$	1,247		$	(161	)	Net income attributable to ONEOK

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

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EARNINGS PER SHARE (Tables)

6 Months Ended

Jun. 30, 2016

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 June 30, 2016
	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	$	86,171	211,075	$	0.41
Diluted EPS from continuing operations
Effect of dilutive securities	—		1,543
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	86,171	212,618	$	0.41

	Three Months Ended June 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	$	76,645	210,204	$	0.36
Diluted EPS from continuing operations
Effect of dilutive securities	—		273
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	76,645	210,477	$	0.36

	Six Months Ended June 30, 2016
	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	$	170,569	210,928	$	0.81
Diluted EPS from continuing operations
Effect of dilutive securities	—		735
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	170,569	211,663	$	0.81

	Six Months Ended June 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	$	137,589	210,059	$	0.65
Diluted EPS from continuing operations
Effect of dilutive securities	—		427
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	137,589	210,486	$	0.65

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EMPLOYEE BENEFIT PLANS (Tables)

6 Months Ended

Jun. 30, 2016

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						Six Months Ended
	June 30,						June 30,
	2016			2015			2016			2015
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	1,622		$	1,887		$	3,244		$	3,774
Interest cost	4,947			4,546			9,894			9,092
Expected return on assets	(5,077		)	(5,213		)	(10,154		)	(10,426		)
Amortization of unrecognized prior service cost	—			23			—			46
Amortization of net loss	2,736			3,987			5,473			7,974
Net periodic benefit cost	$	4,228		$	5,230		$	8,457		$	10,460

	Postretirement Benefits
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2016			2015			2016			2015
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	149		$	186		$	298		$	372
Interest cost	601			587			1,202			1,173
Expected return on assets	(531		)	(564		)	(1,062		)	(1,128		)
Amortization of unrecognized prior service cost	(415		)	(415		)	(830		)	(830		)
Amortization of net loss	261			436			522			872
Net periodic benefit cost	$	65		$	230		$	130		$	459

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UNCONSOLIDATED AFFILIATES (Tables)

6 Months Ended

Jun. 30, 2016

Equity In Net Earnings From Investments [Member]

Schedule of Equity Method Investments [Line Items]

Equity Method Investments

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2016		2015		2016		2015
	(Thousands of dollars)
Northern Border Pipeline	$	15,723	$	15,273	$	34,397	$	34,975
Overland Pass Pipeline Company	13,608		9,623		26,912		16,510
Other	3,041		5,144		3,977		9,476
Equity in net earnings from investments	$	32,372	$	30,040	$	65,286	$	60,961

Summarized Financial Information Of Unconsolidated Affiliates [Member]

Schedule of Equity Method Investments [Line Items]

Equity Method Investments

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2016		2015		2016		2015
	(Thousands of dollars)
Income Statement
Operating revenues	$	142,631	$	125,738	$	279,203	$	255,319
Operating expenses	$	66,674	$	55,959	$	125,373	$	113,538
Net income	$	69,420	$	62,643	$	141,457	$	129,002
Distributions paid to ONEOK Partners	$	62,024	$	41,354	$	108,577	$	80,783

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ONEOK PARTNERS (Tables)

6 Months Ended

Jun. 30, 2016

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 June 30, 2016:

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.

Consolidated Variable Interest Entity Assets and Liabilities

The following table shows the carrying amount and classification of ONEOK Partners’ assets and liabilities in our Consolidated Balance Sheets:

	June 30,		December 31,
	2016		2015
	(Thousands of dollars)
Assets
Total current assets	$	1,096,107	$	883,164
Net property, plant and equipment	12,372,176		12,256,791
Total investments and other assets	1,749,593		1,787,631
Total assets	$	15,217,876	$	14,927,586
Liabilities
Total current liabilities	$	2,140,793	$	1,580,300
Long-term debt, excluding current maturities	6,691,950		6,695,312
Total deferred credits and other liabilities	183,200		154,631
Total liabilities	$	9,015,943	$	8,430,243

ONEOK Partners' Distributions Paid

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2016		2015		2016		2015
	(Thousands, except per unit amounts)
Distribution per unit	$	0.79	$	0.79	$	1.58	$	1.58
General partner distributions	$	6,660	$	5,955	$	13,320	$	11,869
Incentive distributions	100,538		89,889		201,076		179,168
Distributions to general partner	107,198		95,844		214,396		191,037
Limited partner distributions to ONEOK	90,323		73,302		180,646		146,604
Limited partner distributions to noncontrolling interest	135,479		128,583		270,959		255,794
Total distributions paid	$	333,000	$	297,729	$	666,001	$	593,435

ONEOK Partners' Distributions Declared

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2016		2015		2016		2015
	(Thousands, except per unit amounts)
Distribution per unit	$	0.79	$	0.79	$	1.58	$	1.58
General partner distributions	$	6,660	$	6,081	$	13,320	$	12,036
Incentive distributions	100,538		91,794		201,076		181,683
Distributions to general partner	107,198		97,875		214,396		193,719
Limited partner distributions to ONEOK	90,323		73,302		180,646		146,604
Limited partner distributions to noncontrolling interest	135,479		132,862		270,959		261,445
Total distributions declared	$	333,000	$	304,039	$	666,001	$	601,768

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DISCONTINUED OPERATIONS (Tables)

6 Months Ended

Jun. 30, 2016

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:

	Six Months Ended
	June 30,
	2016			2015
	(Millions of dollars)
Beginning balance	$	36.3		$	73.8
Settlements	(11.6		)	(22.4		)
Accretion	0.3			0.6
Ending balance	$	25.0		$	52.0

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SEGMENTS (Tables)

6 Months Ended

Jun. 30, 2016

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 June 30, 2016	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)		Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	293,071		$	1,754,122		$	86,401	$	513		$	2,134,107
Intersegment revenues	183,688			117,871			1,668		(303,227		)	—
Total revenues	476,759			1,871,993			88,069		(302,714		)	2,134,107
Cost of sales and fuel (exclusive of items shown separately below)	299,991			1,525,234			5,112		(303,014		)	1,527,323
Operating costs	69,304			83,769			29,189		9,577			191,839
Depreciation and amortization	46,413			40,696			11,398		740			99,247
(Gain) loss on sale of assets	(240		)	(71		)	725		(1		)	413
Operating income	$	61,291		$	222,365		$	41,645	$	(10,016	)	$	315,285
Equity in net earnings from investments	$	2,576		$	13,904		$	15,892	$	—		$	32,372
Capital expenditures	$	84,674		$	20,779		$	29,278	$	2,112		$	136,843

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $297.5 million, of which $258.4 million related to sales within the segment, cost of sales and fuel of $112.7 million and operating income of $120.8 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $56.6 million, cost of sales and fuel of $5.7 million and operating income of $23.8 million.

Three Months Ended June 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	$	279,498		$	1,769,580	$	78,429	$	545		$	2,128,052
Intersegment revenues	180,564			79,295		1,683		(261,542		)	—
Total revenues	460,062			1,848,875		80,112		(260,997		)	2,128,052
Cost of sales and fuel (exclusive of items shown separately below)	322,927			1,535,492		6,005		(261,331		)	1,603,093
Operating costs	63,550			77,410		25,240		(850		)	165,350
Depreciation and amortization	35,952			39,433		10,814		788			86,987
(Gain) loss on sale of assets	(195		)	73		—		—			(122		)
Operating income	$	37,828		$	196,467	$	38,053	$	396		$	272,744
Equity in net earnings from investments	$	4,922		$	9,693	$	15,425	$	—		$	30,040
Capital expenditures	$	205,434		$	59,087	$	15,613	$	5,467		$	285,601

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $227.5 million, of which $186.4 million related to sales within the segment, cost of sales and fuel of $98.9 million and operating income of $73.6 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $64.1 million, cost of sales and fuel of $7.0 million and operating income of $25.7 million.

Six Months Ended June 30, 2016	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)			Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	610,117		$	3,125,547		$	171,875		$	1,027		$	3,908,566
Intersegment revenues	298,653			233,836			2,167			(534,656		)	—
Total revenues	908,770			3,359,383			174,042			(533,629		)	3,908,566
Cost of sales and fuel (exclusive of items shown separately below)	566,291			2,682,184			9,044			(534,458		)	2,723,061
Operating costs	138,910			156,951			56,702			16,291			368,854
Depreciation and amortization	88,264			81,402			22,577			1,482			193,725
(Gain) loss on sale of assets	(1,485		)	(7		)	(2,239		)	(62		)	(3,793		)
Operating income	$	116,790		$	438,853		$	87,958		$	(16,882	)	$	626,719
Equity in net earnings from investments	$	5,391		$	27,251		$	32,644		$	—		$	65,286
Investments in unconsolidated affiliates	$	68,854		$	471,415		$	373,544		$	—		$	913,813
Total assets	$	5,222,225		$	8,289,089		$	1,856,128		$	455,458		$	15,822,900
Noncontrolling interests in consolidated subsidiaries	$	—		$	159,049		$	—		$	3,095,699		$	3,254,748
Capital expenditures	$	226,171		$	54,986		$	47,226		$	4,871		$	333,254

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $579.3 million, of which $489.2 million related to sales within the segment, cost of sales and fuel of $219.5 million and operating income of $236.4 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $111.4 million, cost of sales and fuel of $11.3 million and operating income of $46.9 million.

Six Months Ended June 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	$	567,514		$	3,204,393	$	160,359		$	1,092		$	3,933,358
Intersegment revenues	348,171			140,574		3,302			(492,047		)	—
Total revenues	915,685			3,344,967		163,661			(490,955		)	3,933,358
Cost of sales and fuel (exclusive of items shown separately below)	653,858			2,764,357		20,431			(491,689		)	2,946,957
Operating costs	132,760			159,656		52,482			(530		)	344,368
Depreciation and amortization	71,749			78,727		21,570			896			172,942
(Gain) loss on sale of assets	(196		)	81		(1		)	—			(116		)
Operating income	$	57,514		$	342,146	$	69,179		$	368		$	469,207
Equity in net earnings from investments	$	9,161		$	16,673	$	35,127		$	—		$	60,961
Investments in unconsolidated affiliates	$	252,468		$	485,381	$	408,558		$	—		$	1,146,407
Total assets	$	5,007,456		$	8,139,590	$	1,848,779		$	655,355		$	15,651,180
Noncontrolling interests in consolidated subsidiaries	$	4,065		$	162,494	$	—		$	3,315,292		$	3,481,851
Capital expenditures	$	460,735		$	132,553	$	25,205		$	10,955		$	629,448

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $437.3 million, of which $351.7 million related to sales within the segment, cost of sales and fuel of $184.6 million and operating income of $138.5 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $133.4 million, cost of sales and fuel of $15.4 million and operating income of $53.1 million.

	Three Months Ended						Six Months Ended
	June 30,						June 30,
(Unaudited)	2016			2015			2016			2015
	(Thousands of dollars)
Segment Adjusted EBITDA:
Natural Gas Gathering and Processing	$	110,298		$	78,062		$	210,333		$	138,580
Natural Gas Liquids	276,611			244,591			546,780			437,246
Natural Gas Pipelines	68,542			65,234			142,881			135,946
Other	(2,768		)	(2,228		)	(5,682		)	(5,701		)
Depreciation and amortization	(99,247		)	(86,987		)	(193,725		)	(172,942		)
Interest expense, net of capitalized interest	(118,976		)	(102,384		)	(237,223		)	(199,134		)
Income taxes	(52,458		)	(48,222		)	(102,524		)	(85,650		)
AFUDC and other	(1,916		)	2,954			(4,843		)	(1,488		)
Income from continuing operations	180,086			151,020			355,997			246,857
Income (loss) from discontinued operations, net of tax	(227		)	(140		)	(1,179		)	(284		)
Net income	$	179,859		$	150,880		$	354,818		$	246,573

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FAIR VALUE MEASUREMENTS - Part 1 (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash held - offsetting derivative net asset positions under master-netting arrangements	$ 0	$ 34,400
Cash posted - total	33,500
Cash posted - offsetting derivative net liability positions under master-netting arrangements	16,700	0
Cash posted - remaining in excess of derivative net liability positions included in consolidated Balance Sheets	16,800
Derivative liabilities
Long-term Debt, Fair Value	9,000,000	7,400,000
Long-term Debt, Book Value	8,800,000	8,400,000
Fair Value, Measurements, Recurring [Member]
Derivative assets
Commodity contracts - financial	6,201	3,760
Commodity contracts - physical	68	3,591
Total derivatives assets	6,269	7,351
Derivative liabilities
Commodity contracts - financial	0	0
Commodity contracts - physical	(4,929)
Interest-rate contracts	(70,111)	(9,936)
Total derivative liabilities	(75,040)	(9,936)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Derivative assets
Commodity contracts - financial	13,966	38,921
Commodity contracts - physical	0	0
Total derivatives assets	13,966	38,921
Derivative liabilities
Commodity contracts - financial	(15,352)	(4,513)
Commodity contracts - physical	0
Interest-rate contracts	0	0
Total derivative liabilities	(15,352)	(4,513)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Derivative assets
Commodity contracts - financial	0	0
Commodity contracts - physical	0	0
Total derivatives assets	0	0
Derivative liabilities
Commodity contracts - financial	0	0
Commodity contracts - physical	0
Interest-rate contracts	(70,111)	(9,936)
Total derivative liabilities	(70,111)	(9,936)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Derivative assets
Commodity contracts - financial	3,205	7,253
Commodity contracts - physical	68	3,591
Total derivatives assets	3,273	10,844
Derivative liabilities
Commodity contracts - financial	(12,365)	(3,513)
Commodity contracts - physical	(4,929)
Interest-rate contracts	0	0
Total derivative liabilities	(17,294)	(3,513)
Fair Value, Measurements, Recurring [Member] | Total Gross [Member]
Derivative assets
Commodity contracts - financial	17,171	46,174
Commodity contracts - physical	68	3,591
Total derivatives assets	17,239	49,765
Derivative liabilities
Commodity contracts - financial	(27,717)	(8,026)
Commodity contracts - physical	(4,929)
Interest-rate contracts	(70,111)	(9,936)
Total derivative liabilities	(102,757)	(17,962)
Fair Value, Measurements, Recurring [Member] | Netting [Member]
Derivative assets
Commodity contracts - financial	(10,970)	(42,414)
Commodity contracts - physical	0	0
Total derivatives assets	(10,970)	(42,414)
Derivative liabilities
Commodity contracts - financial	27,717	8,026
Commodity contracts - physical	0
Interest-rate contracts	0	0
Total derivative liabilities	$ 27,717	$ 8,026

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FAIR VALUE MEASUREMENTS - Part 2 (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Net assets at beginning of period	$ 34	$ 7,040	$ 7,331	$ 9,285
Total realized/unrealized gains (losses):
Included in earnings	318	(159)	(427)	110
Included in other comprehensive income (loss)	(14,373)	3,506	(20,925)	992
Net assets (liabilities) at end of period	(14,021)	10,387	(14,021)	10,387
Transfers between levels	$ 0	$ 0	$ 0	$ 0

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES Part 1 (Details) - USD ($)	Jun. 30, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Assets	$ 17,239,000	$ 49,765,000
Liabilities	(102,757,000)	(17,962,000)
Derivative, Net Liability Position, Aggregate Fair Value	0
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	14,659,000	42,846,000
Liabilities	(100,068,000)	(11,376,000)
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member]
Derivatives, Fair Value [Line Items]
Assets	0	0
Liabilities	(70,111,000)	(9,936,000)
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	2,580,000	6,919,000
Liabilities	(2,689,000)	(6,586,000)
Physical Derivative Instrument [Member] | Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Assets	68,000	3,591,000
Liabilities	(4,929,000)	0
Financial Derivative Instrument [Member] | Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Assets	14,591,000	39,255,000
Liabilities	(25,028,000)	(1,440,000)
Financial Derivative Instrument [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Assets	2,580,000	6,919,000
Liabilities	(2,689,000)	(6,586,000)
Natural Gas Pipelines [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net	$ 0	$ 0

XML

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES Part 2 (Details) $ in Millions	6 Months Ended
	Jun. 30, 2016 USD ($) MMcf MMBbls	Dec. 31, 2015 USD ($) MMcf MMBbls
Forward Contracts [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member] | LIBOR Based Interest Payments [Member]
Derivative [Line Items]
Derivative, Notional Amount | $	$ 1,000.0
Forward Contracts [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member] | Forecasted Debt Issuances [Member]
Derivative [Line Items]
Derivative, Notional Amount | $	1,200.0	$ 400.0
Derivative, Notional Amount, New Contracts | $	$ 750.0
Futures and swaps [Member] | Designated as Hedging Instrument [Member] | Fixed Price [Member] | Purchased [Member] | Natural Gas [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMcf	0	0
Futures and swaps [Member] | Designated as Hedging Instrument [Member] | Fixed Price [Member] | Sold [Member] | Natural Gas [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMcf	(41,200)	(27,100)
Futures and swaps [Member] | Designated as Hedging Instrument [Member] | Basis [Member] | Purchased [Member] | Natural Gas [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMcf	0	0
Futures and swaps [Member] | Designated as Hedging Instrument [Member] | Basis [Member] | Sold [Member] | Natural Gas [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMcf	(41,200)	(27,100)
Interest Rate Contract [Member] | Designated as Hedging Instrument [Member] | Purchased [Member]
Derivative [Line Items]
Derivative, Notional Amount | $	$ 2,150.0	$ 400.0
Interest Rate Contract [Member] | Designated as Hedging Instrument [Member] | Sold [Member]
Derivative [Line Items]
Derivative, Notional Amount | $	$ 0.0	$ 0.0
Options [Member] | Designated as Hedging Instrument [Member] | Fixed Price [Member] | Purchased [Member] | Natural Gas [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMcf	89,700	0
Options [Member] | Designated as Hedging Instrument [Member] | Fixed Price [Member] | Purchased [Member] | Propane [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBbls	1.5	0.0
Options [Member] | Designated as Hedging Instrument [Member] | Fixed Price [Member] | Sold [Member] | Natural Gas [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMcf	0	0
Options [Member] | Designated as Hedging Instrument [Member] | Fixed Price [Member] | Sold [Member] | Propane [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBbls	0.0	0.0
Futures, forwards and swaps [Member] | Not Designated as Hedging Instrument [Member] | Fixed Price [Member] | Purchased [Member] | Crude Oil and NGL [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBbls	0.8	0.6
Futures, forwards and swaps [Member] | Not Designated as Hedging Instrument [Member] | Fixed Price [Member] | Sold [Member] | Crude Oil and NGL [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBbls	(1.0)	(0.6)
Futures, forwards and swaps [Member] | Designated as Hedging Instrument [Member] | Fixed Price [Member] | Purchased [Member] | Crude Oil and NGL [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBbls	0.0	0.0
Futures, forwards and swaps [Member] | Designated as Hedging Instrument [Member] | Fixed Price [Member] | Sold [Member] | Crude Oil and NGL [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBbls	(5.5)	(2.3)

XML

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES Part 3 (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax	$ (159,246)		$ (159,246)		$ (127,242)
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)			(27,813)
Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	(87,218)	$ 17,981	(107,151)	$ 5,424
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income on derivatives (effective portion)	9,247	12,480	19,048	22,935
Gain (Loss) on Discontinuation of Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net	0	0	0	0
Commodity Contract [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Commodity cash flow hedge gain (loss) to be reclassified	(8,800)		(8,800)
Price Risk Cash Flow Hedge Unrealized Gain (Loss) to be Reclassified During Next 12 Months	(5,800)		(5,800)
Commodity Cash Flow Hedge Gain (Loss) To Be Reclassified After Next 12 Months Net	(3,000)		(3,000)
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	(58,654)	1,072	(46,976)	11,091
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)	14,049	17,078	28,548	31,250
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.	(47,000)		(47,000)
Amount of loss to be recognized in the next 12 months	(6,300)		(6,300)
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	(28,564)	16,909	(60,175)	(5,667)
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)	$ (4,802)	$ (4,598)	$ (9,500)	$ (8,315)

XML

SHORT-TERM BORROWINGS (Details)	6 Months Ended
	Jun. 30, 2016 USD ($) Rate
ONEOK Credit Agreement [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 300,000,000
Indebtedness To Adjusted EBITDA Maximum	4.0
Indebtedness To Adjusted EBITDA Current	2.2
Line of Credit Facility Letter of Credit Sublimit	$ 50,000,000
Line of Credit Facility Swingline Sublimit	50,000,000
Line Of Credit Facility Option To Increase Borrowing Capacity	$ 500,000,000
Interest rate description	borrowings, if any, will accrue interest at LIBOR plus 145 basis points
Line Of Credit Facility, Annual Facility Fee Description	the annual facility fee is 30 basis points
Letters of credit issued	$ 1,100,000
Borrowings outstanding under Partnership Credit Agreement	0
Partnership Credit Agreement [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 2,400,000,000
Indebtedness To Adjusted EBITDA Maximum	5.0
Indebtedness To Adjusted EBITDA Current	4.2
Line of Credit Facility Letter of Credit Sublimit	$ 100,000,000
Line of Credit Facility Swingline Sublimit	$ 150,000,000
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
Letters of credit issued	$ 14,000,000
Borrowings outstanding under Partnership Credit Agreement	0
Line of Credit Facility, Remaining Borrowing Capacity	$ 1,800,000,000
Indebtedness To Adjusted EBITDA From Acquisitions Maximum	5.5
Acquisition price threshold for increase in permitted debt to EBITDA covenant ratio	$ 25,000,000
Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial paper outstanding	576,000,000
Maximum Amount Of Commercial Paper	$ 2,400,000,000
Short-term Debt, Weighted Average Interest Rate | Rate	1.17%

XML

LONG-TERM DEBT (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 8,832,669	$ 8,486,820
Unamortized Portion of Terminated Swaps	21,045	21,904
Unamortized debt issuance costs and discounts	(72,787)	(74,492)
Long-term Debt, Current Maturities	(460,650)	(110,650)
Long-term debt, excluding current maturities	8,320,277	8,323,582
Payments to Acquire Interest in Subsidiaries and Affiliates		650,000
Parent Company [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 1,634,587	1,634,913
Parent Company [Member] | Note Payable from Public Offering Due 2022 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.25%
Long-term Debt, Gross	$ 547,397	$ 547,397
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	$ 500,000	$ 500,000
Proceeds from Debt, Net of Issuance Costs		487,100
Parent Company [Member] | Note Payables 1 due 2028 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.50%
Long-term Debt, Gross	$ 87,190	87,516
Parent Company [Member] | Note Payables 2 due 2028 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.875%
Long-term Debt, Gross	$ 100,000	100,000
Parent Company [Member] | Notes Payables due 2035 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.00%
Long-term Debt, Gross	$ 400,000	400,000
Partnership Interest [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 7,198,082	6,851,907
Partnership Interest [Member] | Note Payable from Public Offering Due 2016 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.25%
Long-term Debt, Gross	$ 0	650,000
Partnership Interest [Member] | Notes Payable due 2016 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.15%
Long-term Debt, Gross	$ 450,000	450,000
Partnership Interest [Member] | Note Payable from Public Offering Due 2017 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.00%
Long-term Debt, Gross	$ 400,000	400,000
Partnership Interest [Member] | Note Payable from Public Offering Due 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.20%
Long-term Debt, Gross	$ 425,000	425,000
Partnership Interest [Member] | Term Loan Agreement [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	1,000,000	0
Delayed-Draw Unsecured Senior Term Loan	$ 1,000,000
Debt Instrument, Interest Rate Terms	LIBOR plus 130 basis points
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate	1.74%
Proceeds from Debt, Net of Issuance Costs	$ 1,000,000
Partnership Interest [Member] | Notes Payables due 2019 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	8.625%
Long-term Debt, Gross	$ 500,000	$ 500,000
Partnership Interest [Member] | Note Payable from Public Offering Due 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.80%	3.80%
Long-term Debt, Gross	$ 300,000	$ 300,000
Partnership Interest [Member] | Note Payable 2 from Public Offering Due 2022 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.375%
Long-term Debt, Gross	$ 900,000	900,000
Partnership Interest [Member] | Note Payable from Public Offering Due 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.00%
Long-term Debt, Gross	$ 425,000	$ 425,000
Partnership Interest [Member] | Note Payable from Public Offering Due 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.90%	4.90%
Long-term Debt, Gross	$ 500,000	$ 500,000
Partnership Interest [Member] | Notes Payables due 2036 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.65%
Long-term Debt, Gross	$ 600,000	600,000
Partnership Interest [Member] | Notes Payables due 2037 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.85%
Long-term Debt, Gross	$ 600,000	600,000
Partnership Interest [Member] | Note Payable from Public Offering Due 2041 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.125%
Long-term Debt, Gross	$ 650,000	650,000
Partnership Interest [Member] | Note Payable from Public Offering Due 2043 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.20%
Long-term Debt, Gross	$ 400,000	400,000
Guardian Pipeline [Member] | Notes Payables 1 due 2022 [Member]
Debt Instrument [Line Items]
Long-term Debt, Weighted Average Interest Rate	7.85%
Long-term Debt, Gross	$ 48,082	51,907
Senior Notes [Member] | Partnership Interest [Member]
Debt Instrument [Line Items]
Senior Notes, Noncurrent		800,000
Proceeds from Debt, Net of Issuance Costs		$ 792,300

XML

EQUITY (Details) - $ / shares	3 Months Ended				6 Months Ended
	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Common Stock, Dividends, Per Share, Cash Paid		$ 0.615	$ 0.615		$ 1.230	$ 1.210
Common Stock, Dividends, Per Share, Declared		$ 0.615		$ 0.605	$ 1.23	$ 1.21
Subsequent Event [Member]
Common Stock, Dividends, Per Share, Declared	$ 0.615
Dividends Payable, Date of Record	Aug. 08, 2016
Dividends Payable, Date to be Paid	Aug. 14, 2016

XML

ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Unrealized gains (losses) on risk-management assets/liabilities - January 1, 2016			$ (42,199)
Pension and postretirement benefit plan obligation - January 1, 2016			(84,543)
Unrealized gains (losses) of unconsolidated affiliates - January 1, 2016			(500)
Accumulated other comprehensive loss - January 1, 2016			(127,242)
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net			(27,813)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, before Reclassification Adjustments, Net of Tax			6
Other Comprehensive Income (Loss), Amount Attributable to Equity Method Investments, before Reclassification Adjustments, Net of Tax			(2,950)
Other comprehensive income (loss) before reclassifications			(30,757)
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	$ (8,054)	$ (11,041)	(16,579)	$ (20,271)
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI for Other Comprehensive Income Attributable to Equity Method Investments, Net of Tax			0
Other Comprehensive Income (Loss), Reclassification Adjustment included in Net Income, Net of Tax	(552)	(100)	(1,247)	161
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax, Portion Attributable to Parent			(32,159)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	1,552	2,441	3,105	4,879
Other Comprehensive Income (Loss), Portion Attributable to Equity Method Investments, Net of Tax			(2,950)
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent			(32,004)
Unrealized gains (losses) on risk-management assets/liabilities - June 30, 2016	(74,358)		(74,358)
Pension and postretirement benefit plan obligation - June 30, 2016	(81,438)		(81,438)
Unrealized gains (losses) of unconsolidated affiliates - June 30, 2016	(3,450)		(3,450)
Accumulated other comprehensive loss - June 30, 2016	(159,246)		(159,246)
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Tax	1,193	1,439	2,469	2,664
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	(2,101)	(2,518)	(4,346)	(4,676)
Accumulated Defined Benefit Plans Adjustment [Member]
Other Comprehensive (Income) Loss, Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, Net of Tax	1,549	2,418	3,099	4,837
Defined Benefit Plan, Future Amortization of Gain (Loss)	2,997	4,423	5,995	8,846
Defined Benefit Plan, Future Amortization of Prior Service Cost (Credit)	(415)	(392)	(830)	(784)
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Gain (Loss), before Tax	2,582	4,031	5,165	8,062
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Gain (Loss), Tax	(1,033)	(1,613)	(2,066)	(3,225)
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	(9,247)	(12,480)	(19,048)	(22,935)
Tax Expense [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Tax	1,193	1,439	2,469	2,664
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	(8,054)	(11,041)	(16,579)	(20,271)
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	(5,953)	(8,523)	(12,233)	(15,595)
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	(14,049)	(17,078)	(28,548)	(31,250)
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	$ 4,802	$ 4,598	$ 9,500	$ 8,315

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EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Basic EPS from Continuing Operations [Abstract]
Income from continuing operations attributable to ONEOK available for common stock	$ 86,171	$ 76,645	$ 170,569	$ 137,589
Weighted Average number of share, basic (in shares)	211,075	210,204	210,928	210,059
Per share amount, basic (in dollars per shares)	$ 0.41	$ 0.36	$ 0.81	$ 0.65
Diluted EPS from continuing operations [Abstract]
Effect of dilutive securities	$ 0	$ 0	$ 0	$ 0
Effect of dilutive securities, number of shares (in shares)	1,543	273	735	427
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$ 86,171	$ 76,645	$ 170,569	$ 137,589
Weighted Average number of share, diluted (in shares)	212,618	210,477	211,663	210,486
Per Share amount, diluted (in dollars per share)	$ 0.41	$ 0.36	$ 0.81	$ 0.65

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EMPLOYEE BENEFIT PLANS (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Pension Benefits [Member]
Components of net periodic benefit cost
Service cost	$ 1,622	$ 1,887	$ 3,244	$ 3,774
Interest cost	4,947	4,546	9,894	9,092
Expected return on assets	(5,077)	(5,213)	(10,154)	(10,426)
Amortization of unrecognized prior service cost	0	23	0	46
Amortization of net loss	2,736	3,987	5,473	7,974
Net periodic benefit cost	4,228	5,230	8,457	10,460
Postretirement Benefits [Member]
Components of net periodic benefit cost
Service cost	149	186	298	372
Interest cost	601	587	1,202	1,173
Expected return on assets	(531)	(564)	(1,062)	(1,128)
Amortization of unrecognized prior service cost	(415)	(415)	(830)	(830)
Amortization of net loss	261	436	522	872
Net periodic benefit cost	$ 65	$ 230	$ 130	$ 459

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UNCONSOLIDATED AFFILIATES (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Equity in net earnings from investments	$ 32,372	$ 30,040	$ 65,286	$ 60,961
Accounts Payable, Related Parties, Current	12,200		12,200			$ 8,000
Income Statement
Operating revenues	142,631	125,738	279,203	255,319
Operating expenses	66,674	55,959	125,373	113,538
Net income	69,420	62,643	141,457	129,002
Proceeds from Equity Method Investment, Dividends or Distributions, Total	62,024	41,354	108,577	80,783
Roadrunner Gas Transmission [Member]
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments			20,000
Northern Border Pipeline [Member]
Schedule of Equity Method Investments [Line Items]
Equity in net earnings from investments	15,723	15,273	34,397	34,975
Overland Pass Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Equity in net earnings from investments	13,608	9,623	26,912	16,510
Other Unconsolidated Affiliate [Member]
Schedule of Equity Method Investments [Line Items]
Equity in net earnings from investments	3,041	5,144	3,977	9,476
Unconsolidated Affiliates [Member]
Income Statement
Costs and operating expenses with equity method investees	$ 34,700	$ 25,900	$ 68,300	$ 45,800
Scenario, Forecast [Member] | Roadrunner Gas Transmission [Member]
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments					$ 45,000

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ONEOK PARTNERS (Details) - USD ($) $ / shares in Units, $ in Thousands, shares in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Related Party Transaction [Line Items]
Ownership Interest			41.20%
Common units	41.3		41.3
Class B units	73.0		73.0
Assets, Current	$ 1,281,188		$ 1,281,188		$ 975,210
Property, Plant and Equipment, Net	12,484,622		12,484,622		12,373,989
Investments and Other Noncurrent Assets	2,057,090		2,057,090		2,096,912
Assets	15,822,900	$ 15,651,180	15,822,900	$ 15,651,180	15,446,111
Liabilities, Current	2,188,421		2,188,421		1,638,266
Long-term debt, excluding current maturities	8,320,277		8,320,277		8,323,582
Liabilities, Other than Long-term Debt, Noncurrent	1,822,025		1,822,025		1,717,927
Aggregate Amount Of Common Units Available For Issuance And Sale Under Equity Distribution Agreement			650,000
Remaining Capacity of At The Market Equity Program	138,000		$ 138,000
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.
ONEOK [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	100,800	$ 86,700	$ 189,900	$ 176,300
General Partner [Member]
Related Party Transaction [Line Items]
Ownership Interest			2.00%
Limited Partner [Member]
Related Party Transaction [Line Items]
Ownership Interest			39.20%
Assets, Current	1,096,107		$ 1,096,107		883,164
Property, Plant and Equipment, Net	12,372,176		12,372,176		12,256,791
Investments and Other Noncurrent Assets	1,749,593		1,749,593		1,787,631
Assets	15,217,876		15,217,876		14,927,586
Liabilities, Current	2,140,793		2,140,793		1,580,300
Long-term debt, excluding current maturities	6,691,950		6,691,950		6,695,312
Liabilities, Other than Long-term Debt, Noncurrent	183,200		183,200		154,631
Liabilities	$ 9,015,943		$ 9,015,943		$ 8,430,243
Distribution Paid [Member]
Related Party Transaction [Line Items]
Distribution per unit	$ 0.79	$ 0.79	$ 1.58	$ 1.58
General Partners' Capital Account, Period Distribution Amount	$ 107,198	$ 95,844	$ 214,396	$ 191,037
Total distributions	333,000	297,729	666,001	593,435
Distribution Paid [Member] | ONEOK [Member]
Related Party Transaction [Line Items]
Limited partner distributions to ONEOK	90,323	73,302	180,646	146,604
Distribution Paid [Member] | General Partner [Member]
Related Party Transaction [Line Items]
General partner distributions	6,660	5,955	13,320	11,869
Incentive distributions	100,538	89,889	201,076	179,168
Distribution Paid [Member] | Limited Partner [Member]
Related Party Transaction [Line Items]
Partners Capital Account Distributions to Other Unitholders	$ 135,479	$ 128,583	$ 270,959	$ 255,794
Distribution Declared [Member]
Related Party Transaction [Line Items]
Distribution per unit	$ 0.79	$ 0.79	$ 1.58	$ 1.58
Distribution Made To Member Or Limited Parter Annualized Quarterly Distribution	$ 3.16
Distribution Made to Limited Partner, Distribution Date	Aug. 14, 2016
Distribution Made to Limited Partner, Date of Record	Aug. 08, 2016
General Partners' Capital Account, Period Distribution Amount	$ 107,198	$ 97,875	$ 214,396	$ 193,719
Total distributions	333,000	304,039	666,001	601,768
Distribution Declared [Member] | ONEOK [Member]
Related Party Transaction [Line Items]
Limited partner distributions to ONEOK	90,323	73,302	180,646	146,604
Distribution Declared [Member] | General Partner [Member]
Related Party Transaction [Line Items]
General partner distributions	6,660	6,081	13,320	12,036
Incentive distributions	100,538	91,794	201,076	181,683
Distribution Declared [Member] | Limited Partner [Member]
Related Party Transaction [Line Items]
Partners Capital Account Distributions to Other Unitholders	$ 135,479	$ 132,862	$ 270,959	$ 261,445
Private Placement [Member]
Related Party Transaction [Line Items]
Partners' Capital Account, Units, Sold in Private Placement					21.5
Per Unit Offering Price Under Private Placement					$ 30.17
Partners' Capital Account, Contributions					$ 15,300
Partners Capital Account Units Sold Under Equity Distribution Agreement					3.3
Proceeds from Sale of Interest in Partnership Unit					$ 749,000
Issued Under Equity Distribution Agreement [Member]
Related Party Transaction [Line Items]
Partners Capital Account Units Sold Under Equity Distribution Agreement	0.0	5.5	0.0	7.2	10.5
Proceeds from Sale of Interest in Partnership Unit		$ 208,100		$ 279,700	$ 381,600
General Partner [Member]
Related Party Transaction [Line Items]
Ownership Interest			2.00%

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DISCONTINUED OPERATIONS (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Accumulated charges attributable to exit activities, at beginning of period	$ 36.3	$ 73.8
Settlements	(11.6)	(22.4)
Accretion	0.3	0.6
Accumulated charges attributable to exit activities, at end of period	25.0	$ 52.0
Effect on future cash flows, amount	25.0
2016 [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Effect on future cash flows, amount	7.0
2017 [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Effect on future cash flows, amount	10.0
2018 [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Effect on future cash flows, amount	4.0
2019 - 2023 [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Effect on future cash flows, amount	$ 4.0

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SEGMENTS Part 1 (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Segment Reporting Information [Line Items]
Segment Reporting, Disclosure of Major Customers	For the three months ended June 30, 2016, ONEOK Partners had no single customer from which we received 10 percent or more of our consolidated revenues.	For the three months ended June 30, 2015, ONEOK Partners had one customer, BP p.l.c. or its affiliates, from which it received $224.6 million in total revenue from all of its operating segments, or approximately 11 percent of our consolidated revenues.	For the six months ended June 30, 2016, ONEOK Partners had one customer, BP p.l.c. or its affiliates, from which it received $396.5 million in total revenue from all of its operating segments, or approximately 10 percent of our consolidated revenues.	For the six months ended June 30, 2015, ONEOK Partners had one customer, BP p.l.c. or its affiliates, from which it received $409.5 million in total revenue from all of its operating segments, or approximately 10 percent of our consolidated revenues.
Total revenues	$ 2,134,107	$ 2,128,052	$ 3,908,566	$ 3,933,358
Cost of sales and fuel (exclusive of items shown separately below)	1,527,323	1,603,093	2,723,061	2,946,957
Operating costs	191,839	165,350	368,854	344,368
Depreciation and amortization	99,247	86,987	193,725	172,942
(Gain) loss on sale of assets	413	(122)	(3,793)	(116)
Operating Income	315,285	272,744	626,719	469,207
Equity in net earnings from investments	32,372	30,040	65,286	60,961
Investments in unconsolidated affiliates	913,813	1,146,407	913,813	1,146,407	$ 948,221
Total Assets	15,822,900	15,651,180	15,822,900	15,651,180	15,446,111
Noncontrolling interests in consolidated subsidiaries	3,254,748	3,481,851	3,254,748	3,481,851	$ 3,430,538
Capital expenditures	136,843	285,601	333,254	629,448
Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Total revenues	476,759	460,062	908,770	915,685
Cost of sales and fuel (exclusive of items shown separately below)	299,991	322,927	566,291	653,858
Operating costs	69,304	63,550	138,910	132,760
Depreciation and amortization	46,413	35,952	88,264	71,749
(Gain) loss on sale of assets	(240)	(195)	(1,485)	(196)
Operating Income	61,291	37,828	116,790	57,514
Equity in net earnings from investments	2,576	4,922	5,391	9,161
Investments in unconsolidated affiliates	68,854	252,468	68,854	252,468
Total Assets	5,222,225	5,007,456	5,222,225	5,007,456
Noncontrolling interests in consolidated subsidiaries	0	4,065	0	4,065
Capital expenditures	84,674	205,434	226,171	460,735
Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Total revenues	1,871,993	1,848,875	3,359,383	3,344,967
Cost of sales and fuel (exclusive of items shown separately below)	1,525,234	1,535,492	2,682,184	2,764,357
Operating costs	83,769	77,410	156,951	159,656
Depreciation and amortization	40,696	39,433	81,402	78,727
(Gain) loss on sale of assets	(71)	73	(7)	81
Operating Income	222,365	196,467	438,853	342,146
Equity in net earnings from investments	13,904	9,693	27,251	16,673
Investments in unconsolidated affiliates	471,415	485,381	471,415	485,381
Total Assets	8,289,089	8,139,590	8,289,089	8,139,590
Noncontrolling interests in consolidated subsidiaries	159,049	162,494	159,049	162,494
Capital expenditures	20,779	59,087	54,986	132,553
Natural Gas Liquids [Member] | Natural Gas Liquids Regulated [Member]
Segment Reporting Information [Line Items]
Total revenues	297,500	227,500	579,300	437,300
Cost of sales and fuel (exclusive of items shown separately below)	112,700	98,900	219,500	184,600
Operating Income	120,800	73,600	236,400	138,500
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Total revenues	88,069	80,112	174,042	163,661
Cost of sales and fuel (exclusive of items shown separately below)	5,112	6,005	9,044	20,431
Operating costs	29,189	25,240	56,702	52,482
Depreciation and amortization	11,398	10,814	22,577	21,570
(Gain) loss on sale of assets	725	0	(2,239)	(1)
Operating Income	41,645	38,053	87,958	69,179
Equity in net earnings from investments	15,892	15,425	32,644	35,127
Investments in unconsolidated affiliates	373,544	408,558	373,544	408,558
Total Assets	1,856,128	1,848,779	1,856,128	1,848,779
Noncontrolling interests in consolidated subsidiaries	0	0	0	0
Capital expenditures	29,278	15,613	47,226	25,205
Natural Gas Pipelines [Member] | Natural Gas Pipelines Regulated [Member]
Segment Reporting Information [Line Items]
Total revenues	56,600	64,100	111,400	133,400
Cost of sales and fuel (exclusive of items shown separately below)	5,700	7,000	11,300	15,400
Operating Income	23,800	25,700	46,900	53,100
Corporate Elimination [Member]
Segment Reporting Information [Line Items]
Total revenues	(302,714)	(260,997)	(533,629)	(490,955)
Cost of sales and fuel (exclusive of items shown separately below)	(303,014)	(261,331)	(534,458)	(491,689)
Operating costs	9,577	(850)	16,291	(530)
Depreciation and amortization	740	788	1,482	896
(Gain) loss on sale of assets	(1)	0	(62)	0
Operating Income	(10,016)	396	(16,882)	368
Equity in net earnings from investments	0	0	0	0
Investments in unconsolidated affiliates	0	0	0	0
Total Assets	455,458	655,355	455,458	655,355
Noncontrolling interests in consolidated subsidiaries	3,095,699	3,315,292	3,095,699	3,315,292
Capital expenditures	2,112	5,467	4,871	10,955
Sales to unaffiliated customers
Segment Reporting Information [Line Items]
Total revenues	2,134,107	2,128,052	3,908,566	3,933,358
Sales to unaffiliated customers | Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Total revenues	293,071	279,498	610,117	567,514
Sales to unaffiliated customers | Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Total revenues	1,754,122	1,769,580	3,125,547	3,204,393
Sales to unaffiliated customers | Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Total revenues	86,401	78,429	171,875	160,359
Sales to unaffiliated customers | Corporate Elimination [Member]
Segment Reporting Information [Line Items]
Total revenues	513	545	1,027	1,092
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	183,688	180,564	298,653	348,171
Operating Segments [Member] | Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Total revenues	117,871	79,295	233,836	140,574
Operating Segments [Member] | Natural Gas Liquids [Member] | Natural Gas Liquids Regulated [Member]
Segment Reporting Information [Line Items]
Total revenues	258,400	186,400	489,200	351,700
Operating Segments [Member] | Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Total revenues	1,668	1,683	2,167	3,302
Operating Segments [Member] | Corporate Elimination [Member]
Segment Reporting Information [Line Items]
Total revenues	$ (303,227)	$ (261,542)	$ (534,656)	$ (492,047)

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SEGMENTS SEGMENTS Part 2 (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Reconciliation of Adjusted EBITDA to Net Income [Line Items]
Depreciation and amortization	$ (99,247)	$ (86,987)	$ (193,725)	$ (172,942)
Interest expense (net of capitalized interest)	(118,976)	(102,384)	(237,223)	(199,134)
Income taxes	(52,458)	(48,222)	(102,524)	(85,650)
AFUDC and other	(1,916)	2,954	(4,843)	(1,488)
Income from continuing operations	180,086	151,020	355,997	246,857
Income (loss) from discontinued operations, net of tax	(227)	(140)	(1,179)	(284)
Net income	179,859	150,880	354,818	246,573
Natural Gas Gathering And Processing [Member]
Reconciliation of Adjusted EBITDA to Net Income [Line Items]
Adjusted EBITDA	110,298	78,062	210,333	138,580
Depreciation and amortization	(46,413)	(35,952)	(88,264)	(71,749)
Natural Gas Liquids [Member]
Reconciliation of Adjusted EBITDA to Net Income [Line Items]
Adjusted EBITDA	276,611	244,591	546,780	437,246
Depreciation and amortization	(40,696)	(39,433)	(81,402)	(78,727)
Natural Gas Pipelines [Member]
Reconciliation of Adjusted EBITDA to Net Income [Line Items]
Adjusted EBITDA	68,542	65,234	142,881	135,946
Depreciation and amortization	(11,398)	(10,814)	(22,577)	(21,570)
Other Segments [Member]
Reconciliation of Adjusted EBITDA to Net Income [Line Items]
Adjusted EBITDA	$ (2,768)	$ (2,228)	$ (5,682)	$ (5,701)