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, 2014.

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 29, 2014, the Company had 208,002,586 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, 2014 and 2013	6
	Consolidated Statements of Comprehensive Income - Three and Six Months Ended June 30, 2014 and 2013	7
	Consolidated Balance Sheets - June 30, 2014, and December 31, 2013	8
	Consolidated Statements of Cash Flows - Six Months Ended June 30, 2014 and 2013	11
	Consolidated Statement of Changes in Equity - Six Months Ended June 30, 2014	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	63
Item 4.	Controls and Procedures	63
Part II.	Other Information
Item 1.	Legal Proceedings	63
Item 1A.	Risk Factors	63
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	64
Item 3.	Defaults Upon Senior Securities	64
Item 4.	Mine Safety Disclosures	64
Item 5.	Other Information	64
Item 6.	Exhibits	64
Signature		66

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, 2013
ASU	Accounting Standards Update
Bbl	Barrels, 1 barrel is equivalent to 42 United States gallons
Bbl/d	Barrels per day
BBtu/d	Billion British thermal units per day
Bcf	Billion cubic feet
Btu	British thermal units, a measure of the amount of heat required to raise the temperature of one pound of water one degree Fahrenheit
CFTC	Commodities Futures Trading Commission
Clean Air Act	Federal Clean Air Act, as amended
Clean Water Act	Federal Water Pollution Control Act Amendments of 1972, as amended
Dodd-Frank Act	Dodd-Frank Wall Street Reform and Consumer Protection Act of 2010
DOT	United States Department of Transportation
EBITDA	Earnings before interest expense, income taxes, depreciation and amortization
EPA	United States Environmental Protection Agency
Exchange Act	Securities Exchange Act of 1934, as amended
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
GAAP	Accounting principles generally accepted in the United States of America
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
MMBtu/d	Million British thermal units per day
MMcf/d	Million cubic feet per day
Moody’s	Moody’s Investors Service, Inc.
Natural Gas Policy Act	Natural Gas Policy Act of 1978, as amended
NGL(s)	Natural gas liquid(s)
NGL products	Marketable natural gas liquids purity products, such as ethane, ethane/propane mix, propane, iso-butane, normal butane and natural gasoline
NYMEX	New York Mercantile Exchange
NYSE	New York Stock Exchange
ONE Gas	ONE Gas, Inc.
ONEOK	ONEOK, Inc.
ONEOK Credit Agreement	ONEOK’s $300 million Amended and Restated Revolving Credit Agreement dated January 31, 2014
ONEOK Partners	ONEOK Partners, L.P.
ONEOK Partners Credit Agreement	ONEOK Partners’ $1.7 billion Amended and Restated Revolving Credit Agreement dated January 31, 2014
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

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Quarterly Report(s)	Quarterly Report(s) on Form 10-Q
S&P	Standard & Poor’s Ratings Services
SCOOP	South Central Oklahoma Oil Province
SEC	Securities and Exchange Commission
Securities Act	Securities Act of 1933, as amended
XBRL	eXtensible Business Reporting Language

5

PART I - FINANCIAL INFORMATION

ITEM 1.  FINANCIAL STATEMENTS

ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF INCOME
	Three Months Ended						Six Months Ended
	June 30,						June 30,
(Unaudited)	2014			2013			2014			2013
	(Thousands of dollars, except per share amounts)
Revenues
Commodity sales	$	2,715,109		$	2,447,411		$	5,521,838		$	4,646,205
Services	351,773			321,573			708,340			640,734
Total revenues	3,066,882			2,768,984			6,230,178			5,286,939
Cost of sales and fuel	2,571,402			2,356,226			5,224,071			4,503,074
Net margin	495,480			412,758			1,006,107			783,865
Operating expenses
Operations and maintenance	153,323			108,906			280,049			230,311
Depreciation and amortization	72,127			58,883			139,541			114,166
General taxes	18,699			16,859			41,084			36,589
Total operating expenses	244,149			184,648			460,674			381,066
Gain (loss) on sale of assets	(16		)	279			(1		)	320
Operating income	251,315			228,389			545,432			403,119
Equity earnings from investments (Note K)	25,435			26,421			59,094			52,276
Allowance for equity funds used during construction	1,253			5,656			12,224			14,743
Other income	3,213			2,734			4,622			8,356
Other expense	(1,392		)	(380		)	(26,926		)	(1,881		)
Interest expense (net of capitalized interest of $11,375, $11,359, $27,143 and $23,964, respectively)	(88,751		)	(66,120		)	(183,652		)	(130,606		)
Income before income taxes	191,073			196,700			410,794			346,007
Income taxes	(42,313		)	(42,923		)	(57,297		)	(81,727		)
Income from continuing operations	148,760			153,777			353,497			264,280
Income (loss) from discontinued operations, net of tax (Note B)	(8,009		)	(74,282		)	(6,235		)	(19,080		)
Net income	140,751			79,495			347,262			245,200
Less: Net income attributable to noncontrolling interests	79,161			78,576			192,157			131,760
Net income attributable to ONEOK	$	61,590		$	919		$	155,105		$	113,440
Amounts attributable to ONEOK:
Income from continuing operations	$	69,599		$	75,201		$	161,340		$	132,520
Income (loss) from discontinued operations	(8,009		)	(74,282		)	(6,235		)	(19,080		)
Net income	$	61,590		$	919		$	155,105		$	113,440
Basic earnings per share:
Income from continuing operations (Note I)	$	0.33		$	0.36		$	0.77		$	0.64
Income (loss) from discontinued operations	(0.04		)	(0.36		)	(0.03		)	(0.09		)
Net income	$	0.29		$	—		$	0.74		$	0.55
Diluted earnings per share:
Income from continuing operations (Note I)	$	0.33		$	0.36		$	0.77		$	0.63
Income (loss) from discontinued operations	(0.04		)	(0.36		)	(0.03		)	(0.09		)
Net income	$	0.29		$	—		$	0.74		$	0.54
Average shares (thousands)
Basic	209,403			206,143			209,267			205,811
Diluted	210,516			208,874			210,337			209,166
Dividends declared per share of common stock	$	0.56		$	0.36		$	0.96		$	0.72

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)	2014			2013			2014			2013
	(Thousands of dollars)
Net income	$	140,751		$	79,495		$	347,262		$	245,200
Other comprehensive income (loss), net of tax
Unrealized gains (losses) on energy marketing and risk-management assets/liabilities, net of tax of $3,596, $(13,840), $13,824 and $(9,882), respectively	(28,920		)	53,289			(78,846		)	39,637
Realized (gains) losses in net income, net of tax of $(1,202), $2,614, $(14,219) and $(2,081), respectively	7,511			(3,390		)	45,038			3,905
Unrealized holding gains (losses) on available-for-sale securities, net of tax of $25, $(168), $37 and $(130), respectively	(37		)	268			(113		)	206
Change in pension and postretirement benefit plan liability, net of tax of $(1,356), $4,340, $(3,923) and $9,048, respectively	2,033			(6,882		)	5,884			(14,344		)
Total other comprehensive income (loss), net of tax	(19,413		)	43,285			(28,037		)	29,404
Comprehensive income	121,338			122,780			319,225			274,604
Less: Comprehensive income attributable to noncontrolling interests	62,962			110,678			158,649			156,336
Comprehensive income attributable to ONEOK	$	58,376		$	12,102		$	160,576		$	118,268

See accompanying Notes to Consolidated Financial Statements.

7

ONEOK, Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS
	June 30,		December 31,
(Unaudited)	2014		2013
Assets	(Thousands of dollars)
Current assets
Cash and cash equivalents	$	358,560	$	145,565
Accounts receivable, net	1,097,008		1,109,510
Natural gas and natural gas liquids in storage	335,116		188,286
Commodity imbalances	93,070		80,481
Other current assets	118,545		133,010
Assets of discontinued operations (Note B)	57,356		747,872
Total current assets	2,059,655		2,404,724
Property, plant and equipment
Property, plant and equipment	11,737,291		10,970,256
Accumulated depreciation and amortization	1,866,627		1,738,302
Net property, plant and equipment	9,870,664		9,231,954
Investments and other assets
Investments in unconsolidated affiliates (Note K)	1,212,408		1,229,838
Goodwill and intangible assets	1,018,679		1,024,562
Other assets	193,032		224,353
Assets of discontinued operations (Note B)	30,100		3,626,050
Total investments and other assets	2,454,219		6,104,803
Total assets	$	14,384,538	$	17,741,481

See accompanying Notes to Consolidated Financial Statements.

8

ONEOK, Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS
(Continued)
	June 30,			December 31,
(Unaudited)	2014			2013
Liabilities and equity	(Thousands of dollars)
Current liabilities
Current maturities of long-term debt	$	10,650		$	10,650
Notes payable (Note E)	—			564,462
Accounts payable	1,271,539			1,273,102
Commodity imbalances	207,456			213,577
Accrued interest	105,099			109,099
Other current liabilities	190,289			103,752
Liabilities of discontinued operations (Note B)	66,138			455,688
Total current liabilities	1,851,171			2,730,330
Long-term debt, excluding current maturities (Note F)	7,196,988			7,753,657
Deferred credits and other liabilities
Deferred income taxes	1,253,099			1,146,562
Other deferred credits	237,468			217,522
Liabilities of discontinued operations (Note B)	52,481			1,048,230
Total deferred credits and other liabilities	1,543,048			2,412,314
Commitments and contingencies (Note M)
Equity (Note G)
ONEOK shareholders’ equity:
Common stock, $0.01 par value: authorized 600,000,000 shares; issued 245,811,180 shares and outstanding 207,999,517 shares at June 30, 2014; issued 245,811,180 shares and outstanding 206,618,877 shares at December 31, 2013	2,458			2,458
Paid-in capital	1,503,582			1,433,600
Accumulated other comprehensive loss (Note H)	(113,127		)	(121,987		)
Retained earnings	225,423			2,020,815
Treasury stock, at cost: 37,811,663 shares at June 30, 2014, and 39,192,303 shares at December 31, 2013	(961,911		)	(997,035		)
Total ONEOK shareholders’ equity	656,425			2,337,851
Noncontrolling interests in consolidated subsidiaries	3,136,906			2,507,329
Total equity	3,793,331			4,845,180
Total liabilities and equity	$	14,384,538		$	17,741,481

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)	2014			2013
	(Thousands of dollars)
Operating activities
Net income	$	347,262		$	245,200
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	150,895			182,076
Charges attributable to exit activities	1,739			113,780
Equity earnings from investments	(59,094		)	(52,276		)
Distributions received from unconsolidated affiliates	61,200			51,546
Deferred income taxes	57,191			68,468
Share-based compensation expense	17,288			19,018
Pension and postretirement benefit expense, net of contributions	12,729			5,187
Allowance for equity funds used during construction	(12,224		)	(14,743		)
Loss (gain) on sale of assets	1			(320		)
Other	—			(3,658		)
Changes in assets and liabilities:
Accounts receivable	17,504			190,633
Natural gas and natural gas liquids in storage	(40,122		)	82,018
Accounts payable	(3,426		)	(63,954		)
Commodity imbalances, net	(15,830		)	(57,885		)
Settlement of exit activities liabilities	(25,728		)	—
Accrued interest	(4,129		)	(1,843		)
Other assets and liabilities, net	31,051			25,034
Cash provided by operating activities	536,307			788,281
Investing activities
Capital expenditures (less allowance for equity funds used during construction)	(822,201		)	(1,060,333		)
Acquisition	(14,000		)	—
Contributions to unconsolidated affiliates	(1,063		)	(4,558		)
Distributions received from unconsolidated affiliates	16,449			17,958
Proceeds from sale of assets	319			3,333
Cash used in investing activities	(820,496		)	(1,043,600		)
Financing activities
Borrowing (repayment) of notes payable, net	(564,462		)	16,830
Issuance of ONE Gas, Inc. debt, net of discounts	1,199,994			—
ONE Gas, Inc. long-term debt financing costs	(9,663		)	—
Repayment of debt	(553,855		)	(3,888		)
Issuance of common stock	9,166			6,002
Issuance of common units, net of issuance costs	878,765			15,942
Dividends paid	(199,684		)	(147,982		)
Cash of ONE Gas, Inc. at separation	(60,000		)	—
Distributions to noncontrolling interests	(206,342		)	(181,522		)
Cash provided by (used in) financing activities	493,919			(294,618		)
Change in cash and cash equivalents	209,730			(549,937		)
Change in cash and cash equivalents included in discontinued operations	3,265			247
Change in cash and cash equivalents included in continuing operations	212,995			(549,690		)
Cash and cash equivalents at beginning of period	145,565			579,578
Cash and cash equivalents at end of period	$	358,560		$	29,888

See accompanying Notes to Consolidated Financial Statements.

11

ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
	ONEOK Shareholders’ Equity
(Unaudited)	Common Stock Issued	Common Stock		Paid-in Capital			Accumulated Other Comprehensive Income (Loss)
	(Shares)	(Thousands of dollars)
January 1, 2014	245,811,180	$	2,458	$	1,433,600		$	(121,987	)
Net income	—	—		—			—
Other comprehensive income (loss)	—	—		—			5,471
Common stock issued	—	—		(21,220		)	—
Common stock dividends - $0.96 per share	—	—		—			—
Issuance of common units of ONEOK Partners	—	—		127,125			—
Distribution of ONE Gas to shareholders (Note B)	—	—		—			3,389
Distributions to noncontrolling interests	—	—		—			—
Other	—	—		(35,923		)	—
June 30, 2014	245,811,180	$	2,458	$	1,503,582		$	(113,127	)

See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
(Continued)
	ONEOK Shareholders’ Equity
(Unaudited)	Retained Earnings			Treasury Stock			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity
	(Thousands of dollars)
January 1, 2014	$	2,020,815		$	(997,035	)	$	2,507,329		$	4,845,180
Net income	155,105			—			192,157			347,262
Other comprehensive income (loss)	—			—			(33,508		)	(28,037		)
Common stock issued	—			35,124			—			13,904
Common stock dividends - $0.96 per share	(199,684		)	—			—			(199,684		)
Issuance of common units of ONEOK Partners	—			—			677,270			804,395
Distribution of ONE Gas to shareholders (Note B)	(1,750,813		)	—			—			(1,747,424		)
Distributions to noncontrolling interests	—			—			(206,342		)	(206,342		)
Other	—			—			—			(35,923		)
June 30, 2014	$	225,423		$	(961,911	)	$	3,136,906		$	3,793,331

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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 presentation of the results for the interim periods presented.  All such adjustments are of a normal recurring nature. The 2013 year-end consolidated balance sheet data was derived from our audited financial statements but does not include all disclosures required by GAAP.  These unaudited consolidated financial statements should be read in conjunction with our audited consolidated financial statements in our Annual Report.

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

Organization and Nature of Operations - We are the sole general partner and own limited partner units of ONEOK Partners (NYSE: OKS), which together represent an aggregate 38.5 percent interest in ONEOK Partners at June 30, 2014. On January 31, 2014, we completed the separation of our natural gas distribution business into a stand-alone publicly traded company called ONE Gas. On March 31, 2014, we completed the accelerated wind down of our energy services business. The results of operations for our former natural gas distribution and energy services businesses have been classified as discontinued operations for all periods presented. Following the ONE Gas separation and wind down of our energy services business, our primary source of income and cash flow is generated from our investment in ONEOK Partners. See Note B for additional information.

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

Change in Reportable Segments - Following the separation of our natural gas distribution business into ONE Gas and wind down of our energy services business, our chief operating decision maker reviews the financial performance of each of the three businesses of ONEOK Partners on a regular basis to assess the performance of, and allocate resources to, ONEOK Partners. As a result, our reportable segments have changed to reflect the three business segments of ONEOK Partners, which include the following:

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

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

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

We have reflected the change in reporting segments for all periods presented. See Note N for additional information.

Income Taxes - Deferred income taxes are recorded for the difference between the financial statement and income tax basis of assets and liabilities and carryforward items, based on income tax laws and rates existing at the time the temporary differences are expected to reverse. Deferred tax liabilities and deferred income tax expense were reduced by $34.6 million in the first quarter 2014 due to a reduction in our estimate of the effective state income tax rate to reflect a change in the mix of taxable income in the states in which we now operate, resulting from the separation of our former natural gas distribution business and the wind down of our energy services business. We also recorded a valuation allowance of $8.2 million in the first quarter 2014 for state tax credits as it is more likely than not that we will not be able to utilize these credits as a result of the separation of our former natural gas distribution business and the wind down of our energy services business. Together, these adjustments resulted in a net $26.4 million reduction in deferred tax liabilities and deferred income tax expense.

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

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In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers,” which outlines the principles an entity must apply to measure and recognize revenue for entities that enter into contracts to provide goods or services to their customers. The core principle is that an entity should recognize revenue at an amount that reflects the consideration to which the entity expects to be entitled in exchange for transferring goods or services to a customer. The amendments also require more extensive disaggregated revenue disclosures in interim and annual financial statements. This update will be effective for interim and annual periods that begin on or after December 15, 2016, with either retrospective application for all periods presented or retrospective application with a cumulative effect adjustment. We will adopt this guidance beginning in the first quarter 2017, and we are evaluating the impact on us.

B. DISCONTINUED OPERATIONS

Separation of ONE Gas - On January 31, 2014, we completed the separation of ONE Gas. ONE Gas consists of ONEOK’s former natural gas distribution business that includes Kansas Gas Service, Oklahoma Natural Gas and Texas Gas Service. ONEOK shareholders of record at the close of business on January 21, 2014, retained their shares of ONEOK stock and received one share of ONE Gas stock for every four shares of ONEOK stock owned in a transaction that was tax-free to ONEOK and its shareholders. ONE Gas shares were distributed following the close of business on January 31, 2014. We retained no ownership interest in ONE Gas. On the date of the separation, ONE Gas consisted of approximately $4.3 billion of assets, $2.6 billion of liabilities and $1.7 billion of equity. Excluding cash of ONE Gas at separation, the separation was accounted for as a noncash activity. These balances include certain estimates expected to be finalized in 2014.

Wind Down of Energy Services Business - On March 31, 2014, we completed the accelerated wind down of our energy services business. We executed an agreement in the first quarter 2014 to release a nonaffiliated, third-party natural gas storage contract to a third party, resulting in a noncash charge of $1.7 million. All of the remaining natural gas transportation and storage contracts not previously released or assigned expired on their own terms on or before March 31, 2014. Our energy services business continued to serve its contracted premium-services until these remaining contracts expired on or before March 31, 2014. Our energy services business was classified as discontinued operations, effective at the close of business March 31, 2014, when substantially all operations ceased.

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

	Six Months Ended
	June 30, 2014
	(Millions of dollars)
Beginning balance	$	122.0
Noncash charges	1.7
Settlements	(25.7		)
Accretion	1.1
Ending balance	$	99.1

We expect future cash payments associated with previously released transportation and storage capacity from the wind down of our energy services business on an after-tax basis to be approximately $60 million, with approximately $15 million paid in the remainder of 2014, $23 million in 2015, $11 million in 2016 and $11 million over the period 2017 through 2023.

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Results of Operations of Discontinued Operations - The results of operations for our former natural gas distribution and energy services businesses have been reported as discontinued operations for all periods presented. The tables below provide selected financial information reported in discontinued operations in the Consolidated Statements of Income:

	Three Months Ended											Six Months Ended
	June 30, 2014											June 30, 2014
	Natural Gas Distribution				Energy Services				Total			Natural Gas Distribution				Energy Services			Total
	(Thousands of dollars)
Revenues	$	—			$	—			$	—		$	287,249			$	353,404		$	640,653
Cost of sales and fuel	—				—				—			190,893				364,648			555,541
Net margin	—				—				—			96,356				(11,244		)	85,112
Operating costs	1,416			(a)	1,395			(c)	2,811			60,847			(a)	4,522			65,369
Depreciation and amortization	—				—				—			11,035				319			11,354
Operating income (loss)	(1,416		)		(1,395		)		(2,811		)	24,474				(16,085		)	8,389
Other income (expense), net	—				—				—			(888		)		(7		)	(895		)
Interest expense, net	—				—				—			(4,592		)		(413		)	(5,005		)
Income taxes	(5,745		)	(b)	547				(5,198		)	(16,415		)		7,691			(8,724		)
Income (loss) from discontinued operations, net	$	(7,161	)		$	(848	)		$	(8,009	)	$	2,579			$	(8,814	)	$	(6,235	)

(a) - Includes approximately $1.3 million and $23.0 million for the three and six months ended June 30, 2014, respectively, of costs related to the ONE Gas separation.

(b) - Reflects revision of estimates for income taxes related to the ONE Gas separation.

(c) - Represents primarily accretion expense.

	Three Months Ended									Six Months Ended
	June 30, 2013									June 30, 2013
	Natural Gas Distribution			Energy Services			Total			Natural Gas Distribution			Energy Services			Total
	(Thousands of dollars)
Revenues	$	311,606		$	359,984		$	671,590		$	947,537		$	830,179		$	1,777,716
Cost of sales and fuel	133,163			497,799			630,962			517,420			967,320			1,484,740
Net margin	178,443			(137,815		)	40,628			430,117			(137,141		)	292,976
Operating costs	104,382			3,479			107,861			217,785			8,367			226,152
Depreciation and amortization	32,904			68			32,972			67,771			139			67,910
Operating income (loss)	41,157			(141,362		)	(100,205		)	144,561			(145,647		)	(1,086		)
Other income (expense), net	(44		)	17			(27		)	575			45			620
Interest expense, net	(15,163		)	(448		)	(15,611		)	(30,469		)	(1,093		)	(31,562		)
Income taxes	(10,513		)	52,074			41,561			(40,801		)	53,749			12,948
Income (loss) from discontinued operations, net	$	15,437		$	(89,719	)	$	(74,282	)	$	73,866		$	(92,946	)	$	(19,080	)

Prior to the ONE Gas separation, natural gas sales and transportation and storage services provided to our former natural gas distribution business by ONEOK Partners were $14.3 million for the three months ended June 30, 2013, and $7.5 million and $28.1 million for the six months ended June 30,2014 and 2013, respectively. Prior to February 1, 2014, these revenues and related costs were eliminated in consolidation. Beginning February 1, 2014, these revenues represent third-party transactions with ONE Gas and are not eliminated in consolidation, as such sales and services have continued subsequent to the separation and are expected to continue in future periods.

Prior to the completion of the energy services wind down, natural gas sales and transportation and storage services provided to our energy services business by ONEOK Partners were $77.0 million for the three months ended June 30, 2013, and $46.0 million and $145.9 million for the six months ended June 30,2014 and 2013, respectively. While these transactions were eliminated in consolidation in previous periods, they are reflected now as affiliate transactions and not eliminated in consolidation as these transactions have continued with third parties.

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Statement of Financial Position of Discontinued Operations - The following table presents the carrying value of assets and liabilities of our former natural gas distribution and energy services businesses included in assets and liabilities of discontinued operations in the Consolidated Balance Sheets for the period presented:

	December 31, 2013
	Natural Gas Distribution		Energy Services			Total
	(Thousands of dollars)
Assets
Cash and cash equivalents	$	3,535	$	213		$	3,748
Accounts receivable, net	368,214		87,315			455,529
Natural gas and natural gas liquids in storage	166,128		62,663			228,791
Other current assets	30,328		29,476			59,804
Net property, plant and equipment	3,065,272		279			3,065,551
Goodwill	157,953		—			157,953
Other assets	402,161		385			402,546
Total assets	$	4,193,591	$	180,331		$	4,373,922
Liabilities
Current maturities of long-term debt	$	6	$	—		$	6
Accounts payable	168,785		77,287			246,072
Other current liabilities	168,964		40,646			209,610
Long-term debt, excluding current maturities	1,318		—			1,318
Deferred income taxes	826,921		(35,221		)	791,700
Other deferred credits	184,214		70,998			255,212
Total liabilities	$	1,350,208	$	153,710		$	1,503,918

At June 30, 2014, the major classes of assets and liabilities in discontinued operations related to our former energy services business. These amounts consisted of current assets, which included income taxes receivable of $37.7 million and deferred tax assets of $14.5 million; noncurrent assets, which included deferred tax assets of $29.2 million; current liabilities, which included capacity release obligations of $46.2 million and deferred tax liabilities of $12.2 million; and noncurrent liabilities, which included $52.9 million of noncurrent capacity release obligations.

C. 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 groups of financial assets and liabilities consistent with how a market participant would price the net risk exposure at the measurement date.

In the first quarter 2014, outstanding commodity derivative positions with third parties entered into by our energy services business on ONEOK Partners’ behalf were transferred to ONEOK Partners. Beginning in the second quarter 2014, ONEOK Partners enters into all commodity derivative financial contracts directly with unaffiliated third parties.

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

In addition, as prescribed by the income approach, ONEOK Partners computes the fair value of its derivative portfolio by discounting the projected future cash flows from its derivative assets and liabilities to present value using interest-rate yields to

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calculate present-value discount factors derived from LIBOR, Eurodollar futures and interest-rate swaps.  ONEOK Partners also takes 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.  It considers current market data in evaluating counterparties’, as well as its own, nonperformance risk, net of collateral, by using specific and sector bond yields and monitoring the credit default swap markets.  Although ONEOK Partners uses its best estimates to determine the fair value of the derivative contracts it has executed, the ultimate market prices realized could differ from its estimates, and the differences could be material.

The fair value of ONEOK Partners’ forward-starting interest-rate swaps is 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 and ONEOK Partners utilize a fair value hierarchy to classify fair value amounts recognized or disclosed in the 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 in active markets, including NYMEX-settled prices and actively quoted prices for equity securities. These balances are comprised predominantly of exchange-traded derivative contracts for natural gas and crude oil. Also included in Level 1 are equity securities.

• 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 basis curves that incorporate observable and unobservable market data, NGL price curves from broker quotes, market volatilities derived from the most recent NYMEX close spot prices and forward LIBOR curves, and adjustments for the credit risk of ONEOK Partners’ counterparties.  ONEOK Partners corroborates the data on which its fair value estimates are based using its 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.  ONEOK Partners does not believe that its Level 3 fair value estimates have a material impact on its results of operations, as the majority of its derivatives are accounted for as hedges for which ineffectiveness is not material.

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

	June 30, 2014
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Assets
Derivatives
Commodity contracts
Financial contracts	$	945		$	—		$	506		$	1,451		$	(1,451	)	$	—
Physical contracts	—			—			1,526			1,526			(933		)	593
Interest-rate contracts	—			26,649			—			26,649			—			26,649
Total derivatives	945			26,649			2,032			29,626			(2,384		)	27,242
Available-for-sale investment securities (c)	1,419			—			—			1,419			—			1,419
Total assets	$	2,364		$	26,649		$	2,032		$	31,045		$	(2,384	)	$	28,661
Liabilities
Derivatives
Commodity contracts
Financial contracts	$	(3,814	)	$	(2,865	)	$	(1,120	)	$	(7,799	)	$	4,934		$	(2,865	)
Physical contracts	—			—			(2,225		)	(2,225		)	933			(1,292		)
Interest-rate contracts	—			(19,240		)	—			(19,240		)	—			(19,240		)
Total liabilities	$	(3,814	)	$	(22,105	)	$	(3,345	)	$	(29,264	)	$	5,867		$	(23,397	)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis.  ONEOK Partners nets derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and ONEOK Partners.  At June 30, 2014, ONEOK Partners held no cash collateral and posted $3.5 million cash collateral with various counterparties.

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

(c) - Available-for-sale investment securities represent assets of ONEOK.

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	December 31, 2013
	Level 1		Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Assets
Derivatives
Commodity contracts
Financial contracts	$	—	$	3,657		$	2,812		$	6,469		$	(1,746	)	$	4,723
Physical contracts	—		—			2,023			2,023			(946		)	1,077
Interest-rate contracts	—		54,503			—			54,503			—			54,503
Total derivatives	—		58,160			4,835			62,995			(2,692		)	60,303
Available-for-sale investment securities (c)	1,569		—			—			1,569			—			1,569
Total assets	$	1,569	$	58,160		$	4,835		$	64,564		$	(2,692	)	$	61,872
Liabilities
Derivatives
Commodity contracts
Financial contracts	$	—	$	(2,953	)	$	(2,154	)	$	(5,107	)	$	1,746		$	(3,361	)
Physical contracts	—		—			(3,463		)	(3,463		)	946			(2,517		)
Total derivative liabilities	$	—	$	(2,953	)	$	(5,617	)	$	(8,570	)	$	2,692		$	(5,878	)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis.  ONEOK Partners nets derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and ONEOK Partners. At December 31, 2013, we and ONEOK Partners had no cash collateral held or posted.

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

(c) - Available-for-sale investment securities represent assets of ONEOK.

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

	Three Months Ended						Six Months Ended
	June 30,						June 30,
Derivative Assets (Liabilities)	2014			2013			2014			2013
	(Thousands of dollars)
Net assets (liabilities) at beginning of period	$	1,972		$	(4,855	)	$	(782	)	$	(2,423	)
Total realized/unrealized gains (losses):
Included in earnings (a)	33			—			(895		)	—
Included in other comprehensive income (loss)	(3,318		)	12,537			(3,370		)	10,105
Purchases, issuances and settlements	—			—			3,734			—
Net assets (liabilities) at end of period	$	(1,313	)	$	7,682		$	(1,313	)	$	7,682

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

Realized/unrealized gains (losses) include the realization of ONEOK Partners’ derivative contracts through maturity. During the three and six months ended June 30, 2014 and 2013, 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 the period were not material.

ONEOK Partners recognizes 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, 2014 and 2013, there were no transfers between levels.

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

The estimated fair value of our consolidated long-term debt, including current maturities, was $8.0 billion, and $8.2 billion at June 30, 2014, and December 31, 2013, respectively.  The book value of long-term debt, including current maturities, was $7.2

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billion and $7.8 billion at June 30, 2014, and December 31, 2013, 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.

D. RISK-MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

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

Commodity-price risk - ONEOK Partners is exposed to the risk of loss in cash flows and future earnings arising from adverse changes in the price of natural gas, NGLs and condensate.  ONEOK Partners uses the following commodity derivatives instruments to mitigate the 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 typically are nontransferable and only can be canceled with the consent of both parties; and

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

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

The Natural Gas Liquids segment is exposed to basis risk primarily as a result of the relative value of NGL purchases at one location and sales at another location. To a lesser extent, ONEOK Partners 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. ONEOK Partners utilizes physical-forward contracts to reduce the impact of price fluctuations related to NGLs. At June 30, 2014, and December 31, 2013, there were no financial derivative instruments used in ONEOK Partners’ natural gas liquids operations.

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 as fuel in operations by these pipelines differs from the amount provided by its customers, ONEOK Partners’ pipelines must buy or sell natural gas, or store or use natural gas from inventory, which can expose it to commodity-price risk depending on the regulatory treatment for this activity. To the extent that commodity-price risk in its Natural Gas Pipelines segment is not mitigated by fuel cost-recovery mechanisms, ONEOK Partners uses physical-forward sales or purchases to reduce the impact of price fluctuations related to natural gas. At June 30, 2014, and December 31, 2013, there were no financial derivative instruments used in ONEOK Partners’ natural gas pipeline operations.

Interest-rate risk - We and ONEOK Partners manage interest-rate risk through the use of fixed-rate debt, floating-rate debt and interest-rate swaps. Interest-rate swaps are agreements to exchange interest payments at some future point based on specified notional amounts. ONEOK Partners has forward-starting interest-rate swaps designated as cash flow hedges of the variability of interest payments on a portion of forecasted debt issuances that may result from changes in the benchmark interest rate before the debt is issued. At June 30, 2014, ONEOK Partners had forward-starting interest-rate swaps with notional amounts totaling $400 million with settlement dates greater than 12 months and $500 million with settlement dates less than 12 months.

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

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The table below summarizes the various ways in which we and ONEOK Partners account for 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

Under certain conditions, we and ONEOK Partners designate derivative instruments as a hedge of exposure to changes in fair values or cash flows. We and ONEOK Partners formally document all relationships between hedging instruments and hedged items, as well as risk-management objectives, strategies for undertaking various hedge transactions and methods for assessing and testing correlation and hedge ineffectiveness. We and ONEOK Partners specifically identify the forecasted transaction that has been designated as the hedged item in a cash flow hedge relationship. We and ONEOK Partners assess the effectiveness of hedging relationships quarterly by performing an effectiveness analysis on fair value and cash flow hedging relationships to determine whether the hedge relationships are highly effective on a retrospective and prospective basis.  ONEOK Partners also documents normal purchases and normal sales transactions expected to result in physical delivery and that are exempted from derivative accounting treatment.

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

	June 30, 2014					December 31, 2013
	Assets (a)		(Liabilities) (a)			Assets (a)		(Liabilities) (a)
	(Thousands of dollars)
Derivatives designated as hedging instruments
Commodity contracts
Financial contracts	$	1,451	$	(7,799	)	$	6,469	$	(5,107	)
Physical contracts	1,462		(2,225		)	1,064		(3,463		)
Interest-rate contracts	26,649		(19,240		)	54,503		—
Total derivatives designated as hedging instruments	29,562		(29,264		)	62,036		(8,570		)
Derivatives not designated as hedging instruments
Commodity contracts
Physical contracts	64		—			959		—
Total derivatives not designated as hedging instruments	64		—			959		—
Total derivatives	$	29,626	$	(29,264	)	$	62,995	$	(8,570	)

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

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

		June 30, 2014					December 31, 2013
	Contract Type	Purchased/ Payor		Sold/ Receiver			Purchased/ Payor		Sold/ Receiver
Derivatives designated as hedging instruments:
Cash flow hedges
Fixed price
- Natural gas (Bcf)	Futures and swaps	—		(38.8		)	—		(48.1		)
- Crude oil and NGLs (MMbbl)	Futures, forwards and swaps	0.1		(3.0		)	—		(4.0		)
Basis
- Natural gas (Bcf)	Futures and swaps	—		(38.8		)	—		(48.1		)
Interest-rate contracts (Millions of dollars)	Forward-starting swaps	$	900.0	$	—		$	400.0	$	—

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

Cash Flow Hedges -Accumulated other comprehensive income (loss) at June 30, 2014, includes losses of approximately $2.9 million, net of tax, related to ONEOK Partners’ commodity derivative instruments that will be recognized within the next 18 months as the forecasted transactions affect earnings.  If prices remain at current levels, we will recognize $3.3 million in net losses over the next 12 months and net gains of $0.4 million thereafter.  The amount deferred in accumulated other comprehensive income (loss) attributable to our settled interest-rate swaps is a loss of $39.9 million, net of tax, which will be recognized over the life of the long-term, fixed-rate debt. We expect that losses of $4.7 million will be reclassified into earnings during the next 12 months as the hedged items affect earnings. The remaining amounts in accumulated other comprehensive income (loss) are attributable primarily to ONEOK Partners’ forward-starting interest-rate swaps with future settlement dates, which will be amortized to interest expense over the life of long-term, fixed-rate debt upon issuance of ONEOK Partners’ debt.

The following table sets forth the effects of cash flow hedges recognized in other comprehensive income (loss) for our continuing operations for the periods indicated:

Derivatives in Cash Flow Hedging Relationships	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2014			2013		2014			2013
	(Thousands of dollars)
Commodity contracts	$	(6,114	)	$	33,145	$	(41,876	)	$	13,377
Interest-rate contracts	(26,401		)	22,217		(47,094		)	29,005
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	$	(32,515	)	$	55,362	$	(88,970	)	$	42,382

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

Derivatives in Cash Flow Hedging Relationships	Location of Gain (Loss) Reclassified from  Accumulated Other Comprehensive Income (Loss) into Net Income (Effective Portion)	Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
		(Thousands of dollars)
Commodity contracts	Commodity sales revenues	$	(5,187	)	$	1,245		$	(31,606	)	$	3,811
Interest-rate contracts	Interest expense	(3,526		)	(3,707		)	(14,847		)	(7,144		)
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income on derivatives (effective portion)		$	(8,713	)	$	(2,462	)	$	(46,453	)	$	(3,333	)

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Ineffectiveness related to our and ONEOK Partners’ cash flow hedges was not material for the three and six months ended June 30, 2014 and 2013.  In the event that it becomes probable that a forecasted transaction will not occur, ONEOK Partners will discontinue cash flow hedge treatment, which will affect earnings.

For the six months ended June 30, 2014, we reclassified losses of $4.6 million, net of taxes of $3.1 million, to interest expense from accumulated other comprehensive income (loss) due to the discontinuance of cash flow hedge treatment from the de-designation of interest-rate swaps related to the early retirement of long-term debt. See Note F for additional information. There were no gains or losses due to the discontinuance of cash flow hedge treatment during the three months ended June 30, 2014 and the three and six months ended June 30, 2013.

Credit Risk - In the first quarter 2014, outstanding commodity derivative positions with third parties entered into by our energy services business on ONEOK Partners’ behalf were transferred to ONEOK Partners. Beginning in the second quarter 2014, ONEOK Partners enters into all commodity derivative financial contracts directly with unaffiliated third parties.

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

Some of ONEOK Partners’ financial derivative instruments contain provisions that require it to maintain an investment-grade credit rating from S&P and/or Moody’s.  If ONEOK Partners’ credit ratings on 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 in a net liability position at June 30, 2014.

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

E. CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE

ONEOK Credit Agreement - The ONEOK Credit Agreement, which was amended and restated effective on January 31, 2014, and expires in January 2019, is a $300 million revolving credit facility and contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of indebtedness to Consolidated EBITDA (EBITDA, as defined in our ONEOK Credit Agreement) of no more than 4.0 to 1. Upon breach of certain covenants by us in the ONEOK Credit Agreement, amounts outstanding under the ONEOK Credit Agreement, if any, may become due and payable immediately. At June 30, 2014, ONEOK’s ratio of indebtedness to Consolidated EBITDA was 1.7 to 1, and ONEOK was in compliance with all covenants under the ONEOK Credit Agreement. As a result of a reduction in the borrowing capacity of the ONEOK Credit Agreement, we wrote off approximately $2.9 million in interest expense of previously deferred credit agreement issuance costs in the first quarter 2014.

The ONEOK Credit Agreement also includes a $50 million sublimit for the issuance of standby letters of credit and a $50 million sublimit for swingline loans. Under the terms of the ONEOK Credit Agreement, ONEOK may request an increase in the size of the facility to an aggregate of $500 million from $300 million by either commitments from new lenders or increased commitments from existing lenders. The ONEOK Credit Agreement contains provisions for an applicable margin rate and an annual facility fee, both of which adjust with changes in our credit rating. Based on our current credit rating, borrowings, if any, will accrue at LIBOR plus 125 basis points, and the annual facility fee is 25 basis points.

In February 2014, we repaid all amounts outstanding under our commercial paper program with a portion of the proceeds received from ONE Gas in connection with the separation and terminated the program. See Note F for additional information. At June 30, 2014, ONEOK had $2.1 million in letters of credit issued.

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ONEOK Partners Credit Agreement - The amount of short-term borrowings authorized by ONEOK Partners GP’s Board of Directors is $2.5 billion. At June 30, 2014, ONEOK Partners had no commercial paper outstanding, $14.0 million in letters of credit issued and no borrowings under the ONEOK Partners Credit Agreement.

The ONEOK Partners Credit Agreement, which was amended and restated effective on January 31, 2014, and expires in January 2019, is a $1.7 billion revolving credit facility and includes a $100 million sublimit for the issuance of standby letters of credit, a $150 million swingline sublimit and an option to request an increase in the size of the facility to an aggregate of $2.4 billion by either commitments from new lenders or increased commitments from existing lenders. The ONEOK Partners Credit Agreement is available for general partnership purposes. During the second quarter 2014, ONEOK Partners increased the size of its commercial paper program to $1.7 billion from $1.2 billion. Amounts outstanding under ONEOK Partners’ commercial paper program reduce the borrowing capacity under the ONEOK Partners Credit Agreement.

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

The ONEOK Partners Credit Agreement contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of indebtedness to adjusted EBITDA (EBITDA, as defined in the ONEOK Partners Credit Agreement, adjusted for all noncash charges and increased for projected EBITDA from certain lender-approved capital expansion projects) of no more than 5.0 to 1.  If ONEOK Partners consummates one or more acquisitions in which the aggregate purchase price is $25 million or more, the allowable ratio of indebtedness to adjusted EBITDA will increase to 5.5 to 1 for the quarter in which the acquisition was completed and the two following quarters.  As a result of a pipeline acquisition ONEOK Partners completed in the first quarter 2014, the allowable ratio of indebtedness to adjusted EBITDA increased to 5.5 to 1 through the third quarter 2014. Upon breach of certain covenants by ONEOK Partners 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, 2014, its ratio of indebtedness to adjusted EBITDA was 3.4 to 1, and ONEOK Partners 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.

F. LONG-TERM DEBT

In January 2014, ONE Gas, which at the time was our wholly owned subsidiary, completed a private placement of three series of Senior Notes totaling $1.2 billion. The following table details information about each of the three series of Senior Notes:

	(In millions)
2.07% notes due February 1, 2019	$	300
3.61% notes due February 1, 2024	300
4.658% notes due February 1, 2044	600
Total	$	1,200

Our obligations related to the ONE Gas Senior Notes terminated when we completed the separation of ONE Gas on January 31, 2014.

ONE Gas made a cash payment to us of approximately $1.13 billion from the proceeds of this offering. In February 2014, we retired approximately $152.5 million of the 4.25 percent senior notes due 2022 through a tender offer. The total amount paid was approximately $150 million. In February 2014, we called our $400 million, 5.2 percent senior notes due in 2015. The full repayment occurred in March 2014 and totaled $430.1 million, including accrued but unpaid interest to the redemption date. We recorded a loss on extinguishment of $24.8 million related to the debt retirements, which is included in other expense in our Consolidated Statements of Income.

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G. EQUITY

The following table sets forth the changes in equity attributable to us and our noncontrolling interests, including other comprehensive income, net of tax, for the periods indicated:

	Three Months Ended									Three Months Ended
	June 30, 2014									June 30, 2013
	ONEOK Shareholders’ Equity			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity			ONEOK Shareholders’ Equity			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity
	(Thousands of dollars)
Beginning balance	$	584,500		$	2,543,207		$	3,127,707		$	2,134,354		$	2,069,779		$	4,204,133
Net income	61,590			79,161			140,751			919			78,576			79,495
Other comprehensive income (loss)	(3,214		)	(16,199		)	(19,413		)	11,183			32,102			43,285
Common stock issued	6,325			—			6,325			4,919			—			4,919
Common stock dividends	(116,409		)	—			(116,409		)	(74,201		)	—			(74,201		)
Issuance of common units of ONEOK Partners	116,129			635,424			751,553			—			(264		)	(264		)
Distributions to noncontrolling interests	—			(104,687		)	(104,687		)	—			(91,186		)	(91,186		)
Other	7,504			—			7,504			8,175			—			8,175
Ending balance	$	656,425		$	3,136,906		$	3,793,331		$	2,085,349		$	2,089,007		$	4,174,356

	Six Months Ended									Six Months Ended
	June 30, 2014									June 30, 2013
	ONEOK Shareholders’ Equity			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity			ONEOK Shareholders’ Equity			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity
	(Thousands of dollars)
Beginning balance	$	2,337,851		$	2,507,329		$	4,845,180		$	2,129,609		$	2,102,841		$	4,232,450
Net income	155,105			192,157			347,262			113,440			131,760			245,200
Other comprehensive income (loss)	5,471			(33,508		)	(28,037		)	4,828			24,576			29,404
Common stock issued	13,904			—			13,904			7,750			—			7,750
Common stock dividends	(199,684		)	—			(199,684		)	(147,982		)	—			(147,982		)
Issuance of common units of ONEOK Partners	127,125			677,270			804,395			2,956			11,352			14,308
Distribution of ONE Gas to shareholders	(1,747,424		)	—			(1,747,424		)	—			—			—
Distributions to noncontrolling interests	—			(206,342		)	(206,342		)	—			(181,522		)	(181,522		)
Other	(35,923		)	—			(35,923		)	(25,252		)	—			(25,252		)
Ending balance	$	656,425		$	3,136,906		$	3,793,331		$	2,085,349		$	2,089,007		$	4,174,356

Dividends - Dividends paid on our common stock to shareholders of record at the close of business on February 10, 2014 and April 30, 2014, were $0.40 per share and $0.56 per share, respectively.  A dividend of $0.575 per share was declared for shareholders of record at the close of business on August 4, 2014, payable August 14, 2014.

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

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H. ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

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

	Unrealized Gains (Losses) on Energy Marketing and Risk-Management Assets/Liabilities (a)			Unrealized Holding Gains (Losses) on Investment Securities (a)			Pension and Postretirement Benefit Plan Obligations (a)			Accumulated Other Comprehensive Income (Loss) (a)
	(Thousands of dollars)
January 1, 2014	$	(43,168	)	$	857		$	(79,676	)	$	(121,987	)
Other comprehensive income (loss) before reclassifications	(22,691		)	(113		)	(80		)	(22,884		)
Amounts reclassified from accumulated other comprehensive income (loss)	22,391			—			5,964			28,355
Other comprehensive income (loss) attributable to ONEOK	(300		)	(113		)	5,884			5,471
Transfer to ONE Gas	—			—			3,389			3,389
June 30, 2014	$	(43,468	)	$	744		$	(70,403	)	$	(113,127	)

(a) All amounts are presented net of tax.

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

Details about Accumulated Other Comprehensive Income (Loss) Components	Three Months Ended						Six Months Ended						Affected Line Item in the Consolidated Statements of Income
	June 30,						June 30,
	2014			2013			2014			2013
	(Thousands of dollars)
Unrealized (gains) losses on energy marketing and risk-management assets/liabilities
Commodity contracts	$	5,187		$	(1,245	)	$	31,606		$	(3,811	)	Commodity sales revenues
Interest-rate contracts	3,526			3,707			14,847			7,144			Interest expense
	8,713			2,462			46,453			3,333			Income before income taxes
	(1,202		)	(661		)	(9,098		)	(1,055		)	Income tax expense
	7,511			1,801			37,355			2,278			Income from continuing operations
	—			(5,191		)	7,683			1,627			Income from discontinued operations
	7,511			(3,390		)	45,038			3,905			Net income
Noncontrolling interest	5,538			754			22,647			606			Less: Net income attributable to noncontrolling interest
	$	1,973		$	(4,144	)	$	22,391		$	3,299		Net income attributable to ONEOK
Pension and postretirement benefit plan obligations (a)
Amortization of net loss	$	3,964		$	5,078		$	7,927		$	10,156
Amortization of unrecognized prior service cost	(367		)	(113		)	(734		)	(226		)
Amortization of unrecognized net asset at adoption	—			7			—			14
	3,597			4,972			7,193			9,944			Income before income taxes
	(1,439		)	(1,923		)	(2,877		)	(3,846		)	Income tax expense
	2,158			3,049			4,316			6,098			Income from continuing operations
	—			8,793			1,648			17,002			Income from discontinued operations
	$	2,158		$	11,842		$	5,964		$	23,100		Net income attributable to ONEOK
Total reclassifications for the period attributable to ONEOK	$	4,131		$	7,698		$	28,355		$	26,399		Net income attributable to ONEOK

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

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I. 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, 2014
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	69,599	209,403	$	0.33
Diluted EPS from continuing operations
Effect of dilutive securities	—		1,113
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	69,599	210,516	$	0.33

	Three Months Ended June 30, 2013
	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	$	75,201	206,143	$	0.36
Diluted EPS from continuing operations
Effect of dilutive securities	—		2,731
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	75,201	208,874	$	0.36

	Six Months Ended June 30, 2014
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	161,340	209,267	$	0.77
Diluted EPS from continuing operations
Effect of dilutive securities	—		1,070
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	161,340	210,337	$	0.77

	Six Months Ended June 30, 2013
	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	$	132,520	205,811	$	0.64
Diluted EPS from continuing operations
Effect of dilutive securities	—		3,355
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	132,520	209,166	$	0.63

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J. 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						Pension Benefits
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2014			2013			2014			2013
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	1,823		$	1,532		$	3,645		$	3,064
Interest cost	4,628			3,906			9,256			7,812
Expected return on assets	(4,934		)	(4,969		)	(9,869		)	(9,938		)
Amortization of unrecognized prior service cost	48			58			96			116
Amortization of net loss	3,756			4,755			7,511			9,510
Other	120			—			120			—
Net periodic benefit cost	$	5,441		$	5,282		$	10,759		$	10,564

	Postretirement Benefits						Postretirement Benefits
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2014			2013			2014			2013
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	179		$	118		$	358		$	236
Interest cost	611			298			1,222			596
Expected return on assets	(555		)	(314		)	(1,110		)	(628		)
Amortization of unrecognized net asset at adoption	—			7			—			14
Amortization of unrecognized prior service cost	(415		)	(171		)	(830		)	(342		)
Amortization of net loss	208			323			416			646
Other	(2		)	—			(2		)	—
Net periodic benefit cost	$	26		$	261		$	54		$	522

K. UNCONSOLIDATED AFFILIATES

Equity Earnings from Investments -The following table sets forth ONEOK Partners’ equity earnings (losses) from investments for the periods indicated:

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2014			2013		2014			2013
	(Thousands of dollars)
Northern Border Pipeline	$	15,877		$	15,279	$	39,286		$	31,669
Overland Pass Pipeline Company	4,121			5,528		8,852			8,427
Fort Union Gas Gathering	4,280			3,080		8,409			6,949
Bighorn Gas Gathering	(873		)	626		(1,273		)	1,338
Other	2,030			1,908		3,820			3,893
Equity earnings from investments	$	25,435		$	26,421	$	59,094		$	52,276

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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,
	2014		2013		2014		2013
	(Thousands of dollars)
Income Statement
Operating revenues	$	121,509	$	132,152	$	276,788	$	259,953
Operating expenses	$	51,870	$	61,124	$	123,549	$	125,395
Net income	$	60,878	$	65,746	$	139,551	$	123,950
Distributions paid to ONEOK Partners	$	42,579	$	39,311	$	77,649	$	69,504

ONEOK Partners incurred expenses in transactions with unconsolidated affiliates of $14.3 million and $12.6 million for the three months ended June 30, 2014 and 2013, respectively, and $28.4 million and $20.4 million for the six months ended June 30, 2014 and 2013, respectively, primarily related to Overland Pass Pipeline Company, which are included in cost of sales and fuel in our Consolidated Statements of Income. Accounts payable to ONEOK Partners’ equity method investees at June 30, 2014, and December 31, 2013, were not material.

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

Due to recent reductions in producer activity and declines in natural gas volumes gathered in the dry natural gas area of the Powder River Basin on the Bighorn Gas Gathering system in which ONEOK Partners owns a 49 percent interest, ONEOK Partners tested its investment for impairment at December 31, 2013. The estimated fair value exceeded the carrying value; however, a decline of 10 percent or more in the fair value of ONEOK Partners’ investment in Bighorn Gas Gathering would result in a noncash impairment charge. ONEOK Partners is not able to reasonably estimate a range of potential future impairment charges, as many of the assumptions that would be used in its estimate of fair value are dependent upon events beyond its control. The carrying amount of ONEOK Partners’ investment at June 30, 2014 was $85.7 million, which includes $53.4 million in equity method goodwill.

L. ONEOK PARTNERS

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

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 $300 million. The program allows ONEOK Partners to offer and sell its common units at prices ONEOK Partners 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.

During the six months ended June 30, 2014, ONEOK Partners sold approximately 3.0 million common units through this program. The net proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, were approximately $164.1 million, which were used for general partnership purposes. During the three months ended March 31, 2013, ONEOK Partners sold 300,000 common units through this program that resulted in net proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, of approximately $16.3 million and used the proceeds for general partnership purposes. There were no common units sold through this program in the second quarter 2013.

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As a result of these transactions, our aggregate ownership interest in ONEOK Partners decreased to 38.5 percent at June 30, 2014, from 41.2 percent at December 31, 2013.

We account for the difference between the carrying amount of our investment in ONEOK Partners and the underlying book value arising from issuance of common units by ONEOK Partners as an equity transaction.  If ONEOK Partners issues common units at a price different than our carrying value per unit, we account for the premium or deficiency as an adjustment to paid-in capital. As a result of ONEOK Partners’ issuance of common units, we recognized an increase to paid-in capital of approximately $127.1 million, net of taxes, for the six months ended June 30, 2014.

Ownership Interestin ONEOK Partners - Our ownership interest in ONEOK Partners is shown in the table below at June 30, 2014:

General partner interest	2.0	%
Limited partner interest (a)	36.5	%
Total ownership interest	38.5	%

(a) - Represents 19.8 million common units and approximately 73.0 million Class B units, which are convertible, at our option, into common units.

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 2014, a cash distribution of $0.76 per unit ($3.04 per unit on an annualized basis), an increase of 1.5 cents from the previous quarter, was declared for the second quarter 2014 and will be paid on August 14, 2014, to unitholders of record at the close of business on August 4, 2014.

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2014		2013		2014		2013
	(Thousands, except per unit amounts)
Distribution per unit	$	0.745	$	0.715	$	1.475	$	1.425
General partner distributions	$	5,011	$	4,469	$	9,860	$	8,887
Incentive distributions	71,911		61,576		140,166		122,013
Distributions to general partner	76,922		66,045		150,026		130,900
Limited partner distributions to ONEOK	69,125		66,344		136,862		132,224
Limited partner distributions to noncontrolling interest	104,506		91,039		206,161		181,228
Total distributions paid	$	250,553	$	223,428	$	493,049	$	444,352

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2014		2013		2014		2013
	(Thousands, except per unit amounts)
Distribution per unit	$	0.760	$	0.720	$	1.505	$	1.435
General partner distributions	$	5,501	$	4,512	$	10,512	$	8,981
Incentive distributions	80,381		62,633		152,292		124,209
Distributions to general partner	85,882		67,145		162,804		133,190
Limited partner distributions to ONEOK	70,519		66,807		139,646		133,151
Limited partner distributions to noncontrolling interest	118,644		91,676		223,150		182,715
Total distributions declared	$	275,045	$	225,628	$	525,600	$	449,056

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

Affiliate Transactions - We have certain transactions with ONEOK Partners and its subsidiaries.

Prior to the wind down of our energy services business, ONEOK Partners sold natural gas from its natural gas gathering and processing operations to our energy services business.  In addition, a portion of ONEOK Partners’ revenues from its natural gas pipelines business were from our former energy services and natural gas distribution businesses, which contracted with ONEOK Partners for natural gas transportation and storage services. ONEOK Partners also purchased natural gas from our former energy services business for its natural gas liquids and its natural gas gathering and processing operations.

As a result of the wind down discussed in Note B, our energy services business no longer executes affiliate transactions with ONEOK Partners. Beginning in the second quarter, ONEOK Partners enters into all commodity derivative financial contracts with unaffiliated third parties. ONEOK Partners continues to provide natural gas transportation and storage services to ONE Gas after the separation.

We provide a variety of services to our affiliates, including cash management and financial services, legal and administrative services by our employees and management, insurance and office space leased in our headquarters building and other field locations.  Where costs are incurred specifically on behalf of an affiliate, the costs are billed directly to the affiliate by us.  In other situations, the costs may be allocated to the affiliates through a variety of methods, depending upon the nature of the expenses and the activities of the affiliates.  Beginning in the second quarter 2014, we allocate substantially all of our general overhead costs to ONEOK Partners as a result of the separation of our natural gas distribution business and the wind down of our energy services business in the first quarter 2014.  For the first quarter 2014 and the three and six months ended June 30, 2013, it is not practicable to determine what these general overhead costs would have been on a stand-alone basis.

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2014		2013		2014		2013
	(Thousands of dollars)
Revenues	$	—	$	91,340	$	53,526	$	173,974
Expenses
Cost of sales and fuel	$	—	$	8,742	$	10,835	$	18,293
Administrative and general expenses	78,705		61,861		155,951		134,357
Total expenses	$	78,705	$	70,603	$	166,786	$	152,650

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Prior to the ONE Gas separation, natural gas sales and transportation and storage services provided to our former natural gas distribution business by ONEOK Partners were $14.3 million for the three months ended June 30, 2013, and $7.5 million and $28.1 million for the six months ended June 30,2014 and 2013, respectively. Prior to February 1, 2014, these revenues and related costs were eliminated in consolidation. Beginning February 1, 2014, these revenues represent third-party transactions with ONE Gas and are not eliminated in consolidation, as such sales and services have continued subsequent to the separation and are expected to continue in future periods. Prior to the completion of the energy services wind down, natural gas and natural gas liquids sales and transportation and storage services provided to our energy services business by ONEOK Partners were $77.0 million for the three months ended June 30, 2013, and $46.0 million and $145.9 million for the six months ended June 30,2014 and 2013, respectively. While these transactions were eliminated in consolidation in previous periods, they are now reflected as affiliate transactions and not eliminated in consolidation as these transactions have continued with third parties.

M. COMMITMENTS AND CONTINGENCIES

Environmental Matters - ONEOK Partners is subject to multiple historical preservation, wildlife preservation and environmental laws and/or regulations that affect many aspects of 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, wetland 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 its results of operations. For example, if a leak or spill of hazardous substances or petroleum products occurs from pipelines or facilities that ONEOK Partners owns, operates or otherwise uses, ONEOK Partners could be held jointly and severally liable for all resulting liabilities, including response, investigation and cleanup costs, which could affect materially its 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 its facilities.  ONEOK Partners cannot assure that existing environmental statutes and regulations will not be revised or that new regulations will not be adopted or become applicable to it.  

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

The legal responsibility for the environmental conditions at former manufactured natural gas sites in Kansas was transferred from us to ONE Gas on January 31, 2014 upon the completion of the separation. Our expenditures for environmental assessment, mitigation, remediation and compliance prior to the separation were not significant in relation to our financial position, results of operations or cash flows, and our expenditures related to environmental matters have had no material effects on earnings or cash flows during the three and six months ended June 30, 2014 and 2013.

The EPA’s “Tailoring Rule” regulates greenhouse gas emissions at new or modified facilities that meet certain criteria. Affected facilities are required to review best available control technology (BACT), conduct air-quality and conduct impact analysis and public reviews with respect to such emissions.  At current emissions threshold levels, this rule has had a minimal impact on ONEOK Partners’ existing facilities.  The EPA has stated it will consider lowering the threshold levels over the next five years, which could increase the impact on its existing facilities; however, potential costs, fees or expenses associated with the potential adjustments are unknown. In addition, on June 23, 2014, the Supreme Court of the United States, in a case styled, Utility Air Regulatory Group v. EPA, 530 U.S. (2014), held that an industrial facility’s potential to emit greenhouse gas (GHG) emissions alone cannot subject a facility to the permitting requirements for major stationary source provisions of the Clean Air Act. The decision invalidated the EPA’s current Triggering and Tailoring Rule for GHG Prevention of Significant Deterioration

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(PSD) and Title V requirements. However, the Court also ruled that to the extent a source pursues a capital project (new construction or expansion of existing facility), which otherwise subjects the source to major source PSD permitting for conventional criteria pollutants, the permitting authorities may impose BACT analysis and emission limits for GHGs from those sources. We are in the process of evaluating the effects the decision may have on ONEOK Partners’ existing operations, and the opportunities it creates for design decisions for new project applications.

The EPA’s rule on air-quality standards, National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (RICE NESHAP), initially included a compliance date in 2013, and has since become effective. While the rule could require capital expenditures for the purchase and installation of new emissions-control equipment, ONEOK Partners does not expect these expenditures will have a material impact on its results of operations, financial position or cash flows.

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

The rule was most recently amended in September 2013, and a further proposed rulemaking was published in July 2014. The EPA has indicated that further amendments may be issued in 2014. Based on the amendments, ONEOK Partners’ understanding of pending stakeholder responses to the NSPS rule and the proposed rulemaking, ONEOK Partners does not anticipate a material impact to its anticipated capital, operations and maintenance costs resulting from compliance with the regulation. However, the EPA may issue additional responses, amendments and/or policy guidance on the final rule, which could alter its present expectations. Generally, the NSPS rule will require expenditures for updated emissions controls, monitoring and record-keeping at affected facilities in the crude oil and natural gas industry. ONEOK Partners does not expect these expenditures will have a material impact on its results of operations, financial position or cash flows.

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

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

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

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

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

The potential capital and operating expenditures related to this legislation, the associated regulations or other new pipeline safety regulations are unknown.

Financial Markets Legislation - The Dodd-Frank Act represents a far-reaching overhaul of the framework for regulation of United States financial markets. The CFTC has issued final regulations for most of the provisions of the Dodd-Frank Act, and we have implemented measures to comply with the regulations that are applicable to our businesses. ONEOK Partners continues to participate in financial markets for hedging certain risks inherent in its business, including commodity-price and interest-rate risks. Although the impact to date has not been material, we continue to monitor proposed regulations and the impact these regulations may have on our business and risk-management strategies in the future.

Legal Proceedings - Gas Index Pricing Litigation - As previously reported, ONEOK and its subsidiary, ONEOK Energy Services Company L.P. (OESC), along with several other energy companies, are defending multiple lawsuits arising from alleged market manipulation or false reporting of natural gas prices to natural gas-index publications. On April 10, 2013, the

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United States Court of Appeals for the Ninth Circuit reversed the summary judgments that had been granted in favor of ONEOK, OESC and other unaffiliated defendants in the following cases: Reorganized FLI, Learjet, Arandell, Heartland and NewPage. The Ninth Circuit also reversed the summary judgment that had been granted in favor of OESC on all state law claims asserted in the Sinclair case. ONEOK, OESC and the other unaffiliated defendants filed a Petition for Writ of Certiorari with the United States Supreme Court on August 26, 2013, seeking review of the Ninth Circuit decision. On July 1, 2014, the United States Supreme Court granted the the Petition for Writ of Certiorari. Oral argument has not yet been scheduled.

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

Other Legal Proceedings - We are a 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 on 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.

ONE Gas Separation - In connection with the separation of ONE Gas, we entered into a Separation and Distribution Agreement with ONE Gas, which sets forth the agreements between us and ONE Gas regarding the principal transactions necessary to effect the separation, including cross-indemnities between us and ONE Gas. In general, we agreed to indemnify ONE Gas for any liabilities relating to our business following the separation, including ONEOK Partners and our energy services business, and ONE Gas agreed to indemnify us for liabilities relating to the natural gas distribution business. If a liability does not relate to either our remaining business or to ONE Gas, then we and ONE Gas will each be responsible for a portion of such liability.

In addition, we entered into a Transition Services Agreement with ONE Gas. Under this agreement, ONEOK and ONE Gas agreed to provide each other with various services, including services relating to treasury and risk management, accounting, human resources and payroll management, tax compliance, telecommunications services and information technology services.

N. SEGMENTS

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

• the Natural Gas Gathering and Processing segment gathers 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.

Change in Reportable Segments - On January 31, 2014, we completed the separation of our former natural gas distribution business into a stand-alone publicly traded company called ONE Gas. ONE Gas consists of our former Natural Gas Distribution segment. On March 31, 2014, we completed the accelerated wind down of our Energy Services segment. These former segments are included in discontinued operations for all periods presented. See Notes A and B for additional information.

Following the separation of our natural gas distribution business into ONE Gas and wind down of our energy services business, our chief operating decision maker reviews the financial performance of each of the three businesses of ONEOK Partners on a regular basis to assess the performance of, and allocate resources to, ONEOK Partners. As a result, our reportable segments have changed to reflect the three business segments of ONEOK Partners. Prior periods presented have been recast to conform to the current presentation.

Accounting Policies - We evaluate performance based principally on each segment’s operating income and equity earnings. The accounting policies of the segments are described in Note A of the Notes to Consolidated Financial Statements in our Annual Report.  Affiliate and intersegment sales are recorded on the same basis as sales to unaffiliated customers.  Net margin is comprised of total revenues less cost of sales and fuel.  Cost of sales and fuel includes commodity purchases, fuel, storage and transportation costs. Revenues from sales and services provided by ONEOK Partners to our former Natural Gas Distribution segment, which were previously eliminated in consolidation, are now reported as third-party revenues.

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

For the three and six months ended June 30, 2014 and 2013, ONEOK Partners had no single customer from which it received 10 percent or more of consolidated revenues.

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

Three Months Ended	Natural Gas Gathering and Processing			Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Other and Eliminations			Total
June 30, 2014
	(Thousands of dollars)
Sales to unaffiliated customers	$	374,112		$	2,612,336	$	79,287	$	1,147		$	3,066,882
Intersegment revenues	349,253			52,974		2,698		(404,925		)	—
Total revenues	$	723,365		$	2,665,310	$	81,985	$	(403,778	)	$	3,066,882
Net margin	$	154,970		$	266,145	$	75,471	$	(1,106	)	$	495,480
Operating costs	59,386			76,081		27,287		9,268			172,022
Depreciation and amortization	29,443			31,109		10,895		680			72,127
Gain (loss) on sale of assets	(28		)	11		—		1			(16		)
Operating income	$	66,113		$	158,966	$	37,289	$	(11,053	)	$	251,315
Equity earnings from investments	$	5,099		$	4,459	$	15,877	$	—		$	25,435
Capital expenditures	$	168,208		$	210,676	$	8,710	$	5,082		$	392,676

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $153.3 million, of which $135.3 million related to sales within the segment, net margin of $84.4 million and operating income of $34.5 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $68.3 million, net margin of $59.5 million and operating income of $26.1 million.

Three Months Ended	Natural Gas Gathering and Processing		Natural Gas Liquids (a)			Natural Gas Pipelines (b)		Other and Eliminations (c)			Total
June 30, 2013
	(Thousands of dollars)
Sales to unaffiliated customers	$	166,709	$	2,461,119		$	49,011	$	805		$	2,677,644
Sales to affiliated customers	66,578		—			24,762		—			91,340
Intersegment revenues	248,972		29,996			1,269		(280,237		)	—
Total revenues	$	482,259	$	2,491,115		$	75,042	$	(279,432	)	$	2,768,984
Net margin	$	125,269	$	219,225		$	67,695	$	569		$	412,758
Operating costs	44,975		54,264			24,985		1,541			125,765
Depreciation and amortization	25,106		22,302			10,818		657			58,883
Gain (loss) on sale of assets	285		(6		)	—		—			279
Operating income	$	55,473	$	142,653		$	31,892	$	(1,629	)	$	228,389
Equity earnings from investments	$	5,229	$	5,912		$	15,280	$	—		$	26,421
Capital expenditures	$	206,019	$	269,339		$	6,007	$	77,903		$	559,268

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $121.6 million, of which $106.5 million related to sales within the segment, net margin of $76.8 million and operating income of $44.3 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $56.1 million, net margin of $52.0 million and operating income of $20.6 million.

(c) - The Other segment includes capital expenditures of discontinued operations of $68.8 million.

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Six Months Ended	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)			Other and Eliminations (c)			Total
June 30, 2014
	(Thousands of dollars)
Sales to unaffiliated customers	$	721,128		$	5,282,991		$	170,393		$	2,140		$	6,176,652
Sales to affiliated customers	41,214			—			12,312			—			53,526
Intersegment revenues	723,148			94,131			4,073			(821,352		)	—
Total revenues	$	1,485,490		$	5,377,122		$	186,778		$	(819,212	)	$	6,230,178
Net margin	$	308,524		$	535,123		$	168,960		$	(6,500	)	$	1,006,107
Operating costs	124,210			141,183			54,749			991			321,133
Depreciation and amortization	58,285			58,187			21,710			1,359			139,541
Gain (loss) on sale of assets	(47		)	(37		)	(83		)	166			(1		)
Operating income	$	125,982		$	335,716		$	92,418		$	(8,684	)	$	545,432
Equity earnings from investments	$	10,585		$	9,223		$	39,286		$	—		$	59,094
Investments in unconsolidated affiliates	$	329,726		$	485,960		$	396,722		$	—		$	1,212,408
Total assets	$	4,276,593		$	7,363,417		$	1,852,901		$	891,627		$	14,384,538
Noncontrolling interests in consolidated subsidiaries	$	4,493		$	—		$	—		$	3,132,413		$	3,136,906
Capital expenditures	$	291,099		$	483,739		$	15,337		$	32,026		$	822,201

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $289.1 million, of which $246.9 million related to sales within the segment, net margin of $169.1 million and operating income of $79.6 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $149.6 million, net margin of $128.1 million and operating income of $61.2 million.

(c) - The Other segment includes assets and capital expenditures of discontinued operations of $87.5 million and $23.9 million, respectively.

Six Months Ended	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Other and Eliminations (c)			Total
June 30, 2013
	(Thousands of dollars)
Sales to unaffiliated customers	$	303,954	$	4,699,362	$	108,336	$	1,313		$	5,112,965
Sales to affiliated customers	122,236		—		51,738		—			173,974
Intersegment revenues	493,583		56,421		997		(551,001		)	—
Total revenues	$	919,773	$	4,755,783	$	161,071	$	(549,688	)	$	5,286,939
Net margin	$	234,554	$	405,845	$	141,767	$	1,699		$	783,865
Operating costs	96,663		114,066		52,151		4,020			266,900
Depreciation and amortization	49,010		42,040		21,854		1,262			114,166
Gain (loss) on sale of assets	313		3		4		—			320
Operating income	$	89,194	$	249,742	$	67,766	$	(3,583	)	$	403,119
Equity earnings from investments	$	11,560	$	9,047	$	31,669	$	—		$	52,276
Investments in unconsolidated affiliates	$	332,458	$	494,964	$	381,365	$	—		$	1,208,787
Total assets	$	3,346,874	$	6,008,574	$	1,792,343	$	4,694,483		$	15,842,274
Noncontrolling interests in consolidated subsidiaries	$	4,631	$	—	$	—	$	2,084,376		$	2,089,007
Capital expenditures	$	369,967	$	543,504	$	11,349	$	135,513		$	1,060,333

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $229.8 million, of which $191.1 million related to sales within the segment, net margin of $138.3 million and operating income of $75.6 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $124.5 million, net margin of $109.7 million and operating income of $44.4 million.

(c) - The Other segment includes assets and capital expenditures of discontinued operations of $4.0 billion and $122.6 million, respectively.

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

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

RECENT DEVELOPMENTS

ONEOK and its subsidiaries continue to own all of the general partner interest and a portion of the limited partner interests, which, together, represent a 38.5 percent ownership interest at June 30, 2014, in ONEOK Partners (NYSE: OKS), one of the largest publicly traded master limited partnerships.

Separation of Natural Gas Distribution Business - In January 2014, ourboard of directors unanimously approved the separation of our natural gas distribution business into a stand-alone publicly traded company called ONE Gas, which was completed on January 31, 2014. ONE Gas consists of ONEOK’s former Natural Gas Distribution segment that includes Kansas Gas Service, Oklahoma Natural Gas and Texas Gas Service. ONEOK shareholders of record at the close of business on January 21, 2014, retained their current shares of ONEOK stock and received one share of ONE Gas stock for every four shares of ONEOK stock owned in a transaction that was tax-free to ONEOK and its shareholders. Our natural gas distribution business, which generated operating income of $47.5 million in January 2014, was classified as discontinued operations on January 31, 2014. We also incurred $21.5 million of after-tax costs associated with the separation for the six months ended June 30, 2014, that have been recorded in discontinued operations. See additional discussion in Note B.

In connection with the separation, we received a cash payment of approximately $1.13 billion from ONE Gas and used the proceeds to repay all of our outstanding commercial paper and to retire approximately $552.5 million of long-term debt prior to maturity. As of result of the early retirement of long-term debt, we incurred a loss on extinguishment of approximately $24.8 million, which is included in other expense, and reclassified losses to interest expense of approximately $7.7 million due to the discontinuance of cash flow hedge accounting for the related interest-rate swaps. We also amended and restated our ONEOK Credit Agreement effective January 31, 2014, to reduce the size of the facility to $300 million from $1.2 billion and recorded a charge to interest expense of approximately $2.9 million related to amortization of previous credit agreement issuance costs.

Wind Down of Energy Services Business - We completed the accelerated wind down of our energy services business which ceased operations on March 31, 2014, and was classified as discontinued operations. The energy services business generated net losses of approximately $0.8 million and $8.8 million for the three and six months ended June 30, 2014, respectively. See additional discussion in Note B.

Income Taxes - As a result of the separation of our former natural gas distribution business into ONE Gas and the wind down of the energy services business, we reduced deferred tax liabilities and deferred income tax expense by $34.6 million in the first quarter 2014 due to a reduction in our estimate of the effective state income tax rate to reflect a change in the mix of taxable income in the states in which we now operate. We also recorded a valuation allowance of $8.2 million in the first quarter 2014 for state tax credits, as it is more likely than not that we will be unable to use these credits as a result of the separation of our former natural gas distribution business and the wind down of our energy services business. Together, these adjustments resulted in a net $26.4 million reduction in deferred tax liabilities and deferred income tax expense.

Market Conditions - Domestic supplies of natural gas, natural gas liquids and crude oil continue to increase from drilling activities in crude oil and NGL-rich resource areas. North American natural gas production continues to increase at a faster rate than demand, primarily as a result of increased production from shale and other nonconventional resource areas. ONEOK Partners expects continued demand for midstream infrastructure development to be driven by producers who need to connect emerging natural gas and natural gas liquids production with end-use markets where current infrastructure is insufficient or nonexistent.

When economic conditions warrant, certain natural gas processors elect not to recover the ethane component in the natural gas stream, also known as ethane rejection, and instead leave the ethane component in the natural gas stream sold at the tailgate of natural gas processing plants.  Natural gas prices were favorable to ethane prices on a Btu basis, which resulted in ethane rejection at most of ONEOK Partners’ natural gas processing plants and some of its customers’ natural gas processing plants connected to its natural gas liquids gathering system in the Mid-Continent and Rocky Mountain regions during 2013 and the first six months of 2014, which reduced natural gas liquids volumes gathered and fractionated in its Natural Gas Liquids segment and reduced its results of operations.

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ONEOK Partners expects ethane rejection will persist at least through much of 2016, after which new world-scale ethylene production capacity is forecasted to begin coming on line, although market conditions may result in periods where it is economical to recover the ethane component in the natural gas stream. Ethane rejection is expected to have a significant impact on ONEOK Partners’ financial results over this period. However, new NGL supply commitments are expected to increase volumes in 2014 through 2016 to mitigate partially the impact of ethane rejection on ONEOK Partners’ Natural Gas Liquids segment. In addition, ONEOK Partners’ Natural Gas Liquids segment’s integrated assets enable it to mitigate further the impact of ethane rejection through minimum volume commitments 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 ONEOK Partners’ optimization activities. Beginning in the fourth quarter 2013, ONEOK Partners experienced high propane demand for crop drying and increased heating demand due to much colder than normal weather that continued into the first quarter 2014. In response to this increased demand, propane prices increased significantly at the Mid-Continent market center at Conway, Kansas, compared with the Gulf Coast market center at Mont Belvieu, Texas, for the three months ended March 31, 2014, compared with the same period in 2013. The price of propane in the Mid-Continent market and the wider location price differentials between the Mid-Continent and Gulf Coast market centers peaked in late January 2014 and returned to historical levels by the end of February 2014 as supply and demand normalized. See additional discussion in the “Financial Results and Operating Information” section.

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

New natural gas liquids pipeline projects constructed by third parties are expected to bring incremental NGL supply from the Rocky Mountain, Marcellus and Utica regions to the Mont Belvieu, Texas, market center that may affect NGL prices, as well as compete with or displace NGL supply volumes from the Mid-Continent and Rocky Mountain regions where ONEOK Partners’ assets are located. ONEOK Partners’ Natural Gas Liquids segment’s capital projects are backed by fee-based supply commitments that it expects will fill much of its optimization capacity used historically to capture NGL location price differentials between the Mid-Continent and Gulf Coast market centers.

ONEOK Partners’ Growth Projects - Crude oil and natural gas producers continue to drill aggressively for crude oil and NGL-rich natural gas in many regions where ONEOK Partners has operations.  ONEOK Partners expects continued development of the crude oil and NGL-rich natural gas reserves in the Bakken Shale and Three Forks formations in the Williston Basin, the Niobrara Shale and other formations in the Powder River Basin and in the Cana-Woodford Shale, Woodford Shale, Granite Wash, Mississippian Lime and SCOOP areas in the Mid-Continent region.  In response to this increased production of crude oil, natural gas and NGLs, and higher demand for NGL products from the petrochemical industry, ONEOK Partners is investing approximately $7.0 billion to $7.5 billion in new capital projects and acquisitions from 2010 through 2016 to meet the needs of natural gas producers and processors in these regions, as well as enhance its natural gas liquids fractionation, distribution and storage infrastructure in the Gulf Coast region.  The execution of these capital investments aligns with ONEOK Partners’ strategy to grow fee-based earnings. Acreage dedications and supply commitments from producers and natural gas processors in regions associated with ONEOK Partners’ growth projects are expected to provide incremental cash flows and long-term fee-based earnings.

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

Dividends/Distributions - We declared a quarterly dividend of $0.575 per share ($2.30 per share on an annualized basis) in July 2014.  ONEOK Partners declared a cash distribution of $0.76 per unit ($3.04 per unit on an annualized basis) in July 2014 for the second quarter 2014, an increase of 1.5 cents from the previous quarter. The quarterly dividend and distribution will be paid August 14, 2014, to shareholders and unitholders of record at the close of business on August 4, 2014.

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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,						2014 vs. 2013					2014 vs. 2013
Financial Results	2014			2013			2014			2013			Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
Revenues
Commodity sales	$	2,715.1		$	2,447.4		$	5,521.8		$	4,646.2		$	267.7		11	%	$	875.6		19	%
Services	351.8			321.6			708.3			640.7			30.2			9	%	67.6			11	%
Total revenues	3,066.9			2,769.0			6,230.1			$	5,286.9		297.9			11	%	943.2			18	%
Cost of sales and fuel	2,571.4			2,356.2			5,224.1			4,503.1			215.2			9	%	721.0			16	%
Net margin	495.5			412.8			1,006.0			783.8			82.7			20	%	222.2			28	%
Operating costs	172.1			125.8			321.1			266.9			46.3			37	%	54.2			20	%
Depreciation and amortization	72.1			58.9			139.5			114.2			13.2			22	%	25.3			22	%
Gain (loss) on sale of assets	—			0.3			—			0.3			(0.3		)	(100	)%	(0.3		)	(100	)%
Operating income	$	251.3		$	228.4		$	545.4		$	403.0		$	22.9		10	%	$	142.4		35	%
Equity earnings from investments	$	25.4		$	26.4		$	59.1		$	52.3		$	(1.0	)	(4	)%	$	6.8		13	%
Interest expense	$	(88.8	)	$	(66.1	)	$	(183.7	)	$	(130.6	)	$	22.7		34	%	$	53.1		41	%
Income from continuing operations	$	148.8		$	153.8		$	353.5		$	264.3		$	(5.0	)	(3	)%	$	89.2		34	%
Net income attributable to noncontrolling interests	$	79.2		$	78.6		$	192.2		$	131.8		$	0.6		1	%	$	60.4		46	%
Net income attributable to ONEOK	$	61.6		$	0.9		$	155.1		$	113.4		$	60.7		*		$	41.7		37	%
Capital expenditures (a)	$	392.7		$	559.3		$	822.2		$	1,060.3		$	(166.6	)	(30	)%	$	(238.1	)	(22	)%

* Percentage change is greater than 100 percent.

(a) - Includes capital expenditures of discontinued operations of $23.9 million for the six months ended June, 30, 2014, $68.8 million for the three months ended June 30, 2013, and $122.6 million for the six months ended June 30, 2013.

Commodity sales revenues increased for the three and six months ended June 30, 2014, compared with the same periods in 2013, due to higher natural gas and NGL volumes from ONEOK Partners’ recently completed capital projects, wider NGL product price differentials and higher realized prices in ONEOK Partners’ Natural Gas Gathering and Processing and Natural Gas Liquids segments. In addition, the six months ended June 30, 2014, benefited from wider location price differentials experienced in the first quarter 2014 related primarily to propane due to lower propane inventory levels from crop drying and increased heating demand due to colder than normal weather in late 2013 that continued into the first quarter 2014 in the Mid-Continent region in ONEOK Partners’ Natural Gas Liquids segment.

Services revenues increased for the three and six months ended June 30, 2014, compared with the same periods in 2013, due to higher natural gas and NGL volumes from ONEOK Partners’ recently completed capital projects in its Natural Gas Gathering and Processing and Natural Gas Liquids segments, and higher transportation revenues due to increased rates, volumes and park-and-loan services as a result of weather-related seasonal demand in its Natural Gas Pipelines segment. These increases were offset partially by lower operational measurement gains in ONEOK Partners’ Natural Gas Liquids segment and lower storage revenues from lower contracted capacity in ONEOK Partners’ Natural Gas Pipelines segment.

Operating costs and depreciation and amortization increased for the three and six months ended June 30, 2014, compared with the same periods in 2013, due primarily to the growth of ONEOK Partners’ operations related to its completed capital projects.

Equity earnings from investments increased for the six months ended June 30, 2014, compared with the same period in 2013, due to increased park-and-loan services on Northern Border Pipeline in the first quarter 2014 as a result of weather-related seasonal demand and higher volumes on Overland Pass Pipeline delivered from ONEOK Partners’ Bakken NGL Pipeline as a result of increased volumes from ONEOK Partners recently completed capital projects, offset partially by increased ethane rejection and higher operating costs.

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Interest expense increased for the three and six months ended June 30, 2014, compared with the same periods in 2013, due primarily to interest costs from ONEOK Partners’ $1.25 billion debt issuance in September 2013. Interest expense also increased for the six months ended June 30, 2014 due to write-offs in the first quarter 2014 of approximately $7.7 million due to the discontinuance of cash flow hedge treatment for interest-rate swaps related to early retirement of long-term debt; and $2.9 million related to amortization of previous credit agreement issuance costs related to reducing the borrowing capacity of the credit agreement. This increase was offset partially by higher capitalized interest associated with the investments in ONEOK Partners’ growth projects and decreased interest expense from the early retirement of approximately $553 million of ONEOK’s long-term debt.

Net income attributable to noncontrolling interests, which reflects primarily the portion of ONEOK Partners that we do not own, increased for the three and six months ended June 30, 2014, compared with the same periods in 2013, due to higher earnings at ONEOK Partners.

Capital expenditures decreased for the three and six months ended June 30, 2014, compared with the same periods in 2013, due to the timing of expenditures on ONEOK Partners growth projects and the separation of the natural gas distribution business on January 31, 2014. The prior-year capital expenditures reflect three and six months, respectively, of capital expenditures for our former natural gas distribution business.

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

Natural Gas Gathering and Processing

Overview -ONEOK Partners’ Natural Gas Gathering and Processing segment provides nondiscretionary services to producers that include gathering and processing of natural gas produced from crude oil and natural gas wells. Unprocessed natural gas is compressed and gathered through pipelines and transported to processing facilities where volumes are aggregated, treated and processed to remove water vapor, solids and other contaminants, and to extract NGLs in order to provide marketable natural gas, commonly referred to as residue gas.  The residue gas, which consists primarily of methane, is compressed and delivered to natural gas pipelines for transportation to end-users. When the NGLs are separated from the unprocessed natural gas at the processing plants, the NGLs are in the form of a mixed, unfractionated NGL stream that is delivered to natural gas liquids gathering pipelines for transportation to natural gas liquids fractionators.

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

The significant growth in the development of crude oil and NGL-rich natural gas in the Williston Basin has caused natural gas production to exceed the capacity of existing natural gas gathering and processing infrastructure, which results in the flaring of natural gas (the controlled burning of natural gas at the wellhead). In July 2014, the North Dakota Industrial Commission approved a policy designed to limit flaring at existing and future crude oil wells in the Bakken and Three Forks formations in the Williston Basin. The policy establishes crude oil production limits that will take effect if a producer fails to meet requirements to capture natural gas at the wellhead. ONEOK Partners is constructing additional natural gas gathering pipelines, compression and processing plants and natural gas liquids pipeline capacity that are expected to help alleviate capacity constraints. ONEOK Partners is evaluating the potential impact the new regulation might have on future crude oil and natural gas production and the natural gas volumes it gathers and processes in the Williston Basin.

Revenues for this segment are derived primarily from POP contracts with a fee-based component and fee-based contracts. Under a POP contract with a fee-based component, ONEOK Partners retains a percentage of the proceeds from the sale of residue natural gas, condensate and/or NGLs and charges fees for gathering, treating, compressing and processing the producer’s natural gas. With a fee-based contract, ONEOK Partners is paid a fee for the services it provides, based on volumes gathered, processed, treated and/or compressed.

ONEOK Partners expects its capital projects will continue to generate additional revenues, earnings and cash flows as they are completed. ONEOK Partners expects its natural gas liquids and natural gas commodity price sensitivity within this segment to

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increase in the future as its capital projects are completed and volumes increase under POP contracts with a fee-based component with its customers. ONEOK Partners uses commodity derivative instruments and physical-forward contracts to mitigate its sensitivity to fluctuations in the natural gas, crude oil and NGL prices received for its share of volumes.

Growth Projects - ONEOK Partners’ Natural Gas Gathering and Processing segment is investing approximately $3.8 billion to $4.3 billion from 2010 through 2016 in growth projects in NGL-rich areas in the Williston Basin, the Powder River Basin, the Cana-Woodford Shale and the SCOOP areas that it expects will enable it to meet the rapidly growing needs of crude oil and natural gas producers in those areas. Nearly all of the new natural gas production is from horizontally drilled and completed wells in nonconventional resource areas. These wells tend to produce volumes at higher initial 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. The capital needed to connect to new wells and expand our infrastructure is expected to increase compared with our historical levels of routine growth capital.

ONEOK Partners has completed approximately $1.6 billion in growth projects and acquisitions in this segment through July 2014, which include the following:

Completed Projects	Location	Capacity	Approximate Costs (a)	Completion Date
			(In millions)
Rocky Mountain Region
Garden Creek processing plant and infrastructure	Williston Basin	100 MMcf/d	$360	December 2011
Stateline I & II processing plants and infrastructure	Williston Basin	200 MMcf/d	$565	September 2012/April 2013
Divide County gathering system	Williston Basin	270 miles	$125	June 2013
Sage Creek processing plant and infrastructure (b)	Powder River Basin	50 MMcf/d	$152	September 2013
30 percent interest in Maysville processing plant (b)	Cana-Woodford Shale	40 MMcf/d	$90	December 2013
Mid-Continent Region
Canadian Valley processing plant and infrastructure	Cana-Woodford Shale	200 MMcf/d	$300	March 2014

(a) Excludes AFUDC.

(b) Acquisition.

ONEOK Partners is also constructing or plans to construct the following natural gas processing plants and related infrastructure through 2016:

Projects in Progress	Location	Capacity	Approximate Costs (a)	Expected Completion Date
			(In millions)
Rocky Mountain Region
Garden Creek II processing plant and infrastructure	Williston Basin	100 MMcf/d	$310-$345	Third quarter 2014
Garden Creek III processing plant and infrastructure	Williston Basin	100 MMcf/d	$325-$360	Fourth quarter 2014
Lonesome Creek processing plant and infrastructure	Williston Basin	200 MMcf/d	$550-$680	Fourth quarter 2015
Sage Creek infrastructure	Powder River Basin	n/a	$50	Fourth quarter 2015
Natural gas compression	Williston Basin	100 MMcf/d	$80-$100	Fourth quarter 2015
Demicks Lake processing plant and infrastructure	Williston Basin	200 MMcf/d	$515-$670	Third quarter 2016
Mid-Continent Region
Knox processing plant and infrastructure	SCOOP	200 MMcf/d	$365-$470	Fourth quarter 2016

(a) Excludes AFUDC.

Rocky Mountain Region:

Williston Basin Processing Plants and related projects - ONEOK Partners is constructing natural gas gathering and processing assets in the Williston Basin to meet the growing needs of crude oil and natural gas producers. When ONEOK Partners’ announced projects are completed, it will have natural gas processing capacity of approximately 1.1 Bcf/d in the basin. ONEOK Partners has acreage dedications of approximately 3 million acres supporting these projects.

Garden Creek II and III Plants - The Garden Creek II plant is expected to be completed during the third quarter 2014. The Garden Creek III plant, originally scheduled for completion in the first quarter 2015, is now scheduled for completion in the fourth quarter 2014.

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

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

Demicks Lake - In July 2014, ONEOK Partners announced the Demicks Lake natural gas processing plant and related infrastructure, which will be located in northeast McKenzie County, North Dakota, to help further address natural gas gathering and processing constraints in the region.

Powder River Basin - On September 30, 2013, ONEOK Partners completed the acquisition of a 50 MMcf/d natural gas processing facility, the Sage Creek plant, and related natural gas gathering and natural gas liquids infrastructure.  ONEOK Partners plans to upgrade existing natural gas processing infrastructure and construct new natural gas gathering infrastructure to meet the growing production of NGL-rich natural gas in this area. ONEOK Partners has supply contracts providing for long-term acreage dedications from producers in the area supporting this project.

Mid-Continent Region:

Cana-Woodford Shale and SCOOP areas - ONEOK Partners is constructing natural gas gathering and processing assets to meet the growing production of NGL-rich natural gas in the Cana-Woodford Shale and SCOOP areas. In March 2014, ONEOK Partners completed the Canadian Valley natural gas processing plant, which is located in the Cana-Woodford Shale. When the announced projects are completed, ONEOK Partners’ Oklahoma natural gas processing capacity will be approximately 900 MMcf/d. ONEOK Partners has substantial acreage dedications from crude oil and natural gas producers supporting these plants.

Knox Plant - In July 2014, ONEOK Partners announced it will construct the Knox natural gas processing plant and related infrastructure, which will be located in Grady and Stephens Counties, Oklahoma. The plant and related infrastructure will gather and process liquids-rich natural gas from the emerging SCOOP area and will be located in close proximity to ONEOK Partners existing natural gas and natural gas liquids pipelines.

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

Selected Financial Results - ONEOK Partners’ Natural Gas Gathering and Processing segment’s operating results for the three and six months ended June 30, 2014, reflect the benefits from the Canadian Valley natural gas processing plant, which was completed in March 2014; the acquisition of the Sage Creek natural gas processing plant in Wyoming in September 2013; and the acquisition of the remaining 30 percent undivided interest in its Maysville, Oklahoma, natural gas processing facility, which was acquired in December 2013. Additionally, operating results for the six months ended June 30, 2014, reflect the benefits of the Stateline II natural gas processing plant, which was placed in service in April 2013.

The completion of the Stateline II and Canadian Valley natural gas processing plants resulted in increased natural gas volumes gathered and processed in the Williston Basin and Oklahoma, respectively. ONEOK Partners expects drilling activities and development of the reserves to continue in the Williston Basin and NGL-rich areas of the Powder River Basin in the Rocky Mountain region and the Cana-Woodford Shale, Granite Wash and SCOOP areas in Oklahoma and Texas.

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

	Three Months Ended				Six Months Ended				Three Months					Six Months
	June 30,				June 30,				2014 vs. 2013					2014 vs. 2013
Financial Results	2014		2013		2014		2013		Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
NGL sales	$	354.8	$	230.6	$	734.7	$	464.0	$	124.2		54	%	$	270.7		58	%
Condensate sales	28.5		33.9		57.5		60.9		(5.4		)	(16	%)	(3.4		)	(6	%)
Residue natural gas sales	275.3		162.3		565.4		289.8		113.0			70	%	275.6			95	%
Gathering, compression, dehydration and processing fees and other revenue	64.7		55.5		127.9		105.1		9.2			17	%	22.8			22	%
Cost of sales and fuel	568.4		357.0		1,177.0		685.2		211.4			59	%	491.8			72	%
Net margin	154.9		125.3		308.5		234.6		29.6			24	%	73.9			32	%
Operating costs	59.4		45.0		124.2		96.7		14.4			32	%	27.5			28	%
Depreciation and amortization	29.4		25.1		58.3		49.0		4.3			17	%	9.3			19	%
Gain on sale of assets	—		0.3		—		0.3		(0.3		)	(100	%)	(0.3		)	(100	%)
Operating income	$	66.1	$	55.5	$	126.0	$	89.2	$	10.6		19	%	$	36.8		41	%
Equity earnings from investments	$	5.1	$	5.2	$	10.6	$	11.6	$	(0.1	)	(2	%)	$	(1.0	)	(9	%)
Capital expenditures	$	168.2	$	206.0	$	291.1	$	370.0	$	(37.8	)	(18	%)	$	(78.9	)	(21	%)

Net margin increased for the three months ended June 30, 2014, compared with the same period in 2013, primarily as a result of the following:

• an increase of $24.6 million due primarily to natural gas volume growth in the Williston Basin and Cana-Woodford Shale and increased ownership of ONEOK Partners’ Maysville, Oklahoma, natural gas processing plant resulting in higher natural gas volumes gathered, compressed, processed, transported and sold, and higher NGL volumes sold;

• an increase of $8.1 million due primarily to higher net realized prices; and

• an increase of $3.4 million due primarily to changes in contract mix; offset partially by

• a decrease of $6.4 million due to a condensate contract settlement in 2013.

Net margin increased for the six months ended June 30, 2014, compared with the same period in 2013, primarily as a result of the following:

• an increase of $61.4 million due primarily to natural gas volume growth in the Williston Basin and Cana-Woodford Shale and increased ownership of ONEOK Partners’ Maysville, Oklahoma, natural gas processing plant resulting in higher natural gas volumes gathered, compressed, processed, transported and sold, higher NGL volumes sold, and higher fees, offset partially by wellhead freeze-offs due to severely cold weather in the first quarter 2014;

• an increase of $13.9 million due primarily to higher net realized prices; and

• an increase of $5.1 million due primarily to changes in contract mix; offset partially by

• a decrease of $6.4 million due to a condensate contract settlement in 2013.

Operating costs increased for the three and six months ended June 30, 2014, compared with the same periods in 2013, primarily as a result of the completion of ONEOK Partners’ growth projects and acquisitions, which include the following:

• an increase of $9.4 million and $21.4 million, respectively, due to higher materials and supplies, and outside services expenses; and

• an increase of $7.6 million and $8.8 million, respectively, in employee-related costs due to higher labor and employee benefit costs; offset partially by

• a decrease of $2.6 million and $2.7 million, respectively, due to the timing of ad valorem tax estimates in 2014.

Depreciation and amortization expense increased for the three and six months ended June 30, 2014, compared with the same periods in 2013, due to the completion of ONEOK Partners’ growth projects and acquisitions.

Capital expenditures decreased for the three and six months ended June 30, 2014, compared with the same periods in 2013, due primarily to the timing of expenditures for ONEOK Partners’ growth projects discussed above. During the second quarter 2014, ONEOK Partners connected approximately 360 new wells to its systems compared with approximately 350 in the same period in 2013. For the six months ended June 30, 2014, ONEOK Partners connected approximately 590 wells to its system

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compared with approximately 600 in the same period in 2013. The decrease for the six-month period was due to much colder than normal weather, which impacted construction activities in the Williston Basin in the first quarter 2014.

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
Operating Information (a)	2014		2013		2014		2013
Natural gas gathered (BBtu/d)	1,646		1,326		1,573		1,271
Natural gas processed (BBtu/d) (b)	1,447		1,055		1,358		1,022
NGL sales (MBbl/d)	98		75		94		73
Residue natural gas sales (BBtu/d)	683		467		626		451
Realized composite NGL net sales price ($/gallon) (c)	$	0.96	$	0.85	$	1.00	$	0.85
Realized condensate net sales price ($/Bbl) (c)	$	77.46	$	83.86	$	76.80	$	86.06
Realized residue gas net sales price ($/MMBtu) (c)	$	4.07	$	3.57	$	3.85	$	3.55
Average fee rate ($/MMBtu)	$	0.34	$	0.34	$	0.36	$	0.35

(a) - Includes volumes for consolidated entities only.

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

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

Natural gas volumes gathered and processed, and NGL and residue natural gas sold, increased for the three and six months ended June 30, 2014, compared with the same periods in 2013, due to new processing plants placed in service and increased ownership of ONEOK Partners’ Maysville, Oklahoma, natural gas processing plant, offset partially by continued declines in coal-bed methane production in the Powder River Basin in Wyoming and natural gas production declines in Kansas. The realized composite NGL net sales price increased for the three and six months ended June 30, 2014, compared with the same periods in 2013, due primarily to higher prices from increased demand associated with colder than normal weather and lower propane storage levels in the first quarter 2014.

The quantity and composition of NGLs and natural gas continues to change as ONEOK Partners’ new natural gas processing plants in the Williston Basin and Mid-Continent are placed in service. In March 2014, ONEOK Partners’ Canadian Valley plant in Oklahoma was completed, which has better ethane rejection capabilities than its other processing plants in the Mid-Continent region. ONEOK Partners’ Garden Creek, Stateline I and Stateline II plants in the Williston Basin have the capability to recover ethane when economic conditions warrant but did not do so during the first six months of 2014. Equity NGL volumes also are expected to be weighted more toward propane, iso-butane, normal butane and natural gasoline due to expected ethane rejection through much of 2016.

	Three Months Ended		Six Months Ended
	June 30,		June 30,
Equity Volume Information (a)	2014	2013	2014	2013
NGL sales (MBbl/d)	15.9	13.9	16.8	13.4
Condensate sales (MBbl/d)	3.1	2.5	3.3	2.6
Residue natural gas sales (BBtu/d)	105.3	68.8	96.9	63.1

(a) - Includes volumes for consolidated entities only.

Commodity-Price Risk - The following tables set forth ONEOK Partners’ Natural Gas Gathering and Processing segment’s hedging information for its equity volumes for the periods indicated:

	Six Months Ending December 31, 2014
	Volumes Hedged	Average Price			Percentage Hedged
NGLs (MBbl/d)	11.1	$	1.17	/ gallon	57%
Condensate (MBbl/d)	2.5	$	2.22	/ gallon	73%
Total (MBbl/d)	13.6	$	1.36	/ gallon	60%
Natural gas (BBtu/d)	89.2	$	4.06	/ MMBtu	76%

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	Year Ending December 31, 2015
	Volumes Hedged	Average Price			Percentage Hedged
NGLs (MBbl/d)	1.2	$	1.07	/ gallon	7%
Natural gas (BBtu/d)	61.3	$	4.34	/ MMBtu	44%

ONEOK Partners expects its natural gas liquids and natural gas commodity-price sensitivity within this segment to increase in the future as capital projects are completed and volumes increase under POP contracts with customers.  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, 2014, excluding the effects of hedging and assuming normal operating conditions. Condensate sales are based on the price of crude oil.  ONEOK Partners estimates the following:

• a $0.01 per-gallon change in the composite price of NGLs would change annual net margin by approximately $2.7 million;

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

• a $0.10 per-MMBtu change in the price of residue natural gas would change annual net margin by approximately $4.6 million.

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

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

Equity Investments - Low natural gas prices and the relatively higher crude oil and NGL prices, compared with natural gas on a heating-value basis, have caused producers primarily to focus their development efforts on crude oil and NGL-rich supply basins rather than in areas with dry natural gas production, such as the coal-bed methane production areas in the Powder River Basin.  The reduced coal-bed methane development activities and production declines in the dry natural gas formations of the Powder River Basin have resulted in lower natural gas volumes available to be gathered.  While the reserve potential in the dry natural gas formations of the Powder River Basin still exists, future drilling and development will be affected by commodity prices and producers’ alternative prospects. In the near term, a continued decline in volumes gathered in this area may reduce our ability to recover the carrying value of ONEOK Partners’dry natural gas assets and equity investments in this area and could result in noncash charges to earnings.

Due to recent reductions in producer activity and declines in natural gas volumes gathered in the dry natural gas area of the Powder River Basin on the Bighorn Gas Gathering system, in which ONEOK Partners owns a 49 percent equity interest, ONEOK Partners tested its investment for impairment at December 31, 2013. The estimated fair value exceeded the carrying value; however, a decline of 10 percent or more in the fair value of its investment in Bighorn Gas Gathering would result in a noncash impairment charge. ONEOK Partners was not able to reasonably estimate a range of potential future impairment charges, as many of the assumptions that would be used in its estimate of fair value are dependent upon events beyond its control. The carrying amount of ONEOK Partners’ investment at June 30, 2014, was $85.7 million, which includes $53.4 million in equity method goodwill.

Natural Gas Liquids

Overview - ONEOK Partners’ Natural Gas Liquids segment owns and operates facilities that gather, fractionate, treat and distribute NGLs and store NGL products, primarily in Oklahoma, Kansas, Texas and the Rocky Mountain region where it provides nondiscretionary services to producers of NGLs.  It owns or has an ownership interest in FERC-regulated natural gas liquids gathering and distribution pipelines in Oklahoma, Kansas, Texas, 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 that connect with its NGL fractionation and pipeline assets.  In April 2013, ONEOK Partners began transporting unfractionated NGLs from natural gas processing plants in the Williston Basin on its Bakken NGL Pipeline. These

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unfractionated NGLs previously were transported by rail to its Mid-Continent natural gas liquids fractionation facilities. ONEOK Partners continues to use its rail-terminal facilities in its NGL marketing activities.

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

Revenues for the Natural Gas Liquids segment are derived primarily from nondiscretionary fee-based services that ONEOK Partners provides to its customers and from the physical optimization of its assets.  ONEOK Partners’ fee-based services have increased due primarily to new supply connections, expansion of existing connections and its previously completed capital projects, including the Bakken NGL Pipeline, Sterling III Pipeline, Cana-Woodford Shale and Granite Wash projects, and expansion of its NGL fractionation capacity, including the completion of its MB-2 fractionator in December 2013. ONEOK Partners’ sources of revenue are categorized as exchange services, optimization and marketing, pipeline transportation, isomerization and storage, which are defined as follows:

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

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

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

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

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

Since late 2012, NGL location price differentials have generally remained narrow between the Mid-Continent and Gulf Coast market centers. ONEOK Partners expects these narrower NGL price differentials, with periods of volatility for certain NGL products, to continue as new fractionators and pipelines, including its growth projects discussed below, continue to alleviate constraints between the Conway, Kansas, and Mont Belvieu, Texas, natural gas liquids market centers. In addition, new natural gas liquids pipeline projects constructed by third parties are expected to bring incremental NGL supply from the Rocky Mountain, Marcellus and Utica regions to the Mont Belvieu, Texas, market center that may affect NGL prices, as well as compete with or displace NGL supply volumes from the Mid-Continent and Rocky Mountain regions where its assets are located. ONEOK Partners’ Natural Gas Liquids segment’s capital growth projects are backed by fee-based supply commitments that it expects will fill much of its optimization capacity used historically to capture NGL location price differentials between the two market centers.

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.  Increasing crude oil, natural gas and NGL production resulting from this activity and higher petrochemical industry demand for NGL products 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 in the next three to five years, and international demand for NGLs, particularly propane, also is increasing and is expected to continue to do so in the future.

ONEOK Partners’ Natural Gas Liquids segment is investing approximately $3.2 billion in NGL-related projects from 2010 through 2016.  These investments will accommodate the transportation and fractionation of growing NGL supply from shale and other resource development areas across ONEOK Partners’ asset base and alleviate infrastructure constraints between the

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Mid-Continent and Gulf Coast market centers to meet increasing petrochemical industry and NGL export demand in the Gulf Coast. Over time, these growing fee-based NGL volumes are expected to fill much of ONEOK Partners’ natural gas liquids pipeline capacity used historically to capture the NGL location price differentials between the two market centers.

ONEOK Partners has completed approximately $2.2 billion in growth projects in this segment through July 2014, which include the following:

Completed Projects	Capacity	Approximate Costs	Completion Date
		(In millions)
Sterling I expansion	15 MBbl/d	$30	November 2011
Cana-Woodford/Granite Wash NGL plant connections	60 MBbl/d	$220	April 2012
Bushton fractionator expansion	60 MBbl/d	$117	September 2012
Bakken NGL Pipeline	60 MBbl/d	$455	April 2013
Overland Pass Pipeline expansion	45 MBbl/d	$36	April 2013
Ethane Header pipeline	250 MBbl/d	$23	April 2013
Sage Creek NGL infrastructure (a)	n/a	$153	September 2013
MB-2 Fractionator	75 MBbl/d	$375	December 2013
Ethane/Propane Splitter	40 MBbl/d	$46	March 2014
Sterling III Pipeline and reconfigure Sterling I and II	193 MBbl/d	$767	March 2014

(a) Acquisition.

ONEOK Partners is also constructing, or plans to construct, the following projects through 2016:

Projects in Progress	Capacity	Approximate Costs	Completion Date
		(In millions)
Bakken NGL Pipeline expansion - Phase I	75 MBbl/d	$100	Third quarter 2014
MB-3 Fractionator	75 MBbl/d	$525-$575	Fourth quarter 2014
Sage Creek NGL infrastructure expansion	90 miles	$85	Fourth quarter 2014
NGL pipeline and Hutchinson Fractionator infrastructure	95 miles	$140	First quarter 2015
Bakken NGL Pipeline expansion - Phase II	25 MBbl/d	$100	Second quarter 2016
Demicks Lake infrastructure	12 miles	$10-$15	Fourth quarter 2016

Sterling III Pipeline - In March 2014, ONEOK Partners completed a 550-mile natural gas liquids pipeline, which has the flexibility to transport either unfractionated NGLs or NGL products from the Mid-Continent to the Gulf Coast.  The pipeline is designed to transport up to 193 MBbl/d of NGL production from Medford, Oklahoma, to its storage and fractionation facilities in Mont Belvieu, Texas.  ONEOK Partners has multi-year supply commitments from producers and natural gas processors for approximately 75 percent of the pipeline’s capacity.  Installation of additional pump stations could expand the capacity of the pipeline to 260 MBbl/d. This project also included the reconfiguration of ONEOK Partners’ existing Sterling I and Sterling II pipelines to transport either unfractionated NGLs or NGL products. The reconfiguration was completed in July 2014.

Ethane/Propane Splitter - In March 2014, ONEOK Partners placed in service an ethane/propane splitter at its Mont Belvieu storage facility to split ethane/propane mix into purity ethane in order to meet the needs of petrochemical customers, which ONEOK Partners expects will grow over the long term. The facility is capable of producing 32 MBbl/d of purity ethane and 8 MBbl/d of propane.

Bakken NGL Pipeline Expansions - The first expansion increases the pipeline’s capacity to 135 MBbl/d from the original capacity of 60 MBbl/d, with the second expansion bringing the pipeline’s capacity to 160 MBbl/d. These expansions will accommodate the growing NGL supply from the Williston and Powder River Basins.

MB-3 Fractionator - ONEOK Partners is constructing the MB-3 fractionator near its storage facility in Mont Belvieu, Texas.  In addition, ONEOK Partners plans to expand and upgrade its existing natural gas liquids gathering and pipeline infrastructure, including new connections to natural gas processing facilities and increasing the capacity of its Arbuckle and Sterling II natural gas liquids pipelines. ONEOK Partners has multi-year supply commitments from producers and natural gas processors for approximately 80 percent of the fractionator’s capacity.

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Sage Creek related infrastructure - ONEOK Partners is constructing new natural gas liquids pipeline infrastructure to connect the Sage Creek natural gas processing plant to its Bakken NGL Pipeline.

New natural gas liquids pipeline and modification of Hutchinson fractionation infrastructure - ONEOK Partners is constructing a new 95-mile natural gas liquids pipeline that will connect its existing natural gas liquids fractionation and storage facilities in Hutchinson, Kansas, to similar facilities in Medford, Oklahoma. The project also includes modifications to existing natural gas liquids fractionation infrastructure at Hutchinson, Kansas, to accommodate additional unfractionated NGLs produced in the Williston Basin.

Demicks Lake natural gas liquids infrastructure - ONEOK Partners announced in July 2014 it plans to build new natural gas liquids pipeline infrastructure to connect the Demicks Lake natural gas processing plant to its Bakken NGL Pipeline.

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

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,				2014 vs. 2013					2014 vs. 2013
Financial Results	2014		2013		2014		2013		Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
NGL and condensate sales	$	2,405.0	$	2,267.7	$	4,890.8	$	4,317.7	$	137.3		6	%	$	573.1		13	%
Exchange service and storage revenues	243.3		209.0		445.9		401.3		34.3			16	%	44.6			11	%
Transportation revenues	17.0		14.4		40.4		36.8		2.6			18	%	3.6			10	%
Cost of sales and fuel	2,399.2		2,271.9		4,842.0		4,350.0		127.3			6	%	492.0			11	%
Net margin	266.1		219.2		535.1		405.8		46.9			21	%	129.3			32	%
Operating costs	76.0		54.2		141.2		114.1		21.8			40	%	27.1			24	%
Depreciation and amortization	31.1		22.3		58.2		42.0		8.8			39	%	16.2			39	%
Operating income	$	159.0	$	142.7	$	335.7	$	249.7	$	16.3		11	%	$	86.0		34	%
Equity earnings from investments	$	4.5	$	5.9	$	9.2	$	9.0	$	(1.4	)	(24	%)	$	0.2		2	%
Capital expenditures	$	210.7	$	269.3	$	483.7	$	543.5	$	(58.6	)	(22	%)	$	(59.8	)	(11	%)

Several factors contributed to increased propane demand and price in the first quarter 2014, which impacted our results of operations for the six-months ended 2014. In the fourth quarter 2013, ONEOK Partners experienced high propane demand for crop drying and increased heating demand due to colder than normal weather that continued into the first quarter 2014. In response to increased demand, propane prices at the Mid-Continent market center at Conway, Kansas, increased significantly, compared with propane prices at the Gulf Coast market center at Mont Belvieu, Texas. To help meet the demand and capture the wider location price differentials between these two markets, ONEOK Partners utilized its assets to deliver more propane into the Mid-Continent region from the Gulf Coast region. The price of propane in the Mid-Continent market and the wider location price differentials between the Mid-Continent and Gulf Coast market centers peaked in late January 2014 and returned to historical levels by the end of February 2014 as supply and demand balanced.

Ethane rejection in the Rocky Mountain and Mid-Continent regions continued in the second quarter 2014 as expected, resulting in capacity being available on ONEOK Partners’ pipelines that connect the Mid-Continent and Gulf Coast market centers, a portion of which it was able to utilize for optimization activities, including the delivery of propane into the Mid-Continent region during the first quarter 2014. Severely cold weather in the first quarter 2014 caused wellhead freeze-offs, which also reduced volumes.

Net margin increased for the three months ended June 30, 2014, compared with the same period in 2013, primarily as a result of the following:

• an increase of $31.4 million in exchange-services margins, which resulted primarily from higher NGL volumes delivered from the Bakken NGL Pipeline, volumes from new plants connected in the Mid-Continent region, and higher fees for exchange-services activities resulting from contract renegotiations, offset partially by lower volumes from the termination of a contract;

• an increase of $17.3 million related to higher isomerization volumes, resulting from the wider NGL product price differential between normal butane and iso-butane; and

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• an increase of $1.3 million in storage margins due primarily to contract renegotiations; offset partially by

• a decrease of $2.7 million due to the impact of lower operational measurement gains.

• Optimization and marketing margins were relatively unchanged, primarily due to a $12.5 million decrease from narrower NGL location price differentials and lower volumes, offset partially by an $8.0 million increase due primarily to wider NGL product price differentials; and a $4.4 million increase in marketing margins.

Net margin increased for the six months ended June 30, 2014, compared with the same period in 2013, primarily as a result of the following:

• an increase of $72.4 million in optimization and marketing margins, which resulted from a $28.2 million increase due primarily to significantly wider NGL location price differentials, primarily related to increased weather-related seasonal demand for propane during the first quarter 2014; a $26.2 million increase due primarily to wider NGL product price differentials; and a $18.0 million increase in marketing margins related primarily to increased weather-related seasonal demand for propane during the first quarter 2014;

• an increase of $39.4 million in exchange-services margins, which resulted primarily from higher NGL volumes delivered from the Bakken NGL Pipeline, volumes from new plants connected in the Mid-Continent region, and higher fees for exchange-services activities resulting from contract renegotiations, offset partially by lower volumes from the termination of a contract;

• an increase of $20.6 million related to higher isomerization volumes, resulting from the wider NGL product price differential between normal butane and iso-butane; and

• an increase of $4.7 million in storage margins due primarily to contract renegotiations; offset partially by

• a decrease of $4.1 million due to the impact of lower operational measurement gains, and

• a decrease of $3.8 million resulting from the impact of ethane rejection, which resulted in lower NGL volumes.

Operating costs increased for the three months ended June 30, 2014, compared with the same period in 2013, primarily as a result of the following:

• an increase of $8.7 million due to higher outside services expenses associated primarily with scheduled maintenance and the growth of operations related to completed capital projects;

• an increase of $4.5 million due to higher ad valorem taxes related to completed capital projects; and

• an increase of $4.0 million due to higher employee-related expenses due primarily to recently completed capital projects and the growth of ONEOK Partners’ operations.

Operating costs increased for the six months ended June 30, 2014, compared with the same period in 2013, primarily as a result of the following:

• an increase of $11.0 million due to higher outside services expenses associated primarily with scheduled maintenance and the growth of operations related to completed capital projects;

• an increase of $6.6 million due to higher ad valorem taxes related to completed capital projects;

• an increase of $5.0 million due to higher employee-related expenses due primarily to recently completed capital projects and the growth of ONEOK Partners’ operations; and

• an increase of $1.4 million due to higher chemical, materials and supplies expense.

Depreciation and amortization expense increased for the three and six months ended June 30, 2014, compared with the same periods in 2013, due to depreciation associated with completed capital projects.

Equity earnings decreased for the three months ended June 30, 2014, compared with the same period in 2013, due primarily to increased ethane rejection and higher operating costs, offset partially by higher volumes delivered to Overland Pass Pipeline from ONEOK Partners’ Bakken NGL Pipeline, which was placed in service in April 2013.

Equity earnings were relatively unchanged for the six months ended June 30, 2014, compared with the same period in 2013, due primarily to higher volumes delivered to Overland Pass Pipeline from ONEOK Partners’ Bakken NGL Pipeline, which was placed in service in April 2013, offset partially by increased ethane rejection.

Capital expenditures decreased for the three and six months ended June 30, 2014, compared with the same periods in 2013, due primarily to the timing of expenditures for ONEOK Partners’ growth projects discussed above.

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
Operating Information	2014		2013		2014		2013
NGL sales (MBbl/d)	603		677		583		628
NGLs transported-gathering lines (MBbl/d) (a)	520		554		498		526
NGLs fractionated (MBbl/d) (b)	520		537		496		525
NGLs transported-distribution lines (MBbl/d) (a)	431		432		430		413
Average Conway-to-Mont Belvieu OPIS price differential - ethane in ethane/propane mix ($/gallon)	$	0.03	$	0.06	$	0.08	$	0.04

(a) - Includes volumes for consolidated entities only.

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

NGLs transported on gathering lines and NGLs fractionated decreased for the three and six months ended June 30, 2014, compared with the same periods in 2013, due primarily to the termination of a contract and increased ethane rejection in the Mid-Continent region, offset partially by increased volumes from the Williston Basin on ONEOK Partners’ completed Bakken NGL Pipeline and volume from new plants connected in the Mid-Continent region.

NGLs transported on distribution lines increased for the six months ended June 30, 2014, compared with the same periods in 2013, due primarily to higher NGL volumes, primarily propane during the first quarter 2014, transported to the Mid-Continent region due to increased demand.

Natural Gas Pipelines

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

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

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

• Viking Gas Transmission Company, which transports natural gas from an interconnection with TransCanada pipeline near Emerson, Manitoba, to serve local natural gas distribution companies in Minnesota, North Dakota and Wisconsin, and terminates at a connection with ANR Pipeline Company near Marshfield, Wisconsin;

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

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

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, Granite Wash, SCOOP and Mississippian Lime.  They also have access to the major natural gas producing formations, including the Mississippian Lime formation in south central Kansas.  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 Delaware and Cline producing formations in the Permian Basin; and transport natural gas throughout the western portion of Texas, including the Waha Hub where other pipelines may be accessed for transportation to western markets, the Houston Ship Channel market to the east and the Mid-Continent market to the north.

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

ONEOK Partners’ transportation contracts for its regulated natural gas storage activities are based upon rates stated in its tariffs. Tariffs specify the maximum rates that customers may be charged, which may be discounted to meet competition if necessary, and the general terms and conditions for pipeline transportation service, which are established at FERC or appropriate state

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jurisdictional agency proceedings known as rate cases.  In Texas and Kansas, natural gas storage service is a fee business that may be regulated by the state in which the facility operates and by the FERC for certain types of services.  In Oklahoma, natural gas storage operations are also a fee business but are not subject to rate regulation by the state and have market-based rate authority from the FERC for certain types of services.

Selected Financial Results -In the first quarter 2014, ONEOK Partners acquired a 130-mile natural gas pipeline in western Oklahoma for $28 million, of which $14 million will be paid in 2018, that provides service to two natural gas-fired electric power plants and is connected to ONEOK Partners’ existing intrastate natural gas pipeline in the state. The operating results from this acquisition are included in the results for the three and six months ended June 30, 2014.

The following table sets forth certain selected financial results for ONEOK Partners’ Natural Gas Pipelines segment for the periods indicated:

	Three Months Ended				Six Months Ended					Three Months					Six Months
	June 30,				June 30,					2014 vs. 2013					2014 vs. 2013
Financial Results	2014		2013		2014			2013		Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
Transportation revenues	$	66.4	$	54.8	$	140.4		$	115.5	$	11.6		21	%	$	24.9		22	%
Storage revenues	12.6		17.6		36.0			35.0		(5.0		)	(28	%)	1.0			3	%
Gas sales and other revenues	3.0		2.6		10.4			10.6		0.4			15	%	(0.2		)	(2	%)
Cost of sales	6.5		7.3		17.8			19.3		(0.8		)	(11	%)	(1.5		)	(8	%)
Net margin	75.5		67.7		169.0			141.8		7.8			12	%	27.2			19	%
Operating costs	27.3		25.0		54.8			52.1		2.3			9	%	2.7			5	%
Depreciation and amortization	10.9		10.8		21.7			21.9		0.1			1	%	(0.2		)	(1	%)
Loss on sale of assets	—		—		(0.1		)	—		—			—	%	(0.1		)	*
Operating income	$	37.3	$	31.9	$	92.4		$	67.8	$	5.4		17	%	$	24.6		36	%
Equity earnings from investments	$	15.9	$	15.3	$	39.3		$	31.7	$	0.6		4	%	$	7.6		24	%
Capital expenditures	$	8.7	$	6.0	$	15.3		$	11.3	$	2.7		45	%	$	4.0		35	%
Cash paid for acquisitions	$	—	$	—	$	14.0		$	—	$	—		—	%	$	14.0		*

* Percentage change is greater than 100 percent.

Net margin increased for the three months ended June 30, 2014, compared with the same period in 2013, primarily as a result of the following:

• an increase of $9.4 million due to higher transportation revenues primarily from increased rates on ONEOK Partners’ intrastate pipelines, higher rates and contracted capacity on Midwestern Gas Transmission Company and increased interruptible transportation revenues from higher natural gas volumes transported;

• an increase of $1.4 million from additional storage services to meet utility customers’ peak-day demand; and

• an increase of $1.3 million from higher net retained fuel due primarily to additional natural gas volumes retained; offset partially by

• a decrease of $4.3 million due to lower storage revenues from lower contracted capacity.

Net margin increased for the six months ended June 30, 2014, compared with the same period in 2013, primarily as a result of the following:

• an increase of $13.8 million due to higher transportation revenues primarily from increased rates on ONEOK Partners’ intrastate pipelines, higher contracted capacity and rates on Midwestern Gas Transmission Company and increased interruptible transportation revenues from higher natural gas volumes transported;

• an increase of $6.1 million from increased short-term natural gas storage services due to increased park-and-loan services as a result of weather-related seasonal demand primarily in the first quarter 2014;

• an increase of $6.0 million from higher net retained fuel due to higher natural gas prices and additional natural gas volumes retained;

• an increase of $5.3 million due to increased park-and-loan services on ONEOK Partners’ interstate pipelines as a result of weather-related seasonal demand in the first quarter 2014; and

• an increase of $1.6 million primarily from additional storage services to meet utility customers’ peak-day demand; offset partially by

• a decrease of $5.7 million due to lower storage revenues from lower contracted capacity.

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Operating costs increased for the three and six months ended June 30, 2014, compared with the same periods in 2013, as a result of increased employee-related costs due to higher labor and employee benefit costs. The six month period was also impacted by higher materials and supplies expenses.

Equity earnings from ONEOK Partners’ investments increased $7.6 million for the six months ended June 30, 2014, compared with the same period in 2013, primarily due to increased park-and-loan services on Northern Border Pipeline as a result of increased weather-related seasonal demand in the first quarter 2014.

Capital expenditures increased for the three and six months ended June 30, 2014, compared with the same periods in 2013, due primarily to expenditures for system improvements.

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

	Three Months Ended						Six Months Ended
	June 30,						June 30,
Operating Information (a)	2014			2013			2014			2013
Natural gas transportation capacity contracted (MDth/d)	5,691			5,362			5,778			5,515
Transportation capacity subscribed	90		%	88		%	91		%	90		%
Average natural gas price
Mid-Continent region ($/MMBtu)	$	4.36		$	3.85		$	4.98		$	3.63

(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 producers to demand incremental services in the future to transport their production to market.  The abundance of shale gas supply and new regulations on emissions from coal-fired electric-generation plants may also increase the demand for ONEOK Partners’ services from electric-generation companies as they convert to a natural gas fuel source.  Conversely, contracted capacity by certain customers that are focused on capturing location or seasonal price differentials may decrease in the future due to narrowing price differentials. Overall, ONEOK Partners expects its fee-based earnings to remain relatively stable in the future as the development of shale and other resource areas continues.

CONTINGENCIES

Gas Index Pricing Litigation - As previously reported, ONEOK and its subsidiary, ONEOK Energy Services Company L.P. (OESC), along with several other energy companies, are defending multiple lawsuits arising from alleged market manipulation or false reporting of natural gas prices to natural gas-index publications. On April 10, 2013, the United States Court of Appeals for the Ninth Circuit reversed the summary judgments that had been granted in favor of ONEOK, OESC and other unaffiliated defendants in the following cases: Reorganized FLI, Learjet, Arandell, Heartland and NewPage. The Ninth Circuit also reversed the summary judgment that had been granted in favor of OESC on all state law claims asserted in the Sinclair case. ONEOK, OESC and the other unaffiliated defendants filed a Petition for Writ of Certiorari with the United States Supreme Court on August 26, 2013, seeking review of the Ninth Circuit decision. On July 1, 2014, the United States Supreme Court granted the Petition for Writ of Certiorari. Oral argument has not yet been scheduled.

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

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

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LIQUIDITY AND CAPITAL RESOURCES

General - Prior to the separation of our former natural gas distribution business, we relied primarily on operating cash flows, bank credit facilities, commercial paper, debt issuances and the issuance of equity for our liquidity and capital resource requirements. Effective in February 2014 and in connection with the separation, we terminated our commercial paper program and now fund operating expenses, debt service and dividends to shareholders with operating cash flows, which are primarily comprised of cash distributions received from ONEOK Partners.

ONEOK Partners relies primarily on operating cash flows, bank credit facilities, commercial paper, debt issuances and the issuance of equity for its liquidity and capital resource requirements. ONEOK Partners funds operating expenses, debt service and distributions to unitholders primarily with operating cash flows. Capital expenditures are funded by operating cash flows, short- and long-term debt and issuances of equity.

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

ONEOK - In March 2014, we completed the wind down of our energy services business. We expect future cash expenditures associated with the released transportation and storage capacity from the wind down of our energy services business on an after-tax basis to be approximately $60 million, with approximately $15 million paid in the remainder of 2014, $23 million in 2015, $11 million in 2016 and $11 million over the period 2017 through 2023.

On January 31, 2014, we completed the separation of ONE Gas. In conjunction with the separation, the following transactions occurred in the first quarter 2014:

• ONE Gas issued senior notes totaling $1.2 billion, generating net proceeds of approximately $1.19 billion;

• we received a cash distribution of approximately $1.13 billion from the proceeds of the ONE Gas senior notes offering;

• we repaid all commercial paper outstanding, which totaled approximately $600.5 million;

• we paid $150.0 million to retire $152.5 million of senior notes through a tender offer;

• we called $400 million of senior notes that we repaid in March 2014 for a total of $430.1 million, which included accrued but unpaid interest to the redemption date;

• we recorded a loss on extinguishment of $24.8 million in other expense and reclassified losses to interest expense of $7.7 million due to the discontinuance of cash flow hedge treatment for interest-rate swaps related to the debt retirements;

• we reduced our credit facility to $300 million from $1.2 billion; and

• we wrote off $2.9 million of previously deferred credit agreement issuance costs to interest expense.

As a result of the separation of our former natural gas distribution business and the wind down of our energy services business, the cash flow sources and requirements for ONEOK have changed significantly. ONEOK’s primary source of cash inflows are expected to be distributions to us from our general partner and limited partnership interests in ONEOK Partners. The cash distributions that we expect to receive from ONEOK Partners are expected to provide sufficient resources to finance our operations and quarterly cash dividends. Our next long-term debt maturity is in 2022.

ONEOK Partners - In the first six months of 2014, ONEOK Partners utilized cash from operations, its commercial paper program and proceeds from its equity issuances, including its May 2014 equity offering and “at-the-market” equity program, to fund its short-term liquidity needs and capital projects. See discussion under “Short-term Liquidity and “Long-term Financing” for more information.

ONEOK Partners’ ability to continue to access capital markets for debt and equity financing under reasonable terms depends on ONEOK Partners’ financial condition, credit ratings and market conditions. ONEOK Partners expects to fund its future capital expenditures with short- and long-term debt, the issuance of equity and operating cash flows. ONEOK Partners anticipates that these sources of funds will enable it to maintain its current and planned level of operations.

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Capitalization Structure - ONEOK, through its wholly owned subsidiary, ONEOK Partners GP, ONEOK Partners’ sole general partner, is responsible for directing the activities of ONEOK Partners, but ONEOK is not liable for, nor does it guarantee, any of ONEOK Partners’ liabilities. Likewise, ONEOK Partners is not liable for, nor does it guarantee, any of ONEOK’s liabilities. Significant legal and financial separations exist between ONEOK and ONEOK Partners. Additionally, for purposes of determining compliance with financial covenants in the ONEOK Credit Agreement, which are described below, the debt of ONEOK Partners is excluded.

The following table sets forth our consolidated capitalization structure at the dates indicated:

	June 30,	December 31,
	2014	2013
Long-term debt	66%	62%
Total equity	34%	38%
Debt (including notes payable)	66%	63%
Total equity	34%	37%

ONEOK Partners’ capitalization structure was 51 percent debt, including notes payable, and 49 percent equity at June 30, 2014. ONEOK Partners’ capitalization structure was 55 percent debt, including notes payable, and 45 percent equity at December 31, 2013.

Short-term Liquidity - ONEOK’s principal source of short-term liquidity is expected to be quarterly distributions from ONEOK Partners and cash on hand. We have access to our $300 million ONEOK Credit Agreement but do not expect to draw upon the facility. We terminated our commercial paper program in February 2014.

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. To the extent commercial paper is unavailable, ONEOK Partners’ revolving credit agreement may be used.

ONEOK Credit Agreement - Effective January 31, 2014, the ONEOK Credit Agreement was amended and restated to reduce available capacity to $300 million from $1.2 billion and to amend certain other provisions.

In February 2014, ONEOK repaid all commercial paper outstanding. At June 30, 2014, ONEOK had $2.1 million in letters of credit issued under the ONEOK Credit Agreement and approximately $80.5 million of cash and cash equivalents. ONEOK had approximately $297.9 million of credit available at June 30, 2014, 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, 2014, ONEOK’s ratio of indebtedness to Consolidated EBITDA, was 1.7 to 1, and ONEOK was in compliance with all covenants under the ONEOK Credit Agreement.

The ONEOK Credit Agreement also includes a $50 million sublimit for the issuance of standby letters of credit and a $50 million sublimit for swingline loans. Under the terms of the ONEOK Credit Agreement, ONEOK may request an increase in the size of the facility to an aggregate of $500 million from $300 million by either commitments from new lenders or increased commitments from existing lenders.

ONEOK Partners Credit Agreement - The total amount of short-term borrowings authorized by the Board of Directors of ONEOK Partners GP, the general partner of ONEOK Partners, is $2.5 billion.  At June 30, 2014, ONEOK Partners had no commercial paper outstanding, $14.0 million of letters of credit issued, no borrowings outstanding under the ONEOK Partners Credit Agreement, approximately $278.0 million of cash and approximately $1.7 billion of credit available under the ONEOK Partners Credit Agreement.  At June 30, 2014, ONEOK Partners could have issued $3.6 billion of short- and long-term debt to meet its liquidity needs under the most restrictive provisions contained in its various borrowing agreements. Based on the forward LIBOR curve, ONEOK Partners expects interest rates to increase in the next year, compared with interest rates on amounts outstanding during the previous 24 months.

The ONEOK Partners Credit Agreement, which was amended and restated effective on January 31, 2014, and expires in January 2019, is a $1.7 billion revolving credit facility and includes a $100 million sublimit for the issuance of standby letters

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of credit, a $150 million swingline sublimit and an option to request an increase in the size of the facility to an aggregate of $2.4 billion by either commitments from new lenders or increased commitments from existing lenders. The ONEOK Partners Credit Agreement is available for general partnership purposes. During the second quarter 2014, ONEOK Partners increased the size of its commercial paper program to $1.7 billion from $1.2 billion. Amounts outstanding under ONEOK Partners’ commercial paper program reduce the borrowing capacity under the ONEOK Partners Credit Agreement.

The ONEOK Partners Credit Agreement contains 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 be increased to 5.5 to 1 for the quarter in which the acquisition was completed and the two following quarters.  As a result of a pipeline acquisition ONEOK Partners completed in the first quarter 2014, the allowable ratio of indebtedness to adjusted EBITDA increased to 5.5 to 1 through the third quarter 2014. Upon breach of certain covenants by ONEOK Partners 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, 2014, ONEOK Partners’ ratio of indebtedness to adjusted EBITDA was 3.4 to 1, and ONEOK Partners was in compliance with all covenants under the ONEOK Partners Credit Agreement.

Long-term Financing - We do not expect to issue additional equity or long-term notes, as our next debt maturity is not until 2022 and our operating cash requirements are expected to be funded by cash distributions received from ONEOK Partners. Therefore, changes in the debt and equity markets are not expected to impact our financing requirements.

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

ONEOK Partners 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 existing credit facilities, altering the timing of controllable expenditures, restricting future acquisitions and capital projects, or pursuing other debt or equity financing alternatives. ONEOK Partners also has access to its commercial paper program to meet cash requirements. Some of these alternatives could result in higher costs or negatively affect their respective credit ratings, among other factors. Based on ONEOK Partners’ general financial condition, market expectations regarding its future earnings and projected cash flows, and ONEOK Partners’ investment-grade credit ratings, we expect ONEOK Partners will be able to meet its cash requirements and maintain its investment-grade credit ratings.

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

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

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

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

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 $300 million. The program allows ONEOK Partners to offer and sell its common units at prices ONEOK Partners 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

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is under no obligation to offer and sell common units under the program. At June 30, 2014, ONEOK Partners had approximately $100.1 million available for issuance under the program.

During the six months ended June 30, 2014, ONEOK Partners sold approximately 3.0 million common units through this program. The net proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, were approximately $164.1 million, which were used for general partnership purposes. During the three months ended March 31, 2013, ONEOK Partners sold 300,000 common units through this program that resulted in net proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, of approximately $16.3 million and used the proceeds for general partnership purposes. There were no common units sold through this program in the second quarter 2013.

As a result of these transactions, our aggregate ownership interest in ONEOK Partners decreased to 38.5 percent at June 30, 2014, from 41.2 percent at December 31, 2013.

Interest-rate Swaps - ONEOK Partners has entered into forward-starting interest-rate swaps to hedge the variability of interest payments on a portion of forecasted debt issuances that may result from changes in the benchmark interest rate before the debt is issued. At December 31, 2013, ONEOK Partners had forward-starting interest-rate swaps with notional amounts totaling $400 million, which had settlement dates greater than 12 months and are designated as cash flow hedges. In the first quarter 2014, ONEOK Partners entered into forward-starting interest-rate swaps with notional amounts totaling $500 million with settlement dates of less than 12 months that were 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.  Consolidated capital expenditures were $822.2 million and $1.1 billion for the six months ending June 30, 2014 and 2013, respectively.  Of these amounts, ONEOK Partners’ capital expenditures were $792.4 million and $924.8 million for the six months ended June 30, 2014 and 2013, respectively.  Capital expenditures decreased for the six months ended June 30, 2014, compared with the same period in 2013, due to timing of expenditures for ONEOK Partners’ growth projects and the separation of the natural gas distribution business on January 31, 2014. The prior year capital expenditures reflect three and six months, respectively, of capital expenditures for our former natural gas distribution business.

The following table sets forth ONEOK Partners’ 2014 projected capital expenditures, excluding AFUDC:

2014 Projected Capital Expenditures
	(Millions of dollars)
Natural Gas Gathering and Processing	$	1,214
Natural Gas Liquids	798
Natural Gas Pipelines	74
Other	23
Total projected capital expenditures	$	2,109

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

	ONEOK		ONEOK Partners
Rating Agency	Rating	Outlook	Rating	Outlook
Moody’s	Baa3	Stable	Baa2	Stable
S&P	BB+	Stable	BBB	Stable

ONEOK’s rating was downgraded to Baa3 by Moody’s and BB+ by S&P in February 2014 to reflect the separation of our former natural gas distribution business.

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

If ONEOK Partners’ credit ratings were downgraded, the cost to borrow funds under its commercial paper program and credit agreement would increase, and ONEOK Partners potentially could 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

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expires in January 2019. An adverse credit rating change alone is not a default under the ONEOK Credit Agreement or the ONEOK Partners Credit Agreement.

In the normal course of business, ONEOK Partners’ counterparties provide secured and unsecured credit.  In the event of a downgrade in ONEOK Partners’ credit ratings or a significant change in ONEOK Partners’ counterparties’ evaluation of its creditworthiness, ONEOK Partners could be required to provide additional collateral in the form of cash, letters of credit or other negotiable instruments as a condition of continuing to conduct business with such counterparties. ONEOK Partners may be required to fund margin requirements with its counterparties with cash, letters of credit or other negotiable instruments. There were no financial derivative instruments with contingent features related to credit risk that were in a net liability position at June 30, 2014.

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 are calculated after the allocation to the general partner’s partnership interest and before the allocation to the limited partners.

Commodity Prices - ONEOK Partners is subject to commodity price volatility. Significant fluctuations in commodity prices will affect its overall liquidity due to the impact commodity price changes have on its cash flows from operating activities, including the impact on working capital for NGLs and natural gas held in storage, margin requirements and certain energy-related receivables. ONEOK Partners believes that its available credit and cash and cash equivalents are adequate to meet liquidity requirements associated with commodity price volatility. See 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 J 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 impact net income but do not result in actual cash receipts or payments during the period and for operating cash items that do not affect 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 earnings from investments, distributions received from unconsolidated affiliates and changes in our assets and liabilities not classified as investing or financing activities.

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

							Variances
	Six Months Ended						2014 vs. 2013
	June 30,						Increase (Decrease)
	2014			2013
	(Millions of dollars)
Total cash provided by (used in):
Operating activities	$	536.3		$	788.3		$	(252.0	)
Investing activities	(820.5		)	(1,043.6		)	223.1
Financing activities	493.9			(294.6		)	788.5
Change in cash and cash equivalents	209.7			(549.9		)	759.6
Change in cash and cash equivalents included in discontinued operations	3.3			0.2			3.1
Change in cash and cash equivalents included in continuing operations	213.0			(549.7		)	762.7
Cash and cash equivalents at beginning of period	145.6			579.6			(434.0		)
Cash and cash equivalents at end of period	$	358.6		$	29.9		$	328.7

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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 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 approximately $577.0 million for the six months ended June 30, 2014, compared with $614.3 million for the same period in 2013.  The decrease was due primarily to the separation of ONE Gas, as discussed in Note B, resulting in decreased net income offset partially by higher operating income from ONEOK Partners, as discussed in “Financial Results and Operating Information.”

The changes in operating assets and liabilities decreased operating cash flows by approximately $40.7 million for the six months ended June 30, 2014, compared with an increase of $174.0 million for the same period in 2013.  This change is due primarily to the change in NGL volumes in storage and commodity imbalances. This change also is due to the change in accounts receivable, accounts payable and affiliate payables resulting from the timing of receipt of cash from customers and payments to vendors and suppliers, which vary from period to period.

Investing Cash Flows - Cash used in investing activities decreased for the six months ended June 30, 2014, compared with the same period in 2013, due primarily to the separation of ONE Gas, resulting in lower capital expenditures. Cash used in investing activities at ONEOK Partners decreased due to the timing of expenditures for its growth projects.

Financing Cash Flows - Cash provided by financing activities increased for the six months ended June 30, 2014, as compared with the same period in 2013, primarily due to the issuance of $1.2 billion of ONE Gas debt and higher sales of ONEOK Partners common units. This was offset partially by the ONEOK debt retirements, repayment of notes payable, $60 million of cash included in the ONE Gas separation and higher dividends and distributions paid.

REGULATORY

Financial Markets Legislation - The Dodd-Frank Act represents a far-reaching overhaul of the framework for regulation of United States financial markets. The CFTC has issued final regulations for most of the provisions of the Dodd-Frank Act, and we have implemented measures to comply with the regulations that are applicable to our businesses. ONEOK Partners continues to participate in financial markets for hedging certain risks inherent in its business, including commodity-price and interest-rate risks. Although the impact to date has not been material, we continue to monitor proposed regulations and the impact the regulations may have on our business and our risk-management strategies in the future.

ENVIRONMENTAL AND SAFETY MATTERS

Environmental Matters -ONEOK Partners is subject to multiple historical preservation, wildlife preservation and environmental laws and/or regulations that affect many aspects of its present and future operations.  Regulated activities include, but are not limited to, those involving air emissions, storm water and wastewater discharges, handling and disposal of solid and hazardous wastes, wetland 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 its results of operations.  For example, if a leak or spill of hazardous substances or petroleum products occurs from pipelines or facilities that ONEOK Partners owns, operates or otherwise uses, ONEOK Partners could be held jointly and severally liable for all resulting liabilities, including response, investigation and cleanup costs, which could affect materially its 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.  ONEOK Partners cannot assure that existing environmental statutes and regulations will not be revised or that new regulations will not be adopted or become applicable to it.

In June 2013, the Executive Office of the President of the United States (the President) issued the President’s Climate Action Plan, which includes, among other things, plans for further regulatory actions to reduce carbon emissions from various sources. On March 28, 2014, the President released the Climate Action Plan - Strategy to Reduce Methane Emissions (Methane Strategy) that lists a number of actions that the federal agencies will undertake to continue to reduce above-ground methane emissions from several industries, including the oil and natural gas sectors. The proposed measures outlined in the Methane Strategy include, without limitation, the following: collaboration with the states to encourage emission reductions; standards to minimize natural gas venting and flaring on public lands; policy recommendations for reducing emissions from energy infrastructure to increase the performance of the nation’s energy transmission, storage and distribution systems; and continued

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efforts by PHMSA to require pipeline operators to take steps to eliminate leaks and prevent accidental methane releases and evaluate the progress of states in replacing cast iron pipelines. The impact of any such proposed regulatory actions on ONEOK Partners’ facilities and operations is unknown. ONEOK Partners continues to monitor these proposed regulations and the impact they may have on its business. Revised or additional statutes or regulations that result in increased compliance costs or additional operating restrictions could have a significant impact on its business, financial position, results of operations and cash flows.

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

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

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

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

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

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

The potential capital and operating expenditures related to this legislation, the associated regulations or other new pipeline safety regulations are unknown.

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

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

ONEOK Partners’ 2013 total reported emissions were approximately 46.7 million metric tons of carbon dioxide equivalents. The 2013 total reportable emissions related to our former natural gas distribution business were approximately 14.0 million metric tons of carbon dioxide equivalents. These totals include direct emissions from the combustion of fuel in our equipment, such as compressor engines and heaters, as well as carbon dioxide equivalents from natural gas and NGL products delivered to customers and produced, as if all such fuel and NGL products were combusted. The additional cost to gather and report this emissions data did not have, and ONEOK Partners does not expect it to have, a material impact on its results of operations, financial position or cash flows.  In addition, Congress has considered, and may consider in the future, legislation to reduce greenhouse gas emissions, including carbon dioxide and methane. Likewise, the EPA may institute additional regulatory rulemaking associated with greenhouse gas emissions from the oil and gas industry. At this time, no rule or legislation has been enacted that assesses any costs, fees or expenses on any of these emissions.

The EPA’s “Tailoring Rule” regulates greenhouse gas emissions at new or modified facilities that meet certain criteria. Affected facilities are required to review BACT, conduct air-quality and conduct impact analysis and public reviews with respect to such emissions.  At current emissions threshold levels, this rule has had a minimal impact on ONEOK Partners’ existing facilities.  The EPA has stated it will consider lowering the threshold levels over the next five years, which could increase the impact on its existing facilities; however, potential costs, fees or expenses associated with the potential adjustments are unknown. In addition, on June 23, 2014, the Supreme Court of the United States, in a case styled, Utility Air Regulatory Group v. EPA, 530 U.S. (2014), held that an industrial facility’s potential to emit GHG emissions alone cannot subject a facility

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to the permitting requirements for major stationary source provisions of the Clean Air Act. The decision invalidated the EPA’s current Triggering and Tailoring Rule for GHG Prevention of Significant Deterioration (PSD) and Title V requirements. However, the Court also ruled that to the extent a source pursues a capital project (new construction or expansion of existing facility), which otherwise subjects the source to major source PSD permitting for conventional criteria pollutants, the permitting authorities may impose BACT analysis and emission limits for GHGs from those sources. We are in the process of evaluating the effects the decision may have on ONEOK Partners’ existing operations, and the opportunities it creates for design decisions for new project applications.

The EPA’s rule on air-quality standards, titled RICE NESHAP, initially included a compliance date in 2013, and has since become effective. While the rule could require capital expenditures for the purchase and installation of new emissions-control equipment, ONEOK Partners does not expect these expenditures will have a material impact on its results of operations, financial position or cash flows.

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

The rule was most recently amended in September 2013, and a further proposed rulemaking was published in July 2014. The EPA has indicated that further amendments may be issued in 2014. Based on the amendments, ONEOK Partners’ understanding of pending stakeholder responses to the NSPS rule and the proposed rulemaking, ONEOK Partners does not anticipate a material impact to its anticipated capital, operations and maintenance costs resulting from compliance with the regulation. However, the EPA may issue additional responses, amendments and/or policy guidance on the final rule, which could alter its present expectations. Generally, the NSPS rule will require expenditures for updated emissions controls, monitoring and record-keeping at affected facilities in the crude oil and natural gas industry. ONEOK Partners does not expect these expenditures will have a material impact on its results of operations, financial position or cash flows.

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

Chemical Site Security - The United States Department of Homeland Security (Homeland Security) released an interim rule in April 2007 that requires companies to provide reports on sites where certain chemicals, including many hydrocarbon products, are stored.  ONEOK Partners completed the Homeland Security assessments, and its facilities subsequently were assigned one of four risk-based tiers ranging from high (Tier 1) to low (Tier 4) risk, or not tiered at all due to low risk.  To date, four of its facilities have been given a Tier 4 rating.  Facilities receiving a Tier 4 rating are required to complete Site Security Plans and possible physical security enhancements.  ONEOK Partners does not expect the Site Security Plans and possible security enhancements cost to have a material impact on its results of operations, financial position or cash flows.

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

Environmental Footprint - ONEOK Partners environmental and climate change strategy focuses on minimizing the impact of its operations on the environment. These strategies include:  (i) developing and maintaining an accurate greenhouse gas emissions inventory according to current rules issued by the EPA; (ii) improving the efficiency of its various pipelines, natural gas processing facilities and natural gas liquids fractionation facilities; (iii) following developing technologies for emissions

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control and the capture of carbon dioxide to keep it from reaching the atmosphere; and (iv) utilizing practices to reduce the loss of methane from its facilities.

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

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 within the meaning of Section 27A of the Securities Act, as amended, and Section 21E of the Exchange Act, as amended.  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), 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 the Private Securities Litigation Reform Act of 1995.  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, which are applicable only as of the date of this Quarterly Report.  Known and unknown risks, uncertainties and other factors may cause our actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by forward-looking statements.  Those factors may affect our operations, markets, products, services and prices.  In addition to any assumptions and other factors referred to specifically in connection with the forward-looking statements, factors that could cause our actual results to differ materially from those contemplated in any forward-looking statement include, among others, the following:

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

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

• the capital intensive nature of our businesses;

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

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

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

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

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

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• 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;

• changes in demand for the use of natural gas and crude oil because of market conditions caused by concerns about global warming;

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

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

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

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

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

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

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

• the impact and outcome of pending and future litigation;

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

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

– competitive conditions in the overall energy market;

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

– availability of additional storage capacity;

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

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

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

• the mechanical integrity of facilities operated;

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

• our ability to control operating costs;

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

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

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

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

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

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

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

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

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

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

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

• the impact of potential impairment charges;

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

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• 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 Annual Report.  All forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these factors. Other than as required under securities laws, we undertake no obligation to update publicly any forward-looking statement whether as a result of new information, subsequent events or change in circumstances, expectations or otherwise.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

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

As a result of the separation of our natural gas distribution business on January 31, 2014 and the wind down of our energy services business on March 31, 2014, we are no longer exposed to market risks associated with these former segments.

COMMODITY-PRICE RISK

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

INTEREST-RATE RISK

We and ONEOK Partners are subject to the risk of interest-rate fluctuation in the normal course of business.  We and ONEOK Partners manage interest-rate risk through the use of fixed-rate debt, floating-rate debt and interest-rate swaps.  Interest-rate swaps are agreements to exchange interest payments at some future point based on specified notional amounts. At June 30, 2014, and December 31, 2013 ONEOK Partners had forward-starting interest-rate swaps with notional amounts totaling $900 million and $400 million, respectively, that have been designated as cash flow hedges of the variability of interest payments on a portion of a forecasted debt issuance that may result from changes in the benchmark interest rate before the debt is issued. The interest rate on all of our and ONEOK Partners’ long-term debt was fixed. Future issuances of long-term debt could be affected by changes in interest rates, which could result in higher interest costs.

ITEM 4. CONTROLS AND PROCEDURES

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

Changes in Internal Control Over Financial Reporting - There have been no changes in our internal control over financial reporting during the second quarter ended June 30, 2014, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II - OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

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

ITEM 1A. RISK FACTORS

Our investors should consider the risks set forth in Part I, Item 1A, Risk Factors, of our Annual Report that could affect us and our business.  Although we have tried to discuss key factors, our investors need to be aware that other risks may prove to be important in the future.  New risks may emerge at any time, and we cannot predict such risks or estimate the extent to which

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they may affect our financial performance.  Investors should carefully consider the discussion of risks and the other information included or incorporated by reference in this Quarterly Report, including “Forward-Looking Statements,” which are included in Part I, Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations.

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

Not Applicable.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

Not Applicable.

ITEM 4. MINE SAFETY DISCLOSURES

Not Applicable.

ITEM 5. OTHER INFORMATION

Not Applicable.

ITEM 6. EXHIBITS

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

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

Exhibit No.		Exhibit Description
	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, 2014 and 2013; (iii) Consolidated Statements of Comprehensive Income for the three and six months ended June 30, 2014 and 2013; (iv) Consolidated Balance Sheets at June 30, 2014, and December 31, 2013; (v) Consolidated Statements of Cash Flows for the six

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months ended June 30, 2014 and 2013; (vi) Consolidated Statement of Changes in Equity for the six months ended June 30, 2014; and (vii) Notes to Consolidated Financial Statements.

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

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SIGNATURE

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

	ONEOK, Inc.
	Registrant
Date: August 6, 2014	By:	/s/ Derek S. Reiners
		Derek S. Reiners
		Senior Vice President,
		Chief Financial Officer and Treasurer
		(Principal Financial Officer)

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EX-31.1

Exhibit 31.1

Certification

I, Terry K. Spencer, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date: August 6, 2014

/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 6, 2014

/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, 2014, 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 6, 2014

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, 2014, 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 6, 2014

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

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ONEOK PARTNERS (Tables)

6 Months Ended

Jun. 30, 2014

Related Party Transactions [Abstract]

Ownership interest in ONEOK Partners

Ownership Interestin ONEOK Partners - Our ownership interest in ONEOK Partners is shown in the table below at June 30, 2014:

General partner interest	2.0	%
Limited partner interest (a)	36.5	%
Total ownership interest	38.5	%

(a) - Represents 19.8 million common units and approximately 73.0 million Class B units, which are convertible, at our option, into common units.

ONEOK Partners' Distributions Paid

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2014		2013		2014		2013
	(Thousands, except per unit amounts)
Distribution per unit	$	0.745	$	0.715	$	1.475	$	1.425
General partner distributions	$	5,011	$	4,469	$	9,860	$	8,887
Incentive distributions	71,911		61,576		140,166		122,013
Distributions to general partner	76,922		66,045		150,026		130,900
Limited partner distributions to ONEOK	69,125		66,344		136,862		132,224
Limited partner distributions to noncontrolling interest	104,506		91,039		206,161		181,228
Total distributions paid	$	250,553	$	223,428	$	493,049	$	444,352

ONEOK Partners' Distributions Declared

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2014		2013		2014		2013
	(Thousands, except per unit amounts)
Distribution per unit	$	0.760	$	0.720	$	1.505	$	1.435
General partner distributions	$	5,501	$	4,512	$	10,512	$	8,981
Incentive distributions	80,381		62,633		152,292		124,209
Distributions to general partner	85,882		67,145		162,804		133,190
Limited partner distributions to ONEOK	70,519		66,807		139,646		133,151
Limited partner distributions to noncontrolling interest	118,644		91,676		223,150		182,715
Total distributions declared	$	275,045	$	225,628	$	525,600	$	449,056

ONEOK Partners' transactions

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2014		2013		2014		2013
	(Thousands of dollars)
Revenues	$	—	$	91,340	$	53,526	$	173,974
Expenses
Cost of sales and fuel	$	—	$	8,742	$	10,835	$	18,293
Administrative and general expenses	78,705		61,861		155,951		134,357
Total expenses	$	78,705	$	70,603	$	166,786	$	152,650

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) - Part 1 (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Balance of Accumulated Other Comprehensive Income (Loss) [Abstract]
Unrealized Gains (Losses) on Energy Marketing and Risk Management Assets/Liabilities	$ (43,468)		$ (43,468)		$ (43,168)
Unrealized Holding Gains (Losses) on Investment Securities	744		744		857
Pension and Postretirement Benefit Plan Obligations	(70,403)		(70,403)		(79,676)
Accumulated Other Comprehensive Income (Loss)	(113,127)		(113,127)		(121,987)
Other comprehensive income (loss) attributable to ONEOK [Abstract]
Unrealized Gains (Losses) on Energy Marketing and Risk Management Assets/Liabilities			(300)
Unrealized Gains (Losses) on Energy Marketing and Risk Management Assets/Liabilities			(22,691)
Unrealized Holding Gains (Losses) on Investment Securities			(113)
Unrealized Holding Gains (Losses) on Investment Securities			0
Unrealized Holding Gains (Losses) on Investment Securities	(37)	268	(113)	206
Pension and Postretirement Benefit Plan Obligations			(80)
Pension and Postretirement Benefit Plan Obligations	2,033	(6,882)	5,884	(14,344)
Accumulated Other Comprehensive Income (Loss)			(22,884)
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	(7,511)	3,390	(45,038)	(3,905)
Accumulated Other Comprehensive Income (Loss)	4,131	7,698	28,355	26,399
Accumulated Other Comprehensive Income (Loss)			5,471
Transfer to ONE Gas [Abstract]
Unrealized gains (losses) on energy marketing and risk-management assets/liabilities			0
Unrealized holding gains (losses) on investment securities			0
Pension and postretirement benefit plan obligations			3,389
Accumulated other comprehensive income (loss)			3,389
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Other comprehensive income (loss) attributable to ONEOK [Abstract]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	(1,973)	4,144	(22,391)	(3,299)
Accumulated Defined Benefit Plans Adjustment [Member]
Other comprehensive income (loss) attributable to ONEOK [Abstract]
Pension and Postretirement Benefit Plan Obligations	$ 2,158	$ 11,842	$ 5,964	$ 23,100

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES Part 1 (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
Derivatives, Fair Value [Line Items]
Assets	$ 29,626,000	$ 62,995,000
Liabilities	(29,264,000)	(8,570,000)
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	29,562,000	62,036,000
Liabilities	(29,264,000)	(8,570,000)
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	64,000	959,000
Liabilities	0	0
Interest Rate Contract [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	26,649,000	54,503,000
Liabilities	(19,240,000)	0
Interest Rate Contract [Member] | Designated as Hedging Instrument [Member] | Other Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Notional Amount	400,000,000
Interest Rate Contract [Member] | Designated as Hedging Instrument [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Notional Amount	500,000,000
Cash Flow Hedging [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Commodity cash flow hedge loss to be reclassified within 12 months	3,300,000
Commodity Cash Flow Hedge Gain Loss To Be Reclassified After Next 12 Months Net	400,000
Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivatives, Fair Value [Line Items]
Amount of accumulated other comprehensive income (loss) attributable primarily to settled interest-rate swaps.	(39,900,000)
Interest Rate Cash Flow Hedge Gain (Loss) to be Reclassified During Next 12 Months, Net	(4,700,000)
ONEOK Partners [Member] | Cash Flow Hedging [Member] | Forward Starting Interest Rate Swap [Member]
Derivatives, Fair Value [Line Items]
Notional Amount Of Cash Flow Hedge Instruments Greater Than 12 Months		400,000,000
Financial Derivative Instrument [Member] | Commodity Contract [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	1,451,000	6,469,000
Liabilities	(7,799,000)	(5,107,000)
Physical Derivative Instrument [Member] | Commodity Contract [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	1,462,000	1,064,000
Liabilities	(2,225,000)	(3,463,000)
Physical Derivative Instrument [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	64,000	959,000
Liabilities	$ 0	$ 0
Natural Gas Liquids [Member]
Derivatives, Fair Value [Line Items]
Derivative nonmonetary notional amount	0	0
Natural Gas Pipelines [Member]
Derivatives, Fair Value [Line Items]
Derivative nonmonetary notional amount	0	0

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) - Part 2 (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Total reclassifications for the period attributable to ONEOK	$ 4,131	$ 7,698	$ 28,355	$ 26,399
Unrealized (gains) losses on derivatives [Abstract]
Income tax expense	(1,202)	2,614	(14,219)	(2,081)
Income net of tax	7,511	(3,390)	45,038	3,905
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Unrealized (gains) losses on derivatives [Abstract]
Income net of tax	1,973	(4,144)	22,391	3,299
Accumulated Defined Benefit Plans Adjustment [Member]
Pension and postretirement benefit plan obligations [Abstract]
Amortization of net loss	3,964	5,078	7,927	10,156
Amortization of unrecognized prior service cost	(367)	(113)	(734)	(226)
Amortization of unrecognized net asset at adoption	0	7	0	14
Income before income taxes	3,597	4,972	7,193	9,944
Income tax expense	(1,439)	(1,923)	(2,877)	(3,846)
Income net of tax	2,158	11,842	5,964	23,100
Sales [Member] | Commodity Contract [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Unrealized (gains) losses on derivatives [Abstract]
Commodity sales revenues	5,187	(1,245)	31,606	(3,811)
Interest Expense [Member] | Interest Rate Contract [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Unrealized (gains) losses on derivatives [Abstract]
Interest expense	3,526	3,707	14,847	7,144
Total before tax [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Unrealized (gains) losses on derivatives [Abstract]
Income before income taxes	8,713	2,462	46,453	3,333
Tax benefit [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Unrealized (gains) losses on derivatives [Abstract]
Income tax expense	(1,202)	(661)	(9,098)	(1,055)
Income from continuing operations | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Unrealized (gains) losses on derivatives [Abstract]
Income net of tax	7,511	1,801	37,355	2,278
Income from continuing operations | Accumulated Defined Benefit Plans Adjustment [Member]
Pension and postretirement benefit plan obligations [Abstract]
Income net of tax	2,158	3,049	4,316	6,098
Income from discontinued operations | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Unrealized (gains) losses on derivatives [Abstract]
Income net of tax	0	(5,191)	7,683	1,627
Income from discontinued operations | Accumulated Defined Benefit Plans Adjustment [Member]
Pension and postretirement benefit plan obligations [Abstract]
Income net of tax	0	8,793	1,648	17,002
Net income | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Unrealized (gains) losses on derivatives [Abstract]
Income net of tax	7,511	(3,390)	45,038	3,905
Net income attributable to noncontrolling interest [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Unrealized (gains) losses on derivatives [Abstract]
Net income attributable to noncontrolling interest	5,538	754	22,647	606
Cash Flow Hedging [Member]
Unrealized (gains) losses on derivatives [Abstract]
Income before income taxes	8,713	2,462	46,453	3,333
Cash Flow Hedging [Member] | Sales [Member] | Commodity Contract [Member]
Unrealized (gains) losses on derivatives [Abstract]
Income before income taxes	5,187	(1,245)	31,606	(3,811)
Cash Flow Hedging [Member] | Interest Expense [Member] | Interest Rate Contract [Member]
Unrealized (gains) losses on derivatives [Abstract]
Income before income taxes	$ 3,526	$ 3,707	$ 14,847	$ 7,144

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FAIR VALUE MEASUREMENTS, Fair Value Measurements - Part 2 (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2013	Dec. 31, 2012
Total realized/unrealized gains (losses):
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers, Net	$ 0	$ 0	$ 0	$ 0
Derivative Financial Instruments, Assets Liabilities [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation Calculation [Roll Forward]
Net assets (liabilities)	(1,313)	7,682	(1,313)	7,682	1,972	(782)	(4,855)	(2,423)
Total realized/unrealized gains (losses):
Included in earnings	33	0	(895)	0
Included in other comprehensive income (loss)	(3,318)	12,537	(3,370)	10,105
Purchases, issuances and settlements	$ 0	$ 0	$ 3,734	$ 0

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LONG-TERM DEBT Long term debt table (Tables)

6 Months Ended

Jun. 30, 2014

Debt Instrument [Line Items]

Schedule of Long-term Debt Instruments [Table Text Block]

The following table details information about each of the three series of Senior Notes:

	(In millions)
2.07% notes due February 1, 2019	$	300
3.61% notes due February 1, 2024	300
4.658% notes due February 1, 2044	600
Total	$	1,200

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EMPLOYEE BENEFIT PLANS (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Pension Benefits [Member]
Components of net periodic benefit cost
Service cost	$ 1,823	$ 1,532	$ 3,645	$ 3,064
Interest cost	4,628	3,906	9,256	7,812
Expected return on assets	(4,934)	(4,969)	(9,869)	(9,938)
Amortization of unrecognized prior service cost	48	58	96	116
Amortization of net loss	3,756	4,755	7,511	9,510
Other	120	0	120	0
Net periodic benefit cost	5,441	5,282	10,759	10,564
Postretirement Benefits [Member]
Components of net periodic benefit cost
Service cost	179	118	358	236
Interest cost	611	298	1,222	596
Expected return on assets	(555)	(314)	(1,110)	(628)
Amortization of unrecognized net asset at adoption	0	7	0	14
Amortization of unrecognized prior service cost	(415)	(171)	(830)	(342)
Amortization of net loss	208	323	416	646
Other	(2)	0	(2)	0
Net periodic benefit cost	$ 26	$ 261	$ 54	$ 522

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

6 Months Ended

Jun. 30, 2014

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Accounting

Our accompanying unaudited consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC. These statements have been prepared in accordance with GAAP and reflect all adjustments that, in our opinion, are necessary for a fair presentation of the results for the interim periods presented.  All such adjustments are of a normal recurring nature. The 2013 year-end consolidated balance sheet data was derived from our audited financial statements but does not include all disclosures required by GAAP.  These unaudited consolidated financial statements should be read in conjunction with our audited consolidated financial statements in our Annual Report.

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

Organization and Nature of Operations - We are the sole general partner and own limited partner units of ONEOK Partners (NYSE: OKS), which together represent an aggregate 38.5 percent interest in ONEOK Partners at June 30, 2014. On January 31, 2014, we completed the separation of our natural gas distribution business into a stand-alone publicly traded company called ONE Gas. On March 31, 2014, we completed the accelerated wind down of our energy services business. The results of operations for our former natural gas distribution and energy services businesses have been classified as discontinued operations for all periods presented. Following the ONE Gas separation and wind down of our energy services business, our primary source of income and cash flow is generated from our investment in ONEOK Partners. See Note B for additional information.

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

Segment Reporting, Policy

Change in Reportable Segments - Following the separation of our natural gas distribution business into ONE Gas and wind down of our energy services business, our chief operating decision maker reviews the financial performance of each of the three businesses of ONEOK Partners on a regular basis to assess the performance of, and allocate resources to, ONEOK Partners. As a result, our reportable segments have changed to reflect the three business segments of ONEOK Partners, which include the following:

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

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

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

We have reflected the change in reporting segments for all periods presented. See Note N for additional information.

Income Taxes

Income Taxes - Deferred income taxes are recorded for the difference between the financial statement and income tax basis of assets and liabilities and carryforward items, based on income tax laws and rates existing at the time the temporary differences are expected to reverse. Deferred tax liabilities and deferred income tax expense were reduced by $34.6 million in the first quarter 2014 due to a reduction in our estimate of the effective state income tax rate to reflect a change in the mix of taxable income in the states in which we now operate, resulting from the separation of our former natural gas distribution business and the wind down of our energy services business. We also recorded a valuation allowance of $8.2 million in the first quarter 2014 for state tax credits as it is more likely than not that we will not be able to utilize these credits as a result of the separation of our former natural gas distribution business and the wind down of our energy services business. Together, these adjustments resulted in a net $26.4 million reduction in deferred tax liabilities and deferred income tax expense.

Accounting Standards Update 2014-08 [Member]

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

New Accounting Pronouncement or Change in Accounting Principle, Description

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

Accounting Standards Update 2014-09 [Member]

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

New Accounting Pronouncement or Change in Accounting Principle, Description

In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers,” which outlines the principles an entity must apply to measure and recognize revenue for entities that enter into contracts to provide goods or services to their customers. The core principle is that an entity should recognize revenue at an amount that reflects the consideration to which the entity expects to be entitled in exchange for transferring goods or services to a customer. The amendments also require more extensive disaggregated revenue disclosures in interim and annual financial statements. This update will be effective for interim and annual periods that begin on or after December 15, 2016, with either retrospective application for all periods presented or retrospective application with a cumulative effect adjustment. We will adopt this guidance beginning in the first quarter 2017, and we are evaluating the impact on us.

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES Part 3 (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Derivative Instruments, Gain (Loss) [Line Items]
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)			$ (22,691,000)
Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on Discontinuation of Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net	0	0	4,600,000	0
Gain (Loss) on Discontinuation of Interest Rate Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Tax	0	0	3,100,000	0
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income on derivatives (effective portion)	(8,713,000)	(2,462,000)	(46,453,000)	(3,333,000)
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	(32,515,000)	55,362,000	(88,970,000)	42,382,000
Commodity Contract [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	(6,114,000)	33,145,000	(41,876,000)	13,377,000
Commodity cash flow hedge gain loss to be reclassified within 18 months	2,900,000		2,900,000
Commodity cash flow hedge loss to be reclassified within 12 months	3,300,000		3,300,000
Commodity Cash Flow Hedge Gain Loss To Be Reclassified After Next 12 Months Net	400,000		400,000
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)	(5,187,000)	1,245,000	(31,606,000)	3,811,000
Interest Rate Contract [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	(26,401,000)	22,217,000	(47,094,000)	29,005,000
Amount of accumulated other comprehensive income (loss) attributable primarily to settled interest-rate swaps.	39,900,000		39,900,000
Amount of loss to be recognized in the next 12 months	(4,700,000)		(4,700,000)
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)	$ (3,526,000)	$ (3,707,000)	$ (14,847,000)	$ (7,144,000)

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DISCONTINUED OPERATIONS (Details) (USD $)	3 Months Ended	6 Months Ended			3 Months Ended		6 Months Ended				3 Months Ended	6 Months Ended		3 Months Ended	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013	Mar. 31, 2014 Distribution Regulated Segment [Member]	Jan. 31, 2014 Distribution Regulated Segment [Member]	Jun. 30, 2014 2014 [Member]	Jun. 30, 2014 2015 [Member]	Jun. 30, 2014 2016 [Member]	Jun. 30, 2014 2017 - 2023 [Member]	Jun. 30, 2013 ONEOK Partners [Member] Distribution Regulated Segment [Member]	Jun. 30, 2014 ONEOK Partners [Member] Distribution Regulated Segment [Member]	Jun. 30, 2013 ONEOK Partners [Member] Distribution Regulated Segment [Member]	Jun. 30, 2013 ONEOK Partners [Member] Energy Services [Member]	Jun. 30, 2014 ONEOK Partners [Member] Energy Services [Member]	Jun. 30, 2013 ONEOK Partners [Member] Energy Services [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Costs related to separation	$ 1,300,000	$ 23,000,000
Related Party Transaction, Other Revenues from Transactions with Related Party											14,300,000	7,500,000	28,100,000	77,000,000	46,000,000	145,900,000
Accumulated charges attributable to exit activities	99,100,000	99,100,000		122,000,000
Assets	14,384,538,000	14,384,538,000	15,842,274,000	17,741,481,000		4,300,000,000
Liabilities						2,600,000,000
Distribution of ONE Gas to shareholders		(1,747,424,000)	0		1,700,000,000
Noncash charges		1,739,000	113,780,000
Settlements		(25,700,000)
Accretion		1,100,000
Effect on Future Cash Flows, Amount		$ 60,000,000					$ 15,000,000	$ 23,000,000	$ 11,000,000	$ 11,000,000

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EMPLOYEE BENEFIT PLANS (Tables)

6 Months Ended

Jun. 30, 2014

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						Pension Benefits
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2014			2013			2014			2013
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	1,823		$	1,532		$	3,645		$	3,064
Interest cost	4,628			3,906			9,256			7,812
Expected return on assets	(4,934		)	(4,969		)	(9,869		)	(9,938		)
Amortization of unrecognized prior service cost	48			58			96			116
Amortization of net loss	3,756			4,755			7,511			9,510
Other	120			—			120			—
Net periodic benefit cost	$	5,441		$	5,282		$	10,759		$	10,564

	Postretirement Benefits						Postretirement Benefits
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2014			2013			2014			2013
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	179		$	118		$	358		$	236
Interest cost	611			298			1,222			596
Expected return on assets	(555		)	(314		)	(1,110		)	(628		)
Amortization of unrecognized net asset at adoption	—			7			—			14
Amortization of unrecognized prior service cost	(415		)	(171		)	(830		)	(342		)
Amortization of net loss	208			323			416			646
Other	(2		)	—			(2		)	—
Net periodic benefit cost	$	26		$	261		$	54		$	522

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LONG-TERM DEBT (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014 Note Payable from Public Offering Due 2022 [Member] Rate	Jun. 30, 2014 note payable due 2015 [Member] Rate	Jan. 31, 2014 ONE Gas [Member]	Jan. 31, 2014 ONE Gas [Member] Notes Payable due 2019 [Member]	Jan. 31, 2014 ONE Gas [Member] Notes Payable due 2024 [Member]	Jan. 31, 2014 ONE Gas [Member] Notes Payable due 2044 [Member]
Debt Instrument [Line Items]
Long-term Debt	$ 7,200,000,000	$ 7,800,000,000			$ 1,200,000,000	$ 300,000,000	$ 300,000,000	$ 600,000,000
Related Party Transaction, Amounts of Transaction	1,130,000,000
Extinguishment of Debt, Amount			152,500,000	400,000,000
Debt Instrument, Interest Rate, Stated Percentage			4.25%	5.20%
Early Repayment of Senior Debt			150,000,000	430,100,000
Gains (Losses) on Extinguishment of Debt	$ 24,800,000

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FAIR VALUE MEASUREMENTS, Fair Value - Part 3 (Details) (USD $) In Billions, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 8.0	$ 8.2
Long-term Debt, Book Value	$ 7.2	$ 7.8

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CONSOLIDATED STATEMENT OF CHANGES IN EQUITY (USD $) In Thousands, except Share data	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, 2012	$ 4,232,450						$ 2,102,841
Net income	245,200						131,760
Other comprehensive income (loss)	29,404						24,576
Common stock issued	7,750						0
Common stock dividends - $0.96 per share	(147,982)						0
Noncontrolling Interest, Increase from Subsidiary Equity Issuance	14,308						11,352
Distribution of ONE Gas to shareholders (Note B)	0						0
Distributions to noncontrolling interests	(181,522)						(181,522)
Other	(25,252)						0
Stockholders' equity, ending balance at Jun. 30, 2013	4,174,356						2,089,007
Stockholders' equity, beginning balance at Mar. 31, 2013	4,204,133						2,069,779
Net income	79,495						78,576
Other comprehensive income (loss)	43,285						32,102
Common stock issued	4,919						0
Common stock dividends - $0.96 per share	(74,201)						0
Noncontrolling Interest, Increase from Subsidiary Equity Issuance	(264)						(264)
Distributions to noncontrolling interests	(91,186)						(91,186)
Other	8,175						0
Stockholders' equity, ending balance at Jun. 30, 2013	4,174,356						2,089,007
Stockholders' equity, beginning balance at Dec. 31, 2013	4,845,180	2,458	1,433,600	(121,987)	2,020,815	(997,035)	2,507,329
Common stock issued, beginning balance (in shares) at Dec. 31, 2013		245,811,180
Net income	347,262	0	0	0	155,105	0	192,157
Other comprehensive income (loss)	(28,037)	0	0	5,471	0	0	(33,508)
Common stock issued	13,904	0	(21,220)	0	0	35,124	0
Common stock issued (in shares)		0
Common stock dividends - $0.96 per share	(199,684)	0	0	0	(199,684)	0	0
Noncontrolling Interest, Increase from Subsidiary Equity Issuance	804,395	0	127,125	0	0	0	677,270
Distribution of ONE Gas to shareholders (Note B)	(1,747,424)	0	0	3,389	(1,750,813)	0	0
Distributions to noncontrolling interests	(206,342)	0	0	0	0	0	(206,342)
Other	(35,923)	0	(35,923)	0	0	0	0
Stockholders' equity, ending balance at Jun. 30, 2014	3,793,331	2,458	1,503,582	(113,127)	225,423	(961,911)	3,136,906
Common stock issued, ending balance (in shares) at Jun. 30, 2014		245,811,180
Stockholders' equity, beginning balance at Mar. 31, 2014	3,127,707						2,543,207
Net income	140,751						79,161
Other comprehensive income (loss)	(19,413)						(16,199)
Common stock issued	6,325						0
Common stock dividends - $0.96 per share	(116,409)						0
Noncontrolling Interest, Increase from Subsidiary Equity Issuance	751,553						635,424
Distributions to noncontrolling interests	(104,687)						(104,687)
Other	7,504						0
Stockholders' equity, ending balance at Jun. 30, 2014	$ 3,793,331						$ 3,136,906

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DISCONTINUED OPERATIONS Discontinued Operation Income Statement Disclosures (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues	$ 0	$ 671,590,000	$ 640,653,000	$ 1,777,716,000
Cost of sales and fuel	0	630,962,000	555,541,000	1,484,740,000
Net margin	0	40,628,000	85,112,000	292,976,000
Operating costs	2,811,000	107,861,000	65,369,000	226,152,000
Depreciation and amortization	0	32,972,000	11,354,000	67,910,000
Operating income (loss)	(2,811,000)	(100,205,000)	8,389,000	(1,086,000)
Other income (expense), net	0	(27,000)	(895,000)	620,000
Interest expense, net	0	(15,611,000)	(5,005,000)	(31,562,000)
Income taxes	(5,198,000)	41,561,000	(8,724,000)	12,948,000
Income (loss) from discontinued operations, net	(8,009,000)	(74,282,000)	(6,235,000)	(19,080,000)
Costs related to separation	1,300,000		23,000,000
Distribution Regulated Segment [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues	0	311,606,000	287,249,000	947,537,000
Cost of sales and fuel	0	133,163,000	190,893,000	517,420,000
Net margin	0	178,443,000	96,356,000	430,117,000
Operating costs	1,416,000	104,382,000	60,847,000	217,785,000
Depreciation and amortization	0	32,904,000	11,035,000	67,771,000
Operating income (loss)	(1,416,000)	41,157,000	24,474,000	144,561,000
Other income (expense), net	0	(44,000)	(888,000)	575,000
Interest expense, net	0	(15,163,000)	(4,592,000)	(30,469,000)
Income taxes	(5,745,000)	(10,513,000)	(16,415,000)	(40,801,000)
Income (loss) from discontinued operations, net	(7,161,000)	15,437,000	2,579,000	73,866,000
Energy Services [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues	0	359,984,000	353,404,000	830,179,000
Cost of sales and fuel	0	497,799,000	364,648,000	967,320,000
Net margin	0	(137,815,000)	(11,244,000)	(137,141,000)
Operating costs	1,395,000	3,479,000	4,522,000	8,367,000
Depreciation and amortization	0	68,000	319,000	139,000
Operating income (loss)	(1,395,000)	(141,362,000)	(16,085,000)	(145,647,000)
Other income (expense), net	0	17,000	(7,000)	45,000
Interest expense, net	0	(448,000)	(413,000)	(1,093,000)
Income taxes	547,000	52,074,000	7,691,000	53,749,000
Income (loss) from discontinued operations, net	$ (848,000)	$ (89,719,000)	$ (8,814,000)	$ (92,946,000)

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SEGMENTS (Policies)

6 Months Ended

Jun. 30, 2014

Segment Accounting Policies [Abstract]

Segments Accounting Policies [Text Block]

Accounting Policies - We evaluate performance based principally on each segment’s operating income and equity earnings. The accounting policies of the segments are described in Note A of the Notes to Consolidated Financial Statements in our Annual Report.  Affiliate and intersegment sales are recorded on the same basis as sales to unaffiliated customers.  Net margin is comprised of total revenues less cost of sales and fuel.  Cost of sales and fuel includes commodity purchases, fuel, storage and transportation costs. Revenues from sales and services provided by ONEOK Partners to our former Natural Gas Distribution segment, which were previously eliminated in consolidation, are now reported as third-party revenues.

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ONEOK PARTNERS (Policies)

6 Months Ended

Jun. 30, 2014

Related Party Transactions [Abstract]

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, legal and administrative services by our employees and management, insurance and office space leased in our headquarters building and other field locations.  Where costs are incurred specifically on behalf of an affiliate, the costs are billed directly to the affiliate by us.  In other situations, the costs may be allocated to the affiliates through a variety of methods, depending upon the nature of the expenses and the activities of the affiliates.  Beginning in the second quarter 2014, we allocate substantially all of our general overhead costs to ONEOK Partners as a result of the separation of our natural gas distribution business and the wind down of our energy services business in the first quarter 2014.  For the first quarter 2014 and the three and six months ended June 30, 2013, it is not practicable to determine what these general overhead costs would have been on a stand-alone basis.

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.

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EARNINGS PER SHARE (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Basic EPS from continuing operations [Abstract]
Income from continuing operations attributable to ONEOK available for common stock	$ 69,599	$ 75,201	$ 161,340	$ 132,520
Weighted Average number of share, basic (in shares)	209,403	206,143	209,267	205,811
Per share amount, basic (in dollars per shares)	$ 0.33	$ 0.36	$ 0.77	$ 0.64
Diluted EPS from continuing operations [Abstract]
Effect of dilutive securities	0	0	0	0
Effect of dilutive securities, number of shares (in shares)	1,113	2,731	1,070	3,355
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$ 69,599	$ 75,201	$ 161,340	$ 132,520
Weighted Average number of share, diluted (in shares)	210,516	208,874	210,337	209,166
Per Share amount, diluted (in dollars per share)	$ 0.33	$ 0.36	$ 0.77	$ 0.63
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	0	0	0	0

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DISCONTINUED OPERATIONS Discontinued Operations Balance Sheet Disclosures (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash and cash equivalents		$ 3,748,000
Accounts receivable, net		455,529,000
Gas and natural gas liquids in storage		228,791,000
Other current assets		59,804,000
Net property, plant and equipment		3,065,551,000
Goodwill		157,953,000
Other assets		402,546,000
Total assets		4,373,922,000
Current maturities of long-term debt		6,000
Accounts payable		246,072,000
Other current liabilities		209,610,000
Long-term debt, excluding current maturities		1,318,000
Deferred income taxes		791,700,000
Other deferred credits		255,212,000
Total liabilities		1,503,918,000
Distribution Regulated Segment [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash and cash equivalents		3,535,000
Accounts receivable, net		368,214,000
Gas and natural gas liquids in storage		166,128,000
Other current assets		30,328,000
Net property, plant and equipment		3,065,272,000
Goodwill		157,953,000
Other assets		402,161,000
Total assets		4,193,591,000
Current maturities of long-term debt		6,000
Accounts payable		168,785,000
Other current liabilities		168,964,000
Long-term debt, excluding current maturities		1,318,000
Deferred income taxes		826,921,000
Other deferred credits		184,214,000
Total liabilities		1,350,208,000
Energy Services [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash and cash equivalents		213,000
Accounts receivable, net		87,315,000
Gas and natural gas liquids in storage		62,663,000
Other current assets		29,476,000
Net property, plant and equipment		279,000
Goodwill		0
Other assets		385,000
Total assets		180,331,000
Current maturities of long-term debt		0
Accounts payable		77,287,000
Other current liabilities		40,646,000
Long-term debt, excluding current maturities		0
Deferred income taxes		(35,221,000)
Other deferred credits		70,998,000
Total liabilities		153,710,000
Income taxes receivable	37,700,000
Current tax assets	14,500,000
Deferred tax assets	29,200,000
Current capacity release obligations	46,200,000
Current tax liability	12,200,000
Noncurrent capacity release obligations	$ 52,900,000

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DISCONTINUED OPERATIONS (Tables)

6 Months Ended

Jun. 30, 2014

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 period indicated:

	Six Months Ended
	June 30, 2014
	(Millions of dollars)
Beginning balance	$	122.0
Noncash charges	1.7
Settlements	(25.7		)
Accretion	1.1
Ending balance	$	99.1

Components of Net Income (Loss) [Member]

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

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

Results of Operations of Discontinued Operations - The results of operations for our former natural gas distribution and energy services businesses have been reported as discontinued operations for all periods presented. The tables below provide selected financial information reported in discontinued operations in the Consolidated Statements of Income:

	Three Months Ended											Six Months Ended
	June 30, 2014											June 30, 2014
	Natural Gas Distribution				Energy Services				Total			Natural Gas Distribution				Energy Services			Total
	(Thousands of dollars)
Revenues	$	—			$	—			$	—		$	287,249			$	353,404		$	640,653
Cost of sales and fuel	—				—				—			190,893				364,648			555,541
Net margin	—				—				—			96,356				(11,244		)	85,112
Operating costs	1,416			(a)	1,395			(c)	2,811			60,847			(a)	4,522			65,369
Depreciation and amortization	—				—				—			11,035				319			11,354
Operating income (loss)	(1,416		)		(1,395		)		(2,811		)	24,474				(16,085		)	8,389
Other income (expense), net	—				—				—			(888		)		(7		)	(895		)
Interest expense, net	—				—				—			(4,592		)		(413		)	(5,005		)
Income taxes	(5,745		)	(b)	547				(5,198		)	(16,415		)		7,691			(8,724		)
Income (loss) from discontinued operations, net	$	(7,161	)		$	(848	)		$	(8,009	)	$	2,579			$	(8,814	)	$	(6,235	)

(a) - Includes approximately $1.3 million and $23.0 million for the three and six months ended June 30, 2014, respectively, of costs related to the ONE Gas separation.

(b) - Reflects revision of estimates for income taxes related to the ONE Gas separation.

(c) - Represents primarily accretion expense.

	Three Months Ended									Six Months Ended
	June 30, 2013									June 30, 2013
	Natural Gas Distribution			Energy Services			Total			Natural Gas Distribution			Energy Services			Total
	(Thousands of dollars)
Revenues	$	311,606		$	359,984		$	671,590		$	947,537		$	830,179		$	1,777,716
Cost of sales and fuel	133,163			497,799			630,962			517,420			967,320			1,484,740
Net margin	178,443			(137,815		)	40,628			430,117			(137,141		)	292,976
Operating costs	104,382			3,479			107,861			217,785			8,367			226,152
Depreciation and amortization	32,904			68			32,972			67,771			139			67,910
Operating income (loss)	41,157			(141,362		)	(100,205		)	144,561			(145,647		)	(1,086		)
Other income (expense), net	(44		)	17			(27		)	575			45			620
Interest expense, net	(15,163		)	(448		)	(15,611		)	(30,469		)	(1,093		)	(31,562		)
Income taxes	(10,513		)	52,074			41,561			(40,801		)	53,749			12,948
Income (loss) from discontinued operations, net	$	15,437		$	(89,719	)	$	(74,282	)	$	73,866		$	(92,946	)	$	(19,080	)

Carrying Value of Assets and Liabilities [Member]

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

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

Statement of Financial Position of Discontinued Operations - The following table presents the carrying value of assets and liabilities of our former natural gas distribution and energy services businesses included in assets and liabilities of discontinued operations in the Consolidated Balance Sheets for the period presented:

	December 31, 2013
	Natural Gas Distribution		Energy Services			Total
	(Thousands of dollars)
Assets
Cash and cash equivalents	$	3,535	$	213		$	3,748
Accounts receivable, net	368,214		87,315			455,529
Natural gas and natural gas liquids in storage	166,128		62,663			228,791
Other current assets	30,328		29,476			59,804
Net property, plant and equipment	3,065,272		279			3,065,551
Goodwill	157,953		—			157,953
Other assets	402,161		385			402,546
Total assets	$	4,193,591	$	180,331		$	4,373,922
Liabilities
Current maturities of long-term debt	$	6	$	—		$	6
Accounts payable	168,785		77,287			246,072
Other current liabilities	168,964		40,646			209,610
Long-term debt, excluding current maturities	1,318		—			1,318
Deferred income taxes	826,921		(35,221		)	791,700
Other deferred credits	184,214		70,998			255,212
Total liabilities	$	1,350,208	$	153,710		$	1,503,918

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FAIR VALUE MEASUREMENTS (Tables)

6 Months Ended

Jun. 30, 2014

Fair Value Disclosures [Abstract]

Recurring Fair Value Measurments

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

	June 30, 2014
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Assets
Derivatives
Commodity contracts
Financial contracts	$	945		$	—		$	506		$	1,451		$	(1,451	)	$	—
Physical contracts	—			—			1,526			1,526			(933		)	593
Interest-rate contracts	—			26,649			—			26,649			—			26,649
Total derivatives	945			26,649			2,032			29,626			(2,384		)	27,242
Available-for-sale investment securities (c)	1,419			—			—			1,419			—			1,419
Total assets	$	2,364		$	26,649		$	2,032		$	31,045		$	(2,384	)	$	28,661
Liabilities
Derivatives
Commodity contracts
Financial contracts	$	(3,814	)	$	(2,865	)	$	(1,120	)	$	(7,799	)	$	4,934		$	(2,865	)
Physical contracts	—			—			(2,225		)	(2,225		)	933			(1,292		)
Interest-rate contracts	—			(19,240		)	—			(19,240		)	—			(19,240		)
Total liabilities	$	(3,814	)	$	(22,105	)	$	(3,345	)	$	(29,264	)	$	5,867		$	(23,397	)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis.  ONEOK Partners nets derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and ONEOK Partners.  At June 30, 2014, ONEOK Partners held no cash collateral and posted $3.5 million cash collateral with various counterparties.

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

(c) - Available-for-sale investment securities represent assets of ONEOK.

	December 31, 2013
	Level 1		Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Assets
Derivatives
Commodity contracts
Financial contracts	$	—	$	3,657		$	2,812		$	6,469		$	(1,746	)	$	4,723
Physical contracts	—		—			2,023			2,023			(946		)	1,077
Interest-rate contracts	—		54,503			—			54,503			—			54,503
Total derivatives	—		58,160			4,835			62,995			(2,692		)	60,303
Available-for-sale investment securities (c)	1,569		—			—			1,569			—			1,569
Total assets	$	1,569	$	58,160		$	4,835		$	64,564		$	(2,692	)	$	61,872
Liabilities
Derivatives
Commodity contracts
Financial contracts	$	—	$	(2,953	)	$	(2,154	)	$	(5,107	)	$	1,746		$	(3,361	)
Physical contracts	—		—			(3,463		)	(3,463		)	946			(2,517		)
Total derivative liabilities	$	—	$	(2,953	)	$	(5,617	)	$	(8,570	)	$	2,692		$	(5,878	)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis.  ONEOK Partners nets derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and ONEOK Partners. At December 31, 2013, we and ONEOK Partners had no cash collateral held or posted.

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

(c) - Available-for-sale investment securities represent assets of ONEOK.

Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation

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

	Three Months Ended						Six Months Ended
	June 30,						June 30,
Derivative Assets (Liabilities)	2014			2013			2014			2013
	(Thousands of dollars)
Net assets (liabilities) at beginning of period	$	1,972		$	(4,855	)	$	(782	)	$	(2,423	)
Total realized/unrealized gains (losses):
Included in earnings (a)	33			—			(895		)	—
Included in other comprehensive income (loss)	(3,318		)	12,537			(3,370		)	10,105
Purchases, issuances and settlements	—			—			3,734			—
Net assets (liabilities) at end of period	$	(1,313	)	$	7,682		$	(1,313	)	$	7,682

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

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CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013
Operating Activities
Net income	$ 347,262	$ 245,200
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	150,895	182,076
Charges attributable to exit activities	1,739	113,780
Equity earnings from investments	(59,094)	(52,276)
Distributions received from unconsolidated affiliates	61,200	51,546
Deferred income taxes	57,191	68,468
Share-based compensation expense	17,288	19,018
Pension and postretirement benefit expense, net of contributions	12,729	5,187
Allowance for equity funds used during construction	(12,224)	(14,743)
Loss (gain) on sale of assets	1	(320)
Other	0	(3,658)
Changes in assets and liabilities:
Accounts receivable	17,504	190,633
Natural gas and natural gas liquids in storage	(40,122)	82,018
Accounts payable	(3,426)	(63,954)
Commodity imbalances, net	(15,830)	(57,885)
Settlement of exit activities liabilities	(25,728)	0
Accrued interest	(4,129)	(1,843)
Other assets and liabilities, net	31,051	25,034
Cash provided by operating activities	536,307	788,281
Investing Activities
Capital expenditures (less allowance for equity funds used during construction)	(822,201)	(1,060,333)
Acquisition	(14,000)	0
Contributions to unconsolidated affiliates	(1,063)	(4,558)
Distributions received from unconsolidated affiliates	16,449	17,958
Proceeds from sale of assets	319	3,333
Cash used in investing activities	(820,496)	(1,043,600)
Financing Activities
Borrowing (repayment) of notes payable, net	(564,462)	16,830
Issuance of ONE Gas, Inc. debt, net of discounts	1,199,994	0
ONE Gas, Inc. long-term debt financing costs	(9,663)	0
Repayment of debt	(553,855)	(3,888)
Issuance of common stock	9,166	6,002
Issuance of common units, net of issuance costs	878,765	15,942
Dividends paid	(199,684)	(147,982)
Cash of ONE Gas, Inc. at separation	(60,000)	0
Distributions to noncontrolling interests	(206,342)	(181,522)
Cash provided by (used in) financing activities	493,919	(294,618)
Change in cash and cash equivalents	209,730	(549,937)
Change in cash and cash equivalents included in discontinued operations	3,265	247
Change in cash and cash equivalents included in continuing operations	212,995	(549,690)
Cash and cash equivalents at beginning of period	145,565	579,578
Cash and cash equivalents at end of period	$ 358,560	$ 29,888

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES (Tables)

6 Months Ended

Jun. 30, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair value of derivatives

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

	June 30, 2014					December 31, 2013
	Assets (a)		(Liabilities) (a)			Assets (a)		(Liabilities) (a)
	(Thousands of dollars)
Derivatives designated as hedging instruments
Commodity contracts
Financial contracts	$	1,451	$	(7,799	)	$	6,469	$	(5,107	)
Physical contracts	1,462		(2,225		)	1,064		(3,463		)
Interest-rate contracts	26,649		(19,240		)	54,503		—
Total derivatives designated as hedging instruments	29,562		(29,264		)	62,036		(8,570		)
Derivatives not designated as hedging instruments
Commodity contracts
Physical contracts	64		—			959		—
Total derivatives not designated as hedging instruments	64		—			959		—
Total derivatives	$	29,626	$	(29,264	)	$	62,995	$	(8,570	)

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

Notional amounts of derivative instruments

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

		June 30, 2014					December 31, 2013
	Contract Type	Purchased/ Payor		Sold/ Receiver			Purchased/ Payor		Sold/ Receiver
Derivatives designated as hedging instruments:
Cash flow hedges
Fixed price
- Natural gas (Bcf)	Futures and swaps	—		(38.8		)	—		(48.1		)
- Crude oil and NGLs (MMbbl)	Futures, forwards and swaps	0.1		(3.0		)	—		(4.0		)
Basis
- Natural gas (Bcf)	Futures and swaps	—		(38.8		)	—		(48.1		)
Interest-rate contracts (Millions of dollars)	Forward-starting swaps	$	900.0	$	—		$	400.0	$	—

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

The following table sets forth the effects of cash flow hedges recognized in other comprehensive income (loss) for our continuing operations for the periods indicated:

Derivatives in Cash Flow Hedging Relationships	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2014			2013		2014			2013
	(Thousands of dollars)
Commodity contracts	$	(6,114	)	$	33,145	$	(41,876	)	$	13,377
Interest-rate contracts	(26,401		)	22,217		(47,094		)	29,005
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	$	(32,515	)	$	55,362	$	(88,970	)	$	42,382

Schedule of cash flow hedging instruments effect on income

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

Derivatives in Cash Flow Hedging Relationships	Location of Gain (Loss) Reclassified from  Accumulated Other Comprehensive Income (Loss) into Net Income (Effective Portion)	Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
		(Thousands of dollars)
Commodity contracts	Commodity sales revenues	$	(5,187	)	$	1,245		$	(31,606	)	$	3,811
Interest-rate contracts	Interest expense	(3,526		)	(3,707		)	(14,847		)	(7,144		)
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income on derivatives (effective portion)		$	(8,713	)	$	(2,462	)	$	(46,453	)	$	(3,333	)

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SEGMENTS (Tables)

6 Months Ended

Jun. 30, 2014

Segment Reporting [Abstract]

Segments

The following tables set forth certain selected financial information for our and ONEOK Partners’ operating segments for the periods indicated:

Three Months Ended	Natural Gas Gathering and Processing			Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Other and Eliminations			Total
June 30, 2014
	(Thousands of dollars)
Sales to unaffiliated customers	$	374,112		$	2,612,336	$	79,287	$	1,147		$	3,066,882
Intersegment revenues	349,253			52,974		2,698		(404,925		)	—
Total revenues	$	723,365		$	2,665,310	$	81,985	$	(403,778	)	$	3,066,882
Net margin	$	154,970		$	266,145	$	75,471	$	(1,106	)	$	495,480
Operating costs	59,386			76,081		27,287		9,268			172,022
Depreciation and amortization	29,443			31,109		10,895		680			72,127
Gain (loss) on sale of assets	(28		)	11		—		1			(16		)
Operating income	$	66,113		$	158,966	$	37,289	$	(11,053	)	$	251,315
Equity earnings from investments	$	5,099		$	4,459	$	15,877	$	—		$	25,435
Capital expenditures	$	168,208		$	210,676	$	8,710	$	5,082		$	392,676

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $153.3 million, of which $135.3 million related to sales within the segment, net margin of $84.4 million and operating income of $34.5 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $68.3 million, net margin of $59.5 million and operating income of $26.1 million.

Three Months Ended	Natural Gas Gathering and Processing		Natural Gas Liquids (a)			Natural Gas Pipelines (b)		Other and Eliminations (c)			Total
June 30, 2013
	(Thousands of dollars)
Sales to unaffiliated customers	$	166,709	$	2,461,119		$	49,011	$	805		$	2,677,644
Sales to affiliated customers	66,578		—			24,762		—			91,340
Intersegment revenues	248,972		29,996			1,269		(280,237		)	—
Total revenues	$	482,259	$	2,491,115		$	75,042	$	(279,432	)	$	2,768,984
Net margin	$	125,269	$	219,225		$	67,695	$	569		$	412,758
Operating costs	44,975		54,264			24,985		1,541			125,765
Depreciation and amortization	25,106		22,302			10,818		657			58,883
Gain (loss) on sale of assets	285		(6		)	—		—			279
Operating income	$	55,473	$	142,653		$	31,892	$	(1,629	)	$	228,389
Equity earnings from investments	$	5,229	$	5,912		$	15,280	$	—		$	26,421
Capital expenditures	$	206,019	$	269,339		$	6,007	$	77,903		$	559,268

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $121.6 million, of which $106.5 million related to sales within the segment, net margin of $76.8 million and operating income of $44.3 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $56.1 million, net margin of $52.0 million and operating income of $20.6 million.

(c) - The Other segment includes capital expenditures of discontinued operations of $68.8 million.

Six Months Ended	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)			Other and Eliminations (c)			Total
June 30, 2014
	(Thousands of dollars)
Sales to unaffiliated customers	$	721,128		$	5,282,991		$	170,393		$	2,140		$	6,176,652
Sales to affiliated customers	41,214			—			12,312			—			53,526
Intersegment revenues	723,148			94,131			4,073			(821,352		)	—
Total revenues	$	1,485,490		$	5,377,122		$	186,778		$	(819,212	)	$	6,230,178
Net margin	$	308,524		$	535,123		$	168,960		$	(6,500	)	$	1,006,107
Operating costs	124,210			141,183			54,749			991			321,133
Depreciation and amortization	58,285			58,187			21,710			1,359			139,541
Gain (loss) on sale of assets	(47		)	(37		)	(83		)	166			(1		)
Operating income	$	125,982		$	335,716		$	92,418		$	(8,684	)	$	545,432
Equity earnings from investments	$	10,585		$	9,223		$	39,286		$	—		$	59,094
Investments in unconsolidated affiliates	$	329,726		$	485,960		$	396,722		$	—		$	1,212,408
Total assets	$	4,276,593		$	7,363,417		$	1,852,901		$	891,627		$	14,384,538
Noncontrolling interests in consolidated subsidiaries	$	4,493		$	—		$	—		$	3,132,413		$	3,136,906
Capital expenditures	$	291,099		$	483,739		$	15,337		$	32,026		$	822,201

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $289.1 million, of which $246.9 million related to sales within the segment, net margin of $169.1 million and operating income of $79.6 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $149.6 million, net margin of $128.1 million and operating income of $61.2 million.

(c) - The Other segment includes assets and capital expenditures of discontinued operations of $87.5 million and $23.9 million, respectively.

Six Months Ended	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Other and Eliminations (c)			Total
June 30, 2013
	(Thousands of dollars)
Sales to unaffiliated customers	$	303,954	$	4,699,362	$	108,336	$	1,313		$	5,112,965
Sales to affiliated customers	122,236		—		51,738		—			173,974
Intersegment revenues	493,583		56,421		997		(551,001		)	—
Total revenues	$	919,773	$	4,755,783	$	161,071	$	(549,688	)	$	5,286,939
Net margin	$	234,554	$	405,845	$	141,767	$	1,699		$	783,865
Operating costs	96,663		114,066		52,151		4,020			266,900
Depreciation and amortization	49,010		42,040		21,854		1,262			114,166
Gain (loss) on sale of assets	313		3		4		—			320
Operating income	$	89,194	$	249,742	$	67,766	$	(3,583	)	$	403,119
Equity earnings from investments	$	11,560	$	9,047	$	31,669	$	—		$	52,276
Investments in unconsolidated affiliates	$	332,458	$	494,964	$	381,365	$	—		$	1,208,787
Total assets	$	3,346,874	$	6,008,574	$	1,792,343	$	4,694,483		$	15,842,274
Noncontrolling interests in consolidated subsidiaries	$	4,631	$	—	$	—	$	2,084,376		$	2,089,007
Capital expenditures	$	369,967	$	543,504	$	11,349	$	135,513		$	1,060,333

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $229.8 million, of which $191.1 million related to sales within the segment, net margin of $138.3 million and operating income of $75.6 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $124.5 million, net margin of $109.7 million and operating income of $44.4 million.

(c) - The Other segment includes assets and capital expenditures of discontinued operations of $4.0 billion and $122.6 million, respectively.

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EQUITY (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended			6 Months Ended
	Jun. 30, 2014	Mar. 31, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Common Stock, Dividends, Per Share, Cash Paid	$ 0.56	$ 0.40	$ 0.36	$ 0.96	$ 0.72
Stockholders' equity, beginning balance	$ 3,127,707	$ 4,845,180	$ 4,204,133	$ 4,845,180	$ 4,232,450
Net income	140,751		79,495	347,262	245,200
Other comprehensive income (loss)	(19,413)		43,285	(28,037)	29,404
Common stock issued	6,325		4,919	13,904	7,750
Common stock dividends	(116,409)		(74,201)	(199,684)	(147,982)
Issuance of common units of ONEOK Partners	751,553		(264)	804,395	14,308
Distribution of ONE Gas to shareholders				(1,747,424)	0
Distributions to noncontrolling interests	(104,687)		(91,186)	(206,342)	(181,522)
Other	7,504		8,175	(35,923)	(25,252)
Stockholders' equity, ending balance	3,793,331	3,127,707	4,174,356	3,793,331	4,174,356
Dividends declared per share of common stock	$ 0.575
Dividends Payable, Date of Record	Aug. 04, 2014
Dividends Payable, Date to be Paid	Aug. 14, 2014
ONEOK Shareholders' Equity [Member]
Stockholders' equity, beginning balance	584,500	2,337,851	2,134,354	2,337,851	2,129,609
Net income	61,590		919	155,105	113,440
Other comprehensive income (loss)	(3,214)		11,183	5,471	4,828
Common stock issued	6,325		4,919	13,904	7,750
Common stock dividends	(116,409)		(74,201)	(199,684)	(147,982)
Issuance of common units of ONEOK Partners	116,129		0	127,125	2,956
Distribution of ONE Gas to shareholders				(1,747,424)	0
Distributions to noncontrolling interests	0		0	0	0
Other	7,504		8,175	(35,923)	(25,252)
Stockholders' equity, ending balance	656,425		2,085,349	656,425	2,085,349
Noncontrolling Interests in Consolidated Subsidiaries [Member]
Stockholders' equity, beginning balance	2,543,207	2,507,329	2,069,779	2,507,329	2,102,841
Net income	79,161		78,576	192,157	131,760
Other comprehensive income (loss)	(16,199)		32,102	(33,508)	24,576
Common stock issued	0		0	0	0
Common stock dividends	0		0	0	0
Issuance of common units of ONEOK Partners	635,424		(264)	677,270	11,352
Distribution of ONE Gas to shareholders				0	0
Distributions to noncontrolling interests	(104,687)		(91,186)	(206,342)	(181,522)
Other	0		0	0	0
Stockholders' equity, ending balance	$ 3,136,906		$ 2,089,007	$ 3,136,906	$ 2,089,007

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CONSOLIDATED STATEMENTS OF INCOME (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Revenues [Abstract]
Commodity sales	$ 2,715,109	$ 2,447,411	$ 5,521,838	$ 4,646,205
Services	351,773	321,573	708,340	640,734
Total revenues	3,066,882	2,768,984	6,230,178	5,286,939
Cost of sales and fuel	2,571,402	2,356,226	5,224,071	4,503,074
Net margin	495,480	412,758	1,006,107	783,865
Operating expenses
Operations and maintenance	153,323	108,906	280,049	230,311
Depreciation and amortization	72,127	58,883	139,541	114,166
General taxes	18,699	16,859	41,084	36,589
Total operating expenses	244,149	184,648	460,674	381,066
Gain (loss) on sale of assets	(16)	279	(1)	320
Operating income	251,315	228,389	545,432	403,119
Equity earnings from investments (Note K)	25,435	26,421	59,094	52,276
Allowance for equity funds used during construction	1,253	5,656	12,224	14,743
Other income	3,213	2,734	4,622	8,356
Other expense	(1,392)	(380)	(26,926)	(1,881)
Interest expense (net of capitalized interest of $11,375, $11,359, $27,143 and $23,964, respectively)	(88,751)	(66,120)	(183,652)	(130,606)
Income before income taxes	191,073	196,700	410,794	346,007
Income taxes	(42,313)	(42,923)	(57,297)	(81,727)
Income from continuing operations	148,760	153,777	353,497	264,280
Income (loss) from discontinued operations, net of tax (Note B)	(8,009)	(74,282)	(6,235)	(19,080)
Net income	140,751	79,495	347,262	245,200
Less: Net income attributable to noncontrolling interests	79,161	78,576	192,157	131,760
Net income attributable to ONEOK	61,590	919	155,105	113,440
Amounts attributable to ONEOK:
Income from continuing operations	69,599	75,201	161,340	132,520
Income (loss) from discontinued operations	(8,009)	(74,282)	(6,235)	(19,080)
Net income attributable to ONEOK	$ 61,590	$ 919	$ 155,105	$ 113,440
Basic earnings per share:
Income from continuing operations (Note I)	$ 0.33	$ 0.36	$ 0.77	$ 0.64
Income (loss) from discontinued operations	$ (0.04)	$ (0.36)	$ (0.03)	$ (0.09)
Net income	$ 0.29	$ 0.00	$ 0.74	$ 0.55
Diluted earnings per share:
Income from continuing operations (Note I)	$ 0.33	$ 0.36	$ 0.77	$ 0.63
Income (loss) from discontinued operations	$ (0.04)	$ (0.36)	$ (0.03)	$ (0.09)
Net income	$ 0.29	$ 0.00	$ 0.74	$ 0.54
Average shares (thousands)
Basic	209,403	206,143	209,267	205,811
Diluted	210,516	208,874	210,337	209,166
Dividends declared per share of common stock	$ 0.56	$ 0.36	$ 0.96	$ 0.72

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FAIR VALUE MEASUREMENTS - Part 1 (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Derivatives
Cash collateral held	$ 0		$ 0		$ 0
Cash collateral posted	3,500		3,500		0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers, Net	0	0	0	0
Fair Value, Measurements, Recurring [Member]
Derivatives
Commodity contracts - financial	0		0		4,723
Commodity contracts - physical	593		593		1,077
Interest-rate contracts	26,649		26,649		54,503
Total derivatives assets	27,242		27,242		60,303
Other
Available-for-sale investment securities	1,419		1,419		1,569
Total assets	28,661		28,661		61,872
Derivatives
Commodity contracts - financial	(2,865)		(2,865)		(3,361)
Commodity contracts - physical	(1,292)		(1,292)		(2,517)
Interest Rate Derivative Liabilities, at Fair Value	(19,240)		(19,240)
Total liabilities	(23,397)		(23,397)		(5,878)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Derivatives
Commodity contracts - financial	945		945		0
Commodity contracts - physical	0		0		0
Interest-rate contracts	0		0		0
Total derivatives assets	945		945		0
Other
Available-for-sale investment securities	1,419		1,419		1,569
Total assets	2,364		2,364		1,569
Derivatives
Commodity contracts - financial	(3,814)		(3,814)		0
Commodity contracts - physical	0		0		0
Interest Rate Derivative Liabilities, at Fair Value	0		0
Total liabilities	(3,814)		(3,814)		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Derivatives
Commodity contracts - financial	0		0		3,657
Commodity contracts - physical	0		0		0
Interest-rate contracts	26,649		26,649		54,503
Total derivatives assets	26,649		26,649		58,160
Other
Available-for-sale investment securities	0		0		0
Total assets	26,649		26,649		58,160
Derivatives
Commodity contracts - financial	(2,865)		(2,865)		(2,953)
Commodity contracts - physical	0		0		0
Interest Rate Derivative Liabilities, at Fair Value	(19,240)		(19,240)
Total liabilities	(22,105)		(22,105)		(2,953)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Derivatives
Commodity contracts - financial	506		506		2,812
Commodity contracts - physical	1,526		1,526		2,023
Interest-rate contracts	0		0		0
Total derivatives assets	2,032		2,032		4,835
Other
Available-for-sale investment securities	0		0		0
Total assets	2,032		2,032		4,835
Derivatives
Commodity contracts - financial	(1,120)		(1,120)		(2,154)
Commodity contracts - physical	(2,225)		(2,225)		(3,463)
Interest Rate Derivative Liabilities, at Fair Value	0		0
Total liabilities	(3,345)		(3,345)		(5,617)
Fair Value, Measurements, Recurring [Member] | Total Gross, Fair Value Disclosure [Member]
Derivatives
Commodity contracts - financial	1,451		1,451		6,469
Commodity contracts - physical	1,526		1,526		2,023
Interest-rate contracts	26,649		26,649		54,503
Total derivatives assets	29,626		29,626		62,995
Other
Available-for-sale investment securities	1,419		1,419		1,569
Total assets	31,045		31,045		64,564
Derivatives
Commodity contracts - financial	(7,799)		(7,799)		(5,107)
Commodity contracts - physical	(2,225)		(2,225)		(3,463)
Interest Rate Derivative Liabilities, at Fair Value	(19,240)		(19,240)
Total liabilities	(29,264)		(29,264)		(8,570)
Fair Value, Measurements, Recurring [Member] | Netting and Collateral [Member]
Derivatives
Commodity contracts - financial	(1,451)		(1,451)		(1,746)
Commodity contracts - physical	(933)		(933)		(946)
Interest-rate contracts	0		0		0
Total derivatives assets	(2,384)		(2,384)		(2,692)
Other
Available-for-sale investment securities	0		0		0
Total assets	(2,384)		(2,384)		(2,692)
Derivatives
Commodity contracts - financial	4,934		4,934		1,746
Commodity contracts - physical	933		933		946
Interest Rate Derivative Liabilities, at Fair Value	0		0
Total liabilities	$ 5,867		$ 5,867		$ 2,692

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CONSOLIDATED BALANCE SHEETS (USD $) In Thousands, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
Current assets
Cash and cash equivalents	$ 358,560	$ 145,565
Accounts receivable, net	1,097,008	1,109,510
Natural gas and natural gas liquids in storage	335,116	188,286
Commodity imbalances	93,070	80,481
Other current assets	118,545	133,010
Assets of discontinued operations (Note B)	57,356	747,872
Total current assets	2,059,655	2,404,724
Property, plant and equipment
Property, plant and equipment	11,737,291	10,970,256
Accumulated depreciation and amortization	1,866,627	1,738,302
Net property, plant and equipment	9,870,664	9,231,954
Investments and other assets
Investments in unconsolidated affiliates (Note K)	1,212,408	1,229,838
Goodwill and intangible assets	1,018,679	1,024,562
Other assets	193,032	224,353
Assets of discontinued operations (Note B)	30,100	3,626,050
Total investments and other assets	2,454,219	6,104,803
Total assets	14,384,538	17,741,481
Current liabilities
Current maturities of long-term debt	10,650	10,650
Notes payable (Note E)	0	564,462
Accounts payable	1,271,539	1,273,102
Commodity imbalances	207,456	213,577
Accrued interest	105,099	109,099
Other current liabilities	190,289	103,752
Liabilities of discontinued operations (Note B)	66,138	455,688
Total current liabilities	1,851,171	2,730,330
Long-term debt, excluding current maturities (Note F)	7,196,988	7,753,657
Deferred credits and other liabilities
Deferred income taxes	1,253,099	1,146,562
Other deferred credits	237,468	217,522
Liabilities of discontinued operations (Note B)	52,481	1,048,230
Total deferred credits and other liabilities	1,543,048	2,412,314
Commitments and contingencies (Note M)
ONEOK shareholders' equity:
Common stock, $0.01 par value: authorized 600,000,000 shares; issued 245,811,180 shares and outstanding 207,999,517 shares at June 30, 2014; issued 245,811,180 shares and outstanding 206,618,877 shares at December 31, 2013	2,458	2,458
Paid-in capital	1,503,582	1,433,600
Accumulated other comprehensive loss (Note H)	(113,127)	(121,987)
Retained earnings	225,423	2,020,815
Treasury stock, at cost: 37,811,663 shares at June 30, 2014, and 39,192,203 shares at December 31, 2013	(961,911)	(997,035)
Total ONEOK shareholders' equity	656,425	2,337,851
Noncontrolling interests in consolidated subsidiaries	3,136,906	2,507,329
Total equity	3,793,331	4,845,180
Total liabilities and equity	$ 14,384,538	$ 17,741,481

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ONEOK PARTNERS (Details) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Related Party Transaction [Line Items]
Partners' Capital Account, Units, Sold in Public Offering	13,900,000
Public offering price of common units	$ 52.94
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest			38.50%		41.20%
Partners' Capital Account, Contributions	$ 15,000,000
Noncontrolling Interest, Increase from Subsidiary Equity Issuance	751,553,000	(264,000)	804,395,000	14,308,000
Aggregate amount of common units available for issuance and sale under Equity Distribution Agreement			300,000,000
Common units	19,800,000		19,800,000
Class B units	73,000,000		73,000,000
Expenses
Partners capital account units sold under equity distribution agreement		0	3,000,000	300,000
ONEOK [Member]
Related Party Transaction [Line Items]
Revenue	0	91,340,000	53,526,000	173,974,000
Expenses
Cost of sales and fuel	0	8,742,000	10,835,000	18,293,000
Administrative and general expenses	78,705,000	61,861,000	155,951,000	134,357,000
Total expenses	78,705,000	70,603,000	166,786,000	152,650,000
General Partner [Member]
Related Party Transaction [Line Items]
Ownership interest (in hundreths)	2.00%		2.00%
Limited Partner [Member]
Related Party Transaction [Line Items]
Ownership interest (in hundreths)	36.50%		36.50%
Distribution Paid [Member]
Related Party Transaction [Line Items]
Distribution per unit	$ 0.745	$ 0.715	$ 1.475	$ 1.425
Distributions to general partner	76,922,000	66,045,000	150,026,000	130,900,000
Total distributions	250,553,000	223,428,000	493,049,000	444,352,000
Distribution Paid [Member] | ONEOK [Member]
Related Party Transaction [Line Items]
Limited partner distributions to ONEOK	69,125,000	66,344,000	136,862,000	132,224,000
Distribution Paid [Member] | General Partner [Member]
Related Party Transaction [Line Items]
General partner distributions	5,011,000	4,469,000	9,860,000	8,887,000
Incentive distributions	71,911,000	61,576,000	140,166,000	122,013,000
Distribution Paid [Member] | Limited Partner [Member]
Related Party Transaction [Line Items]
Limited partner distributions to noncontrolling interest	104,506,000	91,039,000	206,161,000	181,228,000
Distribution Declared [Member]
Related Party Transaction [Line Items]
Distribution Made to Limited Partner, Distribution Date	Aug. 14, 2014
Distribution per unit	$ 0.760	$ 0.720	$ 1.505	$ 1.435
Distribution Made To Member Or Limited Parter Annualized Quarterly Distribution	3.04
Distribution Made To Member Or Limited Parter Change From Prior Quarter	0.015
Distributions to general partner	85,882,000	67,145,000	162,804,000	133,190,000
Total distributions	275,045,000	225,628,000	525,600,000	449,056,000
Expenses
Distribution Made to Limited Partner, Date of Record	Aug. 04, 2014
Distribution Declared [Member] | ONEOK [Member]
Related Party Transaction [Line Items]
Limited partner distributions to ONEOK	70,519,000	66,807,000	139,646,000	133,151,000
Distribution Declared [Member] | General Partner [Member]
Related Party Transaction [Line Items]
General partner distributions	5,501,000	4,512,000	10,512,000	8,981,000
Incentive distributions	80,381,000	62,633,000	152,292,000	124,209,000
Distribution Declared [Member] | Limited Partner [Member]
Related Party Transaction [Line Items]
Limited partner distributions to noncontrolling interest	118,644,000	91,676,000	223,150,000	182,715,000
Issued Under Public Offering [Member]
Related Party Transaction [Line Items]
Proceeds from Sale of Interest in Partnership Unit	714,500,000
Paid-in Capital [Member]
Related Party Transaction [Line Items]
Noncontrolling Interest, Increase from Subsidiary Equity Issuance			127,125,000
Issued Under Equity Distribution Agreement [Member]
Related Party Transaction [Line Items]
Proceeds from Sale of Interest in Partnership Unit			164,100,000	16,300,000
Distribution Regulated Segment [Member] | ONEOK Partners [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party		14,300,000	7,500,000	28,100,000
Energy Services [Member] | ONEOK Partners [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party		$ 77,000,000	$ 46,000,000	$ 145,900,000

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Tables)

6 Months Ended

Jun. 30, 2014

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

Accumulated other comprehensive income (loss)

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

	Unrealized Gains (Losses) on Energy Marketing and Risk-Management Assets/Liabilities (a)			Unrealized Holding Gains (Losses) on Investment Securities (a)			Pension and Postretirement Benefit Plan Obligations (a)			Accumulated Other Comprehensive Income (Loss) (a)
	(Thousands of dollars)
January 1, 2014	$	(43,168	)	$	857		$	(79,676	)	$	(121,987	)
Other comprehensive income (loss) before reclassifications	(22,691		)	(113		)	(80		)	(22,884		)
Amounts reclassified from accumulated other comprehensive income (loss)	22,391			—			5,964			28,355
Other comprehensive income (loss) attributable to ONEOK	(300		)	(113		)	5,884			5,471
Transfer to ONE Gas	—			—			3,389			3,389
June 30, 2014	$	(43,468	)	$	744		$	(70,403	)	$	(113,127	)

(a) All amounts are presented net of tax.

Statement [Line Items]

Disclosure of Reclassification Amount [Text Block]

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

Details about Accumulated Other Comprehensive Income (Loss) Components	Three Months Ended						Six Months Ended						Affected Line Item in the Consolidated Statements of Income
	June 30,						June 30,
	2014			2013			2014			2013
	(Thousands of dollars)
Unrealized (gains) losses on energy marketing and risk-management assets/liabilities
Commodity contracts	$	5,187		$	(1,245	)	$	31,606		$	(3,811	)	Commodity sales revenues
Interest-rate contracts	3,526			3,707			14,847			7,144			Interest expense
	8,713			2,462			46,453			3,333			Income before income taxes
	(1,202		)	(661		)	(9,098		)	(1,055		)	Income tax expense
	7,511			1,801			37,355			2,278			Income from continuing operations
	—			(5,191		)	7,683			1,627			Income from discontinued operations
	7,511			(3,390		)	45,038			3,905			Net income
Noncontrolling interest	5,538			754			22,647			606			Less: Net income attributable to noncontrolling interest
	$	1,973		$	(4,144	)	$	22,391		$	3,299		Net income attributable to ONEOK
Pension and postretirement benefit plan obligations (a)
Amortization of net loss	$	3,964		$	5,078		$	7,927		$	10,156
Amortization of unrecognized prior service cost	(367		)	(113		)	(734		)	(226		)
Amortization of unrecognized net asset at adoption	—			7			—			14
	3,597			4,972			7,193			9,944			Income before income taxes
	(1,439		)	(1,923		)	(2,877		)	(3,846		)	Income tax expense
	2,158			3,049			4,316			6,098			Income from continuing operations
	—			8,793			1,648			17,002			Income from discontinued operations
	$	2,158		$	11,842		$	5,964		$	23,100		Net income attributable to ONEOK
Total reclassifications for the period attributable to ONEOK	$	4,131		$	7,698		$	28,355		$	26,399		Net income attributable to ONEOK

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

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ONEOK PARTNERS

6 Months Ended

Jun. 30, 2014

Related Party Transactions [Abstract]

ONEOK PARTNERS

L. ONEOK PARTNERS

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

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 $300 million. The program allows ONEOK Partners to offer and sell its common units at prices ONEOK Partners 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.

During the six months ended June 30, 2014, ONEOK Partners sold approximately 3.0 million common units through this program. The net proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, were approximately $164.1 million, which were used for general partnership purposes. During the three months ended March 31, 2013, ONEOK Partners sold 300,000 common units through this program that resulted in net proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, of approximately $16.3 million and used the proceeds for general partnership purposes. There were no common units sold through this program in the second quarter 2013.

As a result of these transactions, our aggregate ownership interest in ONEOK Partners decreased to 38.5 percent at June 30, 2014, from 41.2 percent at December 31, 2013.

We account for the difference between the carrying amount of our investment in ONEOK Partners and the underlying book value arising from issuance of common units by ONEOK Partners as an equity transaction.  If ONEOK Partners issues common units at a price different than our carrying value per unit, we account for the premium or deficiency as an adjustment to paid-in capital. As a result of ONEOK Partners’ issuance of common units, we recognized an increase to paid-in capital of approximately $127.1 million, net of taxes, for the six months ended June 30, 2014.

Ownership Interestin ONEOK Partners - Our ownership interest in ONEOK Partners is shown in the table below at June 30, 2014:

General partner interest	2.0	%
Limited partner interest (a)	36.5	%
Total ownership interest	38.5	%

(a) - Represents 19.8 million common units and approximately 73.0 million Class B units, which are convertible, at our option, into common units.

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 2014, a cash distribution of $0.76 per unit ($3.04 per unit on an annualized basis), an increase of 1.5 cents from the previous quarter, was declared for the second quarter 2014 and will be paid on August 14, 2014, to unitholders of record at the close of business on August 4, 2014.

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2014		2013		2014		2013
	(Thousands, except per unit amounts)
Distribution per unit	$	0.745	$	0.715	$	1.475	$	1.425
General partner distributions	$	5,011	$	4,469	$	9,860	$	8,887
Incentive distributions	71,911		61,576		140,166		122,013
Distributions to general partner	76,922		66,045		150,026		130,900
Limited partner distributions to ONEOK	69,125		66,344		136,862		132,224
Limited partner distributions to noncontrolling interest	104,506		91,039		206,161		181,228
Total distributions paid	$	250,553	$	223,428	$	493,049	$	444,352

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2014		2013		2014		2013
	(Thousands, except per unit amounts)
Distribution per unit	$	0.760	$	0.720	$	1.505	$	1.435
General partner distributions	$	5,501	$	4,512	$	10,512	$	8,981
Incentive distributions	80,381		62,633		152,292		124,209
Distributions to general partner	85,882		67,145		162,804		133,190
Limited partner distributions to ONEOK	70,519		66,807		139,646		133,151
Limited partner distributions to noncontrolling interest	118,644		91,676		223,150		182,715
Total distributions declared	$	275,045	$	225,628	$	525,600	$	449,056

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

Affiliate Transactions - We have certain transactions with ONEOK Partners and its subsidiaries.

Prior to the wind down of our energy services business, ONEOK Partners sold natural gas from its natural gas gathering and processing operations to our energy services business.  In addition, a portion of ONEOK Partners’ revenues from its natural gas pipelines business were from our former energy services and natural gas distribution businesses, which contracted with ONEOK Partners for natural gas transportation and storage services. ONEOK Partners also purchased natural gas from our former energy services business for its natural gas liquids and its natural gas gathering and processing operations.

As a result of the wind down discussed in Note B, our energy services business no longer executes affiliate transactions with ONEOK Partners. Beginning in the second quarter, ONEOK Partners enters into all commodity derivative financial contracts with unaffiliated third parties. ONEOK Partners continues to provide natural gas transportation and storage services to ONE Gas after the separation.

We provide a variety of services to our affiliates, including cash management and financial services, legal and administrative services by our employees and management, insurance and office space leased in our headquarters building and other field locations.  Where costs are incurred specifically on behalf of an affiliate, the costs are billed directly to the affiliate by us.  In other situations, the costs may be allocated to the affiliates through a variety of methods, depending upon the nature of the expenses and the activities of the affiliates.  Beginning in the second quarter 2014, we allocate substantially all of our general overhead costs to ONEOK Partners as a result of the separation of our natural gas distribution business and the wind down of our energy services business in the first quarter 2014.  For the first quarter 2014 and the three and six months ended June 30, 2013, it is not practicable to determine what these general overhead costs would have been on a stand-alone basis.

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2014		2013		2014		2013
	(Thousands of dollars)
Revenues	$	—	$	91,340	$	53,526	$	173,974
Expenses
Cost of sales and fuel	$	—	$	8,742	$	10,835	$	18,293
Administrative and general expenses	78,705		61,861		155,951		134,357
Total expenses	$	78,705	$	70,603	$	166,786	$	152,650

Prior to the ONE Gas separation, natural gas sales and transportation and storage services provided to our former natural gas distribution business by ONEOK Partners were $14.3 million for the three months ended June 30, 2013, and $7.5 million and $28.1 million for the six months ended June 30,2014 and 2013, respectively. Prior to February 1, 2014, these revenues and related costs were eliminated in consolidation. Beginning February 1, 2014, these revenues represent third-party transactions with ONE Gas and are not eliminated in consolidation, as such sales and services have continued subsequent to the separation and are expected to continue in future periods. Prior to the completion of the energy services wind down, natural gas and natural gas liquids sales and transportation and storage services provided to our energy services business by ONEOK Partners were $77.0 million for the three months ended June 30, 2013, and $46.0 million and $145.9 million for the six months ended June 30,2014 and 2013, respectively. While these transactions were eliminated in consolidation in previous periods, they are now reflected as affiliate transactions and not eliminated in consolidation as these transactions have continued with third parties.

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EARNINGS PER SHARE (Tables)

6 Months Ended

Jun. 30, 2014

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, 2014
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	69,599	209,403	$	0.33
Diluted EPS from continuing operations
Effect of dilutive securities	—		1,113
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	69,599	210,516	$	0.33

	Three Months Ended June 30, 2013
	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	$	75,201	206,143	$	0.36
Diluted EPS from continuing operations
Effect of dilutive securities	—		2,731
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	75,201	208,874	$	0.36

	Six Months Ended June 30, 2014
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	161,340	209,267	$	0.77
Diluted EPS from continuing operations
Effect of dilutive securities	—		1,070
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	161,340	210,337	$	0.77

	Six Months Ended June 30, 2013
	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	$	132,520	205,811	$	0.64
Diluted EPS from continuing operations
Effect of dilutive securities	—		3,355
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	132,520	209,166	$	0.63

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SEGMENTS

6 Months Ended

Jun. 30, 2014

Segment Reporting [Abstract]

SEGMENTS

N. SEGMENTS

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

• the Natural Gas Gathering and Processing segment gathers 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.

Change in Reportable Segments - On January 31, 2014, we completed the separation of our former natural gas distribution business into a stand-alone publicly traded company called ONE Gas. ONE Gas consists of our former Natural Gas Distribution segment. On March 31, 2014, we completed the accelerated wind down of our Energy Services segment. These former segments are included in discontinued operations for all periods presented. See Notes A and B for additional information.

Following the separation of our natural gas distribution business into ONE Gas and wind down of our energy services business, our chief operating decision maker reviews the financial performance of each of the three businesses of ONEOK Partners on a regular basis to assess the performance of, and allocate resources to, ONEOK Partners. As a result, our reportable segments have changed to reflect the three business segments of ONEOK Partners. Prior periods presented have been recast to conform to the current presentation.

Accounting Policies - We evaluate performance based principally on each segment’s operating income and equity earnings. The accounting policies of the segments are described in Note A of the Notes to Consolidated Financial Statements in our Annual Report.  Affiliate and intersegment sales are recorded on the same basis as sales to unaffiliated customers.  Net margin is comprised of total revenues less cost of sales and fuel.  Cost of sales and fuel includes commodity purchases, fuel, storage and transportation costs. Revenues from sales and services provided by ONEOK Partners to our former Natural Gas Distribution segment, which were previously eliminated in consolidation, are now reported as third-party revenues.

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

For the three and six months ended June 30, 2014 and 2013, ONEOK Partners had no single customer from which it received 10 percent or more of consolidated revenues.

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

Three Months Ended	Natural Gas Gathering and Processing			Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Other and Eliminations			Total
June 30, 2014
	(Thousands of dollars)
Sales to unaffiliated customers	$	374,112		$	2,612,336	$	79,287	$	1,147		$	3,066,882
Intersegment revenues	349,253			52,974		2,698		(404,925		)	—
Total revenues	$	723,365		$	2,665,310	$	81,985	$	(403,778	)	$	3,066,882
Net margin	$	154,970		$	266,145	$	75,471	$	(1,106	)	$	495,480
Operating costs	59,386			76,081		27,287		9,268			172,022
Depreciation and amortization	29,443			31,109		10,895		680			72,127
Gain (loss) on sale of assets	(28		)	11		—		1			(16		)
Operating income	$	66,113		$	158,966	$	37,289	$	(11,053	)	$	251,315
Equity earnings from investments	$	5,099		$	4,459	$	15,877	$	—		$	25,435
Capital expenditures	$	168,208		$	210,676	$	8,710	$	5,082		$	392,676

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $153.3 million, of which $135.3 million related to sales within the segment, net margin of $84.4 million and operating income of $34.5 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $68.3 million, net margin of $59.5 million and operating income of $26.1 million.

Three Months Ended	Natural Gas Gathering and Processing		Natural Gas Liquids (a)			Natural Gas Pipelines (b)		Other and Eliminations (c)			Total
June 30, 2013
	(Thousands of dollars)
Sales to unaffiliated customers	$	166,709	$	2,461,119		$	49,011	$	805		$	2,677,644
Sales to affiliated customers	66,578		—			24,762		—			91,340
Intersegment revenues	248,972		29,996			1,269		(280,237		)	—
Total revenues	$	482,259	$	2,491,115		$	75,042	$	(279,432	)	$	2,768,984
Net margin	$	125,269	$	219,225		$	67,695	$	569		$	412,758
Operating costs	44,975		54,264			24,985		1,541			125,765
Depreciation and amortization	25,106		22,302			10,818		657			58,883
Gain (loss) on sale of assets	285		(6		)	—		—			279
Operating income	$	55,473	$	142,653		$	31,892	$	(1,629	)	$	228,389
Equity earnings from investments	$	5,229	$	5,912		$	15,280	$	—		$	26,421
Capital expenditures	$	206,019	$	269,339		$	6,007	$	77,903		$	559,268

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $121.6 million, of which $106.5 million related to sales within the segment, net margin of $76.8 million and operating income of $44.3 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $56.1 million, net margin of $52.0 million and operating income of $20.6 million.

(c) - The Other segment includes capital expenditures of discontinued operations of $68.8 million.

Six Months Ended	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)			Other and Eliminations (c)			Total
June 30, 2014
	(Thousands of dollars)
Sales to unaffiliated customers	$	721,128		$	5,282,991		$	170,393		$	2,140		$	6,176,652
Sales to affiliated customers	41,214			—			12,312			—			53,526
Intersegment revenues	723,148			94,131			4,073			(821,352		)	—
Total revenues	$	1,485,490		$	5,377,122		$	186,778		$	(819,212	)	$	6,230,178
Net margin	$	308,524		$	535,123		$	168,960		$	(6,500	)	$	1,006,107
Operating costs	124,210			141,183			54,749			991			321,133
Depreciation and amortization	58,285			58,187			21,710			1,359			139,541
Gain (loss) on sale of assets	(47		)	(37		)	(83		)	166			(1		)
Operating income	$	125,982		$	335,716		$	92,418		$	(8,684	)	$	545,432
Equity earnings from investments	$	10,585		$	9,223		$	39,286		$	—		$	59,094
Investments in unconsolidated affiliates	$	329,726		$	485,960		$	396,722		$	—		$	1,212,408
Total assets	$	4,276,593		$	7,363,417		$	1,852,901		$	891,627		$	14,384,538
Noncontrolling interests in consolidated subsidiaries	$	4,493		$	—		$	—		$	3,132,413		$	3,136,906
Capital expenditures	$	291,099		$	483,739		$	15,337		$	32,026		$	822,201

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $289.1 million, of which $246.9 million related to sales within the segment, net margin of $169.1 million and operating income of $79.6 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $149.6 million, net margin of $128.1 million and operating income of $61.2 million.

(c) - The Other segment includes assets and capital expenditures of discontinued operations of $87.5 million and $23.9 million, respectively.

Six Months Ended	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Other and Eliminations (c)			Total
June 30, 2013
	(Thousands of dollars)
Sales to unaffiliated customers	$	303,954	$	4,699,362	$	108,336	$	1,313		$	5,112,965
Sales to affiliated customers	122,236		—		51,738		—			173,974
Intersegment revenues	493,583		56,421		997		(551,001		)	—
Total revenues	$	919,773	$	4,755,783	$	161,071	$	(549,688	)	$	5,286,939
Net margin	$	234,554	$	405,845	$	141,767	$	1,699		$	783,865
Operating costs	96,663		114,066		52,151		4,020			266,900
Depreciation and amortization	49,010		42,040		21,854		1,262			114,166
Gain (loss) on sale of assets	313		3		4		—			320
Operating income	$	89,194	$	249,742	$	67,766	$	(3,583	)	$	403,119
Equity earnings from investments	$	11,560	$	9,047	$	31,669	$	—		$	52,276
Investments in unconsolidated affiliates	$	332,458	$	494,964	$	381,365	$	—		$	1,208,787
Total assets	$	3,346,874	$	6,008,574	$	1,792,343	$	4,694,483		$	15,842,274
Noncontrolling interests in consolidated subsidiaries	$	4,631	$	—	$	—	$	2,084,376		$	2,089,007
Capital expenditures	$	369,967	$	543,504	$	11,349	$	135,513		$	1,060,333

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $229.8 million, of which $191.1 million related to sales within the segment, net margin of $138.3 million and operating income of $75.6 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $124.5 million, net margin of $109.7 million and operating income of $44.4 million.

(c) - The Other segment includes assets and capital expenditures of discontinued operations of $4.0 billion and $122.6 million, respectively.

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CONSOLIDATED BALANCE SHEETS Parenthetical (USD $)	Jun. 30, 2014	Dec. 31, 2013
Statement of Financial Position [Abstract]
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)	207,999,517	206,618,877
Treasury stock, shares (in shares)	37,811,663	39,192,303

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CONSOLIDATED STATEMENTS OF INCOME (Parenthetical) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Interest Costs, Capitalized During Period	$ 11,375	$ 11,359	$ 27,143	$ 23,964

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EQUITY

6 Months Ended

Jun. 30, 2014

Equity [Abstract]

Stockholders' Equity Note Disclosure [Text Block]

G. EQUITY

The following table sets forth the changes in equity attributable to us and our noncontrolling interests, including other comprehensive income, net of tax, for the periods indicated:

	Three Months Ended									Three Months Ended
	June 30, 2014									June 30, 2013
	ONEOK Shareholders’ Equity			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity			ONEOK Shareholders’ Equity			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity
	(Thousands of dollars)
Beginning balance	$	584,500		$	2,543,207		$	3,127,707		$	2,134,354		$	2,069,779		$	4,204,133
Net income	61,590			79,161			140,751			919			78,576			79,495
Other comprehensive income (loss)	(3,214		)	(16,199		)	(19,413		)	11,183			32,102			43,285
Common stock issued	6,325			—			6,325			4,919			—			4,919
Common stock dividends	(116,409		)	—			(116,409		)	(74,201		)	—			(74,201		)
Issuance of common units of ONEOK Partners	116,129			635,424			751,553			—			(264		)	(264		)
Distributions to noncontrolling interests	—			(104,687		)	(104,687		)	—			(91,186		)	(91,186		)
Other	7,504			—			7,504			8,175			—			8,175
Ending balance	$	656,425		$	3,136,906		$	3,793,331		$	2,085,349		$	2,089,007		$	4,174,356

	Six Months Ended									Six Months Ended
	June 30, 2014									June 30, 2013
	ONEOK Shareholders’ Equity			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity			ONEOK Shareholders’ Equity			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity
	(Thousands of dollars)
Beginning balance	$	2,337,851		$	2,507,329		$	4,845,180		$	2,129,609		$	2,102,841		$	4,232,450
Net income	155,105			192,157			347,262			113,440			131,760			245,200
Other comprehensive income (loss)	5,471			(33,508		)	(28,037		)	4,828			24,576			29,404
Common stock issued	13,904			—			13,904			7,750			—			7,750
Common stock dividends	(199,684		)	—			(199,684		)	(147,982		)	—			(147,982		)
Issuance of common units of ONEOK Partners	127,125			677,270			804,395			2,956			11,352			14,308
Distribution of ONE Gas to shareholders	(1,747,424		)	—			(1,747,424		)	—			—			—
Distributions to noncontrolling interests	—			(206,342		)	(206,342		)	—			(181,522		)	(181,522		)
Other	(35,923		)	—			(35,923		)	(25,252		)	—			(25,252		)
Ending balance	$	656,425		$	3,136,906		$	3,793,331		$	2,085,349		$	2,089,007		$	4,174,356

Dividends - Dividends paid on our common stock to shareholders of record at the close of business on February 10, 2014 and April 30, 2014, were $0.40 per share and $0.56 per share, respectively.  A dividend of $0.575 per share was declared for shareholders of record at the close of business on August 4, 2014, payable August 14, 2014.

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

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Document And Entity Information	6 Months Ended
	Jun. 30, 2014	Jul. 29, 2014
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		208,002,586
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	Q2
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2014

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

6 Months Ended

Jun. 30, 2014

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

ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

H. ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

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

	Unrealized Gains (Losses) on Energy Marketing and Risk-Management Assets/Liabilities (a)			Unrealized Holding Gains (Losses) on Investment Securities (a)			Pension and Postretirement Benefit Plan Obligations (a)			Accumulated Other Comprehensive Income (Loss) (a)
	(Thousands of dollars)
January 1, 2014	$	(43,168	)	$	857		$	(79,676	)	$	(121,987	)
Other comprehensive income (loss) before reclassifications	(22,691		)	(113		)	(80		)	(22,884		)
Amounts reclassified from accumulated other comprehensive income (loss)	22,391			—			5,964			28,355
Other comprehensive income (loss) attributable to ONEOK	(300		)	(113		)	5,884			5,471
Transfer to ONE Gas	—			—			3,389			3,389
June 30, 2014	$	(43,468	)	$	744		$	(70,403	)	$	(113,127	)

(a) All amounts are presented net of tax.

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

Details about Accumulated Other Comprehensive Income (Loss) Components	Three Months Ended						Six Months Ended						Affected Line Item in the Consolidated Statements of Income
	June 30,						June 30,
	2014			2013			2014			2013
	(Thousands of dollars)
Unrealized (gains) losses on energy marketing and risk-management assets/liabilities
Commodity contracts	$	5,187		$	(1,245	)	$	31,606		$	(3,811	)	Commodity sales revenues
Interest-rate contracts	3,526			3,707			14,847			7,144			Interest expense
	8,713			2,462			46,453			3,333			Income before income taxes
	(1,202		)	(661		)	(9,098		)	(1,055		)	Income tax expense
	7,511			1,801			37,355			2,278			Income from continuing operations
	—			(5,191		)	7,683			1,627			Income from discontinued operations
	7,511			(3,390		)	45,038			3,905			Net income
Noncontrolling interest	5,538			754			22,647			606			Less: Net income attributable to noncontrolling interest
	$	1,973		$	(4,144	)	$	22,391		$	3,299		Net income attributable to ONEOK
Pension and postretirement benefit plan obligations (a)
Amortization of net loss	$	3,964		$	5,078		$	7,927		$	10,156
Amortization of unrecognized prior service cost	(367		)	(113		)	(734		)	(226		)
Amortization of unrecognized net asset at adoption	—			7			—			14
	3,597			4,972			7,193			9,944			Income before income taxes
	(1,439		)	(1,923		)	(2,877		)	(3,846		)	Income tax expense
	2,158			3,049			4,316			6,098			Income from continuing operations
	—			8,793			1,648			17,002			Income from discontinued operations
	$	2,158		$	11,842		$	5,964		$	23,100		Net income attributable to ONEOK
Total reclassifications for the period attributable to ONEOK	$	4,131		$	7,698		$	28,355		$	26,399		Net income attributable to ONEOK

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

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Statement of Comprehensive Income [Abstract]
Net income	$ 140,751	$ 79,495	$ 347,262	$ 245,200
Other comprehensive income (loss), net of tax
Unrealized gains (losses) on energy marketing and risk-management assets/liabilities, net of tax of $3,596, $(13,840), $13,824, and $(9,882), respectively	(28,920)	53,289	(78,846)	39,637
Realized (gains) losses in net income, net of tax of $(1,201), $2,614, $(14,219) and $(2,081), respectively	7,511	(3,390)	45,038	3,905
Unrealized holding gains (losses) on available-for-sale securities, net of tax of $25, $(168), $37 and $(130), respectively	(37)	268	(113)	206
Change in pension and postretirement benefit plan liability, net of tax of $(1,356), $4,340, $(3,923) and $9,048 respectively	2,033	(6,882)	5,884	(14,344)
Total other comprehensive income (loss), net of tax	(19,413)	43,285	(28,037)	29,404
Comprehensive income	121,338	122,780	319,225	274,604
Less: Comprehensive income attributable to noncontrolling interests	62,962	110,678	158,649	156,336
Comprehensive income attributable to ONEOK	$ 58,376	$ 12,102	$ 160,576	$ 118,268

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DISCONTINUED OPERATIONS

6 Months Ended

Jun. 30, 2014

Discontinued Operations [Abstract]

DISCONTINUED OPERATIONS

B. DISCONTINUED OPERATIONS

Separation of ONE Gas - On January 31, 2014, we completed the separation of ONE Gas. ONE Gas consists of ONEOK’s former natural gas distribution business that includes Kansas Gas Service, Oklahoma Natural Gas and Texas Gas Service. ONEOK shareholders of record at the close of business on January 21, 2014, retained their shares of ONEOK stock and received one share of ONE Gas stock for every four shares of ONEOK stock owned in a transaction that was tax-free to ONEOK and its shareholders. ONE Gas shares were distributed following the close of business on January 31, 2014. We retained no ownership interest in ONE Gas. On the date of the separation, ONE Gas consisted of approximately $4.3 billion of assets, $2.6 billion of liabilities and $1.7 billion of equity. Excluding cash of ONE Gas at separation, the separation was accounted for as a noncash activity. These balances include certain estimates expected to be finalized in 2014.

Wind Down of Energy Services Business - On March 31, 2014, we completed the accelerated wind down of our energy services business. We executed an agreement in the first quarter 2014 to release a nonaffiliated, third-party natural gas storage contract to a third party, resulting in a noncash charge of $1.7 million. All of the remaining natural gas transportation and storage contracts not previously released or assigned expired on their own terms on or before March 31, 2014. Our energy services business continued to serve its contracted premium-services until these remaining contracts expired on or before March 31, 2014. Our energy services business was classified as discontinued operations, effective at the close of business March 31, 2014, when substantially all operations ceased.

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

	Six Months Ended
	June 30, 2014
	(Millions of dollars)
Beginning balance	$	122.0
Noncash charges	1.7
Settlements	(25.7		)
Accretion	1.1
Ending balance	$	99.1

We expect future cash payments associated with previously released transportation and storage capacity from the wind down of our energy services business on an after-tax basis to be approximately $60 million, with approximately $15 million paid in the remainder of 2014, $23 million in 2015, $11 million in 2016 and $11 million over the period 2017 through 2023.

Results of Operations of Discontinued Operations - The results of operations for our former natural gas distribution and energy services businesses have been reported as discontinued operations for all periods presented. The tables below provide selected financial information reported in discontinued operations in the Consolidated Statements of Income:

	Three Months Ended											Six Months Ended
	June 30, 2014											June 30, 2014
	Natural Gas Distribution				Energy Services				Total			Natural Gas Distribution				Energy Services			Total
	(Thousands of dollars)
Revenues	$	—			$	—			$	—		$	287,249			$	353,404		$	640,653
Cost of sales and fuel	—				—				—			190,893				364,648			555,541
Net margin	—				—				—			96,356				(11,244		)	85,112
Operating costs	1,416			(a)	1,395			(c)	2,811			60,847			(a)	4,522			65,369
Depreciation and amortization	—				—				—			11,035				319			11,354
Operating income (loss)	(1,416		)		(1,395		)		(2,811		)	24,474				(16,085		)	8,389
Other income (expense), net	—				—				—			(888		)		(7		)	(895		)
Interest expense, net	—				—				—			(4,592		)		(413		)	(5,005		)
Income taxes	(5,745		)	(b)	547				(5,198		)	(16,415		)		7,691			(8,724		)
Income (loss) from discontinued operations, net	$	(7,161	)		$	(848	)		$	(8,009	)	$	2,579			$	(8,814	)	$	(6,235	)

(a) - Includes approximately $1.3 million and $23.0 million for the three and six months ended June 30, 2014, respectively, of costs related to the ONE Gas separation.

(b) - Reflects revision of estimates for income taxes related to the ONE Gas separation.

(c) - Represents primarily accretion expense.

	Three Months Ended									Six Months Ended
	June 30, 2013									June 30, 2013
	Natural Gas Distribution			Energy Services			Total			Natural Gas Distribution			Energy Services			Total
	(Thousands of dollars)
Revenues	$	311,606		$	359,984		$	671,590		$	947,537		$	830,179		$	1,777,716
Cost of sales and fuel	133,163			497,799			630,962			517,420			967,320			1,484,740
Net margin	178,443			(137,815		)	40,628			430,117			(137,141		)	292,976
Operating costs	104,382			3,479			107,861			217,785			8,367			226,152
Depreciation and amortization	32,904			68			32,972			67,771			139			67,910
Operating income (loss)	41,157			(141,362		)	(100,205		)	144,561			(145,647		)	(1,086		)
Other income (expense), net	(44		)	17			(27		)	575			45			620
Interest expense, net	(15,163		)	(448		)	(15,611		)	(30,469		)	(1,093		)	(31,562		)
Income taxes	(10,513		)	52,074			41,561			(40,801		)	53,749			12,948
Income (loss) from discontinued operations, net	$	15,437		$	(89,719	)	$	(74,282	)	$	73,866		$	(92,946	)	$	(19,080	)

Prior to the ONE Gas separation, natural gas sales and transportation and storage services provided to our former natural gas distribution business by ONEOK Partners were $14.3 million for the three months ended June 30, 2013, and $7.5 million and $28.1 million for the six months ended June 30,2014 and 2013, respectively. Prior to February 1, 2014, these revenues and related costs were eliminated in consolidation. Beginning February 1, 2014, these revenues represent third-party transactions with ONE Gas and are not eliminated in consolidation, as such sales and services have continued subsequent to the separation and are expected to continue in future periods.

Prior to the completion of the energy services wind down, natural gas sales and transportation and storage services provided to our energy services business by ONEOK Partners were $77.0 million for the three months ended June 30, 2013, and $46.0 million and $145.9 million for the six months ended June 30,2014 and 2013, respectively. While these transactions were eliminated in consolidation in previous periods, they are reflected now as affiliate transactions and not eliminated in consolidation as these transactions have continued with third parties.

Statement of Financial Position of Discontinued Operations - The following table presents the carrying value of assets and liabilities of our former natural gas distribution and energy services businesses included in assets and liabilities of discontinued operations in the Consolidated Balance Sheets for the period presented:

	December 31, 2013
	Natural Gas Distribution		Energy Services			Total
	(Thousands of dollars)
Assets
Cash and cash equivalents	$	3,535	$	213		$	3,748
Accounts receivable, net	368,214		87,315			455,529
Natural gas and natural gas liquids in storage	166,128		62,663			228,791
Other current assets	30,328		29,476			59,804
Net property, plant and equipment	3,065,272		279			3,065,551
Goodwill	157,953		—			157,953
Other assets	402,161		385			402,546
Total assets	$	4,193,591	$	180,331		$	4,373,922
Liabilities
Current maturities of long-term debt	$	6	$	—		$	6
Accounts payable	168,785		77,287			246,072
Other current liabilities	168,964		40,646			209,610
Long-term debt, excluding current maturities	1,318		—			1,318
Deferred income taxes	826,921		(35,221		)	791,700
Other deferred credits	184,214		70,998			255,212
Total liabilities	$	1,350,208	$	153,710		$	1,503,918

At June 30, 2014, the major classes of assets and liabilities in discontinued operations related to our former energy services business. These amounts consisted of current assets, which included income taxes receivable of $37.7 million and deferred tax assets of $14.5 million; noncurrent assets, which included deferred tax assets of $29.2 million; current liabilities, which included capacity release obligations of $46.2 million and deferred tax liabilities of $12.2 million; and noncurrent liabilities, which included $52.9 million of noncurrent capacity release obligations.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

6 Months Ended

Jun. 30, 2014

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

A. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Our accompanying unaudited consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC. These statements have been prepared in accordance with GAAP and reflect all adjustments that, in our opinion, are necessary for a fair presentation of the results for the interim periods presented.  All such adjustments are of a normal recurring nature. The 2013 year-end consolidated balance sheet data was derived from our audited financial statements but does not include all disclosures required by GAAP.  These unaudited consolidated financial statements should be read in conjunction with our audited consolidated financial statements in our Annual Report.

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

Organization and Nature of Operations - We are the sole general partner and own limited partner units of ONEOK Partners (NYSE: OKS), which together represent an aggregate 38.5 percent interest in ONEOK Partners at June 30, 2014. On January 31, 2014, we completed the separation of our natural gas distribution business into a stand-alone publicly traded company called ONE Gas. On March 31, 2014, we completed the accelerated wind down of our energy services business. The results of operations for our former natural gas distribution and energy services businesses have been classified as discontinued operations for all periods presented. Following the ONE Gas separation and wind down of our energy services business, our primary source of income and cash flow is generated from our investment in ONEOK Partners. See Note B for additional information.

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

Change in Reportable Segments - Following the separation of our natural gas distribution business into ONE Gas and wind down of our energy services business, our chief operating decision maker reviews the financial performance of each of the three businesses of ONEOK Partners on a regular basis to assess the performance of, and allocate resources to, ONEOK Partners. As a result, our reportable segments have changed to reflect the three business segments of ONEOK Partners, which include the following:

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

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

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

We have reflected the change in reporting segments for all periods presented. See Note N for additional information.

Income Taxes - Deferred income taxes are recorded for the difference between the financial statement and income tax basis of assets and liabilities and carryforward items, based on income tax laws and rates existing at the time the temporary differences are expected to reverse. Deferred tax liabilities and deferred income tax expense were reduced by $34.6 million in the first quarter 2014 due to a reduction in our estimate of the effective state income tax rate to reflect a change in the mix of taxable income in the states in which we now operate, resulting from the separation of our former natural gas distribution business and the wind down of our energy services business. We also recorded a valuation allowance of $8.2 million in the first quarter 2014 for state tax credits as it is more likely than not that we will not be able to utilize these credits as a result of the separation of our former natural gas distribution business and the wind down of our energy services business. Together, these adjustments resulted in a net $26.4 million reduction in deferred tax liabilities and deferred income tax expense.

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

In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers,” which outlines the principles an entity must apply to measure and recognize revenue for entities that enter into contracts to provide goods or services to their customers. The core principle is that an entity should recognize revenue at an amount that reflects the consideration to which the entity expects to be entitled in exchange for transferring goods or services to a customer. The amendments also require more extensive disaggregated revenue disclosures in interim and annual financial statements. This update will be effective for interim and annual periods that begin on or after December 15, 2016, with either retrospective application for all periods presented or retrospective application with a cumulative effect adjustment. We will adopt this guidance beginning in the first quarter 2017, and we are evaluating the impact on us.

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COMMITMENTS AND CONTINGENCIES

6 Months Ended

Jun. 30, 2014

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

M. COMMITMENTS AND CONTINGENCIES

Environmental Matters - ONEOK Partners is subject to multiple historical preservation, wildlife preservation and environmental laws and/or regulations that affect many aspects of 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, wetland 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 its results of operations. For example, if a leak or spill of hazardous substances or petroleum products occurs from pipelines or facilities that ONEOK Partners owns, operates or otherwise uses, ONEOK Partners could be held jointly and severally liable for all resulting liabilities, including response, investigation and cleanup costs, which could affect materially its 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 its facilities.  ONEOK Partners cannot assure that existing environmental statutes and regulations will not be revised or that new regulations will not be adopted or become applicable to it.  

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

The legal responsibility for the environmental conditions at former manufactured natural gas sites in Kansas was transferred from us to ONE Gas on January 31, 2014 upon the completion of the separation. Our expenditures for environmental assessment, mitigation, remediation and compliance prior to the separation were not significant in relation to our financial position, results of operations or cash flows, and our expenditures related to environmental matters have had no material effects on earnings or cash flows during the three and six months ended June 30, 2014 and 2013.

The EPA’s “Tailoring Rule” regulates greenhouse gas emissions at new or modified facilities that meet certain criteria. Affected facilities are required to review best available control technology (BACT), conduct air-quality and conduct impact analysis and public reviews with respect to such emissions.  At current emissions threshold levels, this rule has had a minimal impact on ONEOK Partners’ existing facilities.  The EPA has stated it will consider lowering the threshold levels over the next five years, which could increase the impact on its existing facilities; however, potential costs, fees or expenses associated with the potential adjustments are unknown. In addition, on June 23, 2014, the Supreme Court of the United States, in a case styled, Utility Air Regulatory Group v. EPA, 530 U.S. (2014), held that an industrial facility’s potential to emit greenhouse gas (GHG) emissions alone cannot subject a facility to the permitting requirements for major stationary source provisions of the Clean Air Act. The decision invalidated the EPA’s current Triggering and Tailoring Rule for GHG Prevention of Significant Deterioration (PSD) and Title V requirements. However, the Court also ruled that to the extent a source pursues a capital project (new construction or expansion of existing facility), which otherwise subjects the source to major source PSD permitting for conventional criteria pollutants, the permitting authorities may impose BACT analysis and emission limits for GHGs from those sources. We are in the process of evaluating the effects the decision may have on ONEOK Partners’ existing operations, and the opportunities it creates for design decisions for new project applications.

The EPA’s rule on air-quality standards, National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (RICE NESHAP), initially included a compliance date in 2013, and has since become effective. While the rule could require capital expenditures for the purchase and installation of new emissions-control equipment, ONEOK Partners does not expect these expenditures will have a material impact on its results of operations, financial position or cash flows.

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

The rule was most recently amended in September 2013, and a further proposed rulemaking was published in July 2014. The EPA has indicated that further amendments may be issued in 2014. Based on the amendments, ONEOK Partners’ understanding of pending stakeholder responses to the NSPS rule and the proposed rulemaking, ONEOK Partners does not anticipate a material impact to its anticipated capital, operations and maintenance costs resulting from compliance with the regulation. However, the EPA may issue additional responses, amendments and/or policy guidance on the final rule, which could alter its present expectations. Generally, the NSPS rule will require expenditures for updated emissions controls, monitoring and record-keeping at affected facilities in the crude oil and natural gas industry. ONEOK Partners does not expect these expenditures will have a material impact on its results of operations, financial position or cash flows.

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

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

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

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

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

The potential capital and operating expenditures related to this legislation, the associated regulations or other new pipeline safety regulations are unknown.

Financial Markets Legislation - The Dodd-Frank Act represents a far-reaching overhaul of the framework for regulation of United States financial markets. The CFTC has issued final regulations for most of the provisions of the Dodd-Frank Act, and we have implemented measures to comply with the regulations that are applicable to our businesses. ONEOK Partners continues to participate in financial markets for hedging certain risks inherent in its business, including commodity-price and interest-rate risks. Although the impact to date has not been material, we continue to monitor proposed regulations and the impact these regulations may have on our business and risk-management strategies in the future.

Legal Proceedings - Gas Index Pricing Litigation - As previously reported, ONEOK and its subsidiary, ONEOK Energy Services Company L.P. (OESC), along with several other energy companies, are defending multiple lawsuits arising from alleged market manipulation or false reporting of natural gas prices to natural gas-index publications. On April 10, 2013, the United States Court of Appeals for the Ninth Circuit reversed the summary judgments that had been granted in favor of ONEOK, OESC and other unaffiliated defendants in the following cases: Reorganized FLI, Learjet, Arandell, Heartland and NewPage. The Ninth Circuit also reversed the summary judgment that had been granted in favor of OESC on all state law claims asserted in the Sinclair case. ONEOK, OESC and the other unaffiliated defendants filed a Petition for Writ of Certiorari with the United States Supreme Court on August 26, 2013, seeking review of the Ninth Circuit decision. On July 1, 2014, the United States Supreme Court granted the the Petition for Writ of Certiorari. Oral argument has not yet been scheduled.

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

Other Legal Proceedings - We are a 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 on 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.

ONE Gas Separation - In connection with the separation of ONE Gas, we entered into a Separation and Distribution Agreement with ONE Gas, which sets forth the agreements between us and ONE Gas regarding the principal transactions necessary to effect the separation, including cross-indemnities between us and ONE Gas. In general, we agreed to indemnify ONE Gas for any liabilities relating to our business following the separation, including ONEOK Partners and our energy services business, and ONE Gas agreed to indemnify us for liabilities relating to the natural gas distribution business. If a liability does not relate to either our remaining business or to ONE Gas, then we and ONE Gas will each be responsible for a portion of such liability.

In addition, we entered into a Transition Services Agreement with ONE Gas. Under this agreement, ONEOK and ONE Gas agreed to provide each other with various services, including services relating to treasury and risk management, accounting, human resources and payroll management, tax compliance, telecommunications services and information technology services.

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EARNINGS PER SHARE

6 Months Ended

Jun. 30, 2014

Earnings Per Share [Abstract]

EARNINGS PER SHARE

I. 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, 2014
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	69,599	209,403	$	0.33
Diluted EPS from continuing operations
Effect of dilutive securities	—		1,113
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	69,599	210,516	$	0.33

	Three Months Ended June 30, 2013
	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	$	75,201	206,143	$	0.36
Diluted EPS from continuing operations
Effect of dilutive securities	—		2,731
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	75,201	208,874	$	0.36

	Six Months Ended June 30, 2014
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	161,340	209,267	$	0.77
Diluted EPS from continuing operations
Effect of dilutive securities	—		1,070
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	161,340	210,337	$	0.77

	Six Months Ended June 30, 2013
	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	$	132,520	205,811	$	0.64
Diluted EPS from continuing operations
Effect of dilutive securities	—		3,355
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	132,520	209,166	$	0.63

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CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE

6 Months Ended

Jun. 30, 2014

Short-term Debt [Abstract]

CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE

E. CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE

ONEOK Credit Agreement - The ONEOK Credit Agreement, which was amended and restated effective on January 31, 2014, and expires in January 2019, is a $300 million revolving credit facility and contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of indebtedness to Consolidated EBITDA (EBITDA, as defined in our ONEOK Credit Agreement) of no more than 4.0 to 1. Upon breach of certain covenants by us in the ONEOK Credit Agreement, amounts outstanding under the ONEOK Credit Agreement, if any, may become due and payable immediately. At June 30, 2014, ONEOK’s ratio of indebtedness to Consolidated EBITDA was 1.7 to 1, and ONEOK was in compliance with all covenants under the ONEOK Credit Agreement. As a result of a reduction in the borrowing capacity of the ONEOK Credit Agreement, we wrote off approximately $2.9 million in interest expense of previously deferred credit agreement issuance costs in the first quarter 2014.

The ONEOK Credit Agreement also includes a $50 million sublimit for the issuance of standby letters of credit and a $50 million sublimit for swingline loans. Under the terms of the ONEOK Credit Agreement, ONEOK may request an increase in the size of the facility to an aggregate of $500 million from $300 million by either commitments from new lenders or increased commitments from existing lenders. The ONEOK Credit Agreement contains provisions for an applicable margin rate and an annual facility fee, both of which adjust with changes in our credit rating. Based on our current credit rating, borrowings, if any, will accrue at LIBOR plus 125 basis points, and the annual facility fee is 25 basis points.

In February 2014, we repaid all amounts outstanding under our commercial paper program with a portion of the proceeds received from ONE Gas in connection with the separation and terminated the program. See Note F for additional information. At June 30, 2014, ONEOK had $2.1 million in letters of credit issued.

ONEOK Partners Credit Agreement - The amount of short-term borrowings authorized by ONEOK Partners GP’s Board of Directors is $2.5 billion. At June 30, 2014, ONEOK Partners had no commercial paper outstanding, $14.0 million in letters of credit issued and no borrowings under the ONEOK Partners Credit Agreement.

The ONEOK Partners Credit Agreement, which was amended and restated effective on January 31, 2014, and expires in January 2019, is a $1.7 billion revolving credit facility and includes a $100 million sublimit for the issuance of standby letters of credit, a $150 million swingline sublimit and an option to request an increase in the size of the facility to an aggregate of $2.4 billion by either commitments from new lenders or increased commitments from existing lenders. The ONEOK Partners Credit Agreement is available for general partnership purposes. During the second quarter 2014, ONEOK Partners increased the size of its commercial paper program to $1.7 billion from $1.2 billion. Amounts outstanding under ONEOK Partners’ commercial paper program reduce the borrowing capacity under the ONEOK Partners Credit Agreement.

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

The ONEOK Partners Credit Agreement contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of indebtedness to adjusted EBITDA (EBITDA, as defined in the ONEOK Partners Credit Agreement, adjusted for all noncash charges and increased for projected EBITDA from certain lender-approved capital expansion projects) of no more than 5.0 to 1.  If ONEOK Partners consummates one or more acquisitions in which the aggregate purchase price is $25 million or more, the allowable ratio of indebtedness to adjusted EBITDA will increase to 5.5 to 1 for the quarter in which the acquisition was completed and the two following quarters.  As a result of a pipeline acquisition ONEOK Partners completed in the first quarter 2014, the allowable ratio of indebtedness to adjusted EBITDA increased to 5.5 to 1 through the third quarter 2014. Upon breach of certain covenants by ONEOK Partners 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, 2014, its ratio of indebtedness to adjusted EBITDA was 3.4 to 1, and ONEOK Partners was in compliance with all covenants under the ONEOK Partners Credit Agreement.

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

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SEGMENTS (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Segment Reporting Information [Line Items]
Segment Reporting, Disclosure of Major Customers	ONEOK Partners had no single customer from which it received 10 percent or more of consolidated revenues	we had no single external customer from which we received 10 percent or more of our consolidated gross revenues	we had no single external customer from which we received 10 percent or more of our consolidated gross revenues	we had no single external customer from which we received 10 percent or more of our consolidated gross revenues
Total revenues	$ 3,066,882	$ 2,768,984	$ 6,230,178	$ 5,286,939
Net margin	495,480	412,758	1,006,107	783,865
Operating costs	172,022	125,765	321,133	266,900
Depreciation and amortization	72,127	58,883	139,541	114,166
Gain (loss) on sale of assets	(16)	279	(1)	320
Operating income	251,315	228,389	545,432	403,119
Equity earnings from investments	25,435	26,421	59,094	52,276
Investments in unconsolidated affiliates	1,212,408	1,208,787	1,212,408	1,208,787	1,229,838
Total assets	14,384,538	15,842,274	14,384,538	15,842,274	17,741,481
Noncontrolling interests in consolidated subsidiaries	3,136,906	2,089,007	3,136,906	2,089,007	2,507,329
Capital expenditures	392,676	559,268	822,201	1,060,333
Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Total revenues	723,365	482,259	1,485,490	919,773
Net margin	154,970	125,269	308,524	234,554
Operating costs	59,386	44,975	124,210	96,663
Depreciation and amortization	29,443	25,106	58,285	49,010
Gain (loss) on sale of assets	(28)	285	(47)	313
Operating income	66,113	55,473	125,982	89,194
Equity earnings from investments	5,099	5,229	10,585	11,560
Investments in unconsolidated affiliates	329,726	332,458	329,726	332,458
Total assets	4,276,593	3,346,874	4,276,593	3,346,874
Noncontrolling interests in consolidated subsidiaries	4,493	4,631	4,493	4,631
Capital expenditures	168,208	206,019	291,099	369,967
Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Total revenues	2,665,310	2,491,115	5,377,122	4,755,783
Net margin	266,145	219,225	535,123	405,845
Operating costs	76,081	54,264	141,183	114,066
Depreciation and amortization	31,109	22,302	58,187	42,040
Gain (loss) on sale of assets	11	(6)	(37)	3
Operating income	158,966	142,653	335,716	249,742
Equity earnings from investments	4,459	5,912	9,223	9,047
Investments in unconsolidated affiliates	485,960	494,964	485,960	494,964
Total assets	7,363,417	6,008,574	7,363,417	6,008,574
Noncontrolling interests in consolidated subsidiaries	0	0	0	0
Capital expenditures	210,676	269,339	483,739	543,504
Natural Gas Liquids [Member] | Natural Gas Liquids for Regulated Segment [Member]
Segment Reporting Information [Line Items]
Total revenues	153,300	121,600	289,100	229,800
Net margin	84,400	76,800	169,100	138,300
Operating income	34,500	44,300	79,600	75,600
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Total revenues	81,985	75,042	186,778	161,071
Net margin	75,471	67,695	168,960	141,767
Operating costs	27,287	24,985	54,749	52,151
Depreciation and amortization	10,895	10,818	21,710	21,854
Gain (loss) on sale of assets	0	0	(83)	4
Operating income	37,289	31,892	92,418	67,766
Equity earnings from investments	15,877	15,280	39,286	31,669
Investments in unconsolidated affiliates	396,722	381,365	396,722	381,365
Total assets	1,852,901	1,792,343	1,852,901	1,792,343
Noncontrolling interests in consolidated subsidiaries	0	0	0	0
Capital expenditures	8,710	6,007	15,337	11,349
Natural Gas Pipelines [Member] | Natural Gas Pipelines for Regulated Segment [Member]
Segment Reporting Information [Line Items]
Total revenues	68,300	56,100	149,600	124,500
Net margin	59,500	52,000	128,100	109,700
Operating income	26,100	20,600	61,200	44,400
Corporate Elimination [Member]
Segment Reporting Information [Line Items]
Total revenues	(403,778)	(279,432)	(819,212)	(549,688)
Net margin	(1,106)	569	(6,500)	1,699
Operating costs	9,268	1,541	991	4,020
Depreciation and amortization	680	657	1,359	1,262
Gain (loss) on sale of assets	1	0	166	0
Operating income	(11,053)	(1,629)	(8,684)	(3,583)
Equity earnings from investments	0	0	0	0
Investments in unconsolidated affiliates	0	0	0	0
Total assets	891,627	4,694,483	891,627	4,694,483
Noncontrolling interests in consolidated subsidiaries	3,132,413	2,084,376	3,132,413	2,084,376
Capital expenditures	5,082	77,903	32,026	135,513
Discontinued Operations [Member] | Corporate Elimination [Member]
Segment Reporting Information [Line Items]
Total assets	87,500	4,000,000	87,500	4,000,000
Capital expenditures	0	68,800	23,900	122,600
Sales to unaffiliated customers
Segment Reporting Information [Line Items]
Total revenues	3,066,882	2,677,644	6,176,652	5,112,965
Sales to unaffiliated customers | Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Total revenues	374,112	166,709	721,128	303,954
Sales to unaffiliated customers | Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Total revenues	2,612,336	2,461,119	5,282,991	4,699,362
Sales to unaffiliated customers | Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Total revenues	79,287	49,011	170,393	108,336
Sales to unaffiliated customers | Corporate Elimination [Member]
Segment Reporting Information [Line Items]
Total revenues	1,147	805	2,140	1,313
Sales to affiliated customers
Segment Reporting Information [Line Items]
Total revenues		91,340	53,526	173,974
Sales to affiliated customers | Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Total revenues		66,578	41,214	122,236
Sales to affiliated customers | Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Total revenues		0	0	0
Sales to affiliated customers | Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Total revenues		24,762	12,312	51,738
Sales to affiliated customers | Corporate Elimination [Member]
Segment Reporting Information [Line Items]
Total revenues		0	0	0
Intersegment revenues
Segment Reporting Information [Line Items]
Total revenues	0	0	0	0
Intersegment revenues | Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Total revenues	349,253	248,972	723,148	493,583
Intersegment revenues | Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Total revenues	52,974	29,996	94,131	56,421
Intersegment revenues | Natural Gas Liquids [Member] | Natural Gas Liquids for Regulated Segment [Member]
Segment Reporting Information [Line Items]
Total revenues	135,300	106,500	246,900	191,100
Intersegment revenues | Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Total revenues	2,698	1,269	4,073	997
Intersegment revenues | Corporate Elimination [Member]
Segment Reporting Information [Line Items]
Total revenues	$ (404,925)	$ (280,237)	$ (821,352)	$ (551,001)

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FAIR VALUE MEASUREMENTS

6 Months Ended

Jun. 30, 2014

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

C. 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 groups of financial assets and liabilities consistent with how a market participant would price the net risk exposure at the measurement date.

In the first quarter 2014, outstanding commodity derivative positions with third parties entered into by our energy services business on ONEOK Partners’ behalf were transferred to ONEOK Partners. Beginning in the second quarter 2014, ONEOK Partners enters into all commodity derivative financial contracts directly with unaffiliated third parties.

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

In addition, as prescribed by the income approach, ONEOK Partners computes the fair value of its derivative portfolio by discounting the projected future cash flows from its derivative assets and liabilities to present value using interest-rate yields to calculate present-value discount factors derived from LIBOR, Eurodollar futures and interest-rate swaps.  ONEOK Partners also takes 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.  It considers current market data in evaluating counterparties’, as well as its own, nonperformance risk, net of collateral, by using specific and sector bond yields and monitoring the credit default swap markets.  Although ONEOK Partners uses its best estimates to determine the fair value of the derivative contracts it has executed, the ultimate market prices realized could differ from its estimates, and the differences could be material.

The fair value of ONEOK Partners’ forward-starting interest-rate swaps is 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 and ONEOK Partners utilize a fair value hierarchy to classify fair value amounts recognized or disclosed in the 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 in active markets, including NYMEX-settled prices and actively quoted prices for equity securities. These balances are comprised predominantly of exchange-traded derivative contracts for natural gas and crude oil. Also included in Level 1 are equity securities.

• 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 basis curves that incorporate observable and unobservable market data, NGL price curves from broker quotes, market volatilities derived from the most recent NYMEX close spot prices and forward LIBOR curves, and adjustments for the credit risk of ONEOK Partners’ counterparties.  ONEOK Partners corroborates the data on which its fair value estimates are based using its 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.  ONEOK Partners does not believe that its Level 3 fair value estimates have a material impact on its results of operations, as the majority of its derivatives are accounted for as hedges for which ineffectiveness is not material.

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

	June 30, 2014
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Assets
Derivatives
Commodity contracts
Financial contracts	$	945		$	—		$	506		$	1,451		$	(1,451	)	$	—
Physical contracts	—			—			1,526			1,526			(933		)	593
Interest-rate contracts	—			26,649			—			26,649			—			26,649
Total derivatives	945			26,649			2,032			29,626			(2,384		)	27,242
Available-for-sale investment securities (c)	1,419			—			—			1,419			—			1,419
Total assets	$	2,364		$	26,649		$	2,032		$	31,045		$	(2,384	)	$	28,661
Liabilities
Derivatives
Commodity contracts
Financial contracts	$	(3,814	)	$	(2,865	)	$	(1,120	)	$	(7,799	)	$	4,934		$	(2,865	)
Physical contracts	—			—			(2,225		)	(2,225		)	933			(1,292		)
Interest-rate contracts	—			(19,240		)	—			(19,240		)	—			(19,240		)
Total liabilities	$	(3,814	)	$	(22,105	)	$	(3,345	)	$	(29,264	)	$	5,867		$	(23,397	)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis.  ONEOK Partners nets derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and ONEOK Partners.  At June 30, 2014, ONEOK Partners held no cash collateral and posted $3.5 million cash collateral with various counterparties.

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

(c) - Available-for-sale investment securities represent assets of ONEOK.

	December 31, 2013
	Level 1		Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Assets
Derivatives
Commodity contracts
Financial contracts	$	—	$	3,657		$	2,812		$	6,469		$	(1,746	)	$	4,723
Physical contracts	—		—			2,023			2,023			(946		)	1,077
Interest-rate contracts	—		54,503			—			54,503			—			54,503
Total derivatives	—		58,160			4,835			62,995			(2,692		)	60,303
Available-for-sale investment securities (c)	1,569		—			—			1,569			—			1,569
Total assets	$	1,569	$	58,160		$	4,835		$	64,564		$	(2,692	)	$	61,872
Liabilities
Derivatives
Commodity contracts
Financial contracts	$	—	$	(2,953	)	$	(2,154	)	$	(5,107	)	$	1,746		$	(3,361	)
Physical contracts	—		—			(3,463		)	(3,463		)	946			(2,517		)
Total derivative liabilities	$	—	$	(2,953	)	$	(5,617	)	$	(8,570	)	$	2,692		$	(5,878	)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis.  ONEOK Partners nets derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and ONEOK Partners. At December 31, 2013, we and ONEOK Partners had no cash collateral held or posted.

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

(c) - Available-for-sale investment securities represent assets of ONEOK.

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

	Three Months Ended						Six Months Ended
	June 30,						June 30,
Derivative Assets (Liabilities)	2014			2013			2014			2013
	(Thousands of dollars)
Net assets (liabilities) at beginning of period	$	1,972		$	(4,855	)	$	(782	)	$	(2,423	)
Total realized/unrealized gains (losses):
Included in earnings (a)	33			—			(895		)	—
Included in other comprehensive income (loss)	(3,318		)	12,537			(3,370		)	10,105
Purchases, issuances and settlements	—			—			3,734			—
Net assets (liabilities) at end of period	$	(1,313	)	$	7,682		$	(1,313	)	$	7,682

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

Realized/unrealized gains (losses) include the realization of ONEOK Partners’ derivative contracts through maturity. During the three and six months ended June 30, 2014 and 2013, 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 the period were not material.

ONEOK Partners recognizes 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, 2014 and 2013, there were no transfers between levels.

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

The estimated fair value of our consolidated long-term debt, including current maturities, was $8.0 billion, and $8.2 billion at June 30, 2014, and December 31, 2013, respectively.  The book value of long-term debt, including current maturities, was $7.2 billion and $7.8 billion at June 30, 2014, and December 31, 2013, 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, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

D. RISK-MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

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

Commodity-price risk - ONEOK Partners is exposed to the risk of loss in cash flows and future earnings arising from adverse changes in the price of natural gas, NGLs and condensate.  ONEOK Partners uses the following commodity derivatives instruments to mitigate the 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 typically are nontransferable and only can be canceled with the consent of both parties; and

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

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

The Natural Gas Liquids segment is exposed to basis risk primarily as a result of the relative value of NGL purchases at one location and sales at another location. To a lesser extent, ONEOK Partners 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. ONEOK Partners utilizes physical-forward contracts to reduce the impact of price fluctuations related to NGLs. At June 30, 2014, and December 31, 2013, there were no financial derivative instruments used in ONEOK Partners’ natural gas liquids operations.

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 as fuel in operations by these pipelines differs from the amount provided by its customers, ONEOK Partners’ pipelines must buy or sell natural gas, or store or use natural gas from inventory, which can expose it to commodity-price risk depending on the regulatory treatment for this activity. To the extent that commodity-price risk in its Natural Gas Pipelines segment is not mitigated by fuel cost-recovery mechanisms, ONEOK Partners uses physical-forward sales or purchases to reduce the impact of price fluctuations related to natural gas. At June 30, 2014, and December 31, 2013, there were no financial derivative instruments used in ONEOK Partners’ natural gas pipeline operations.

Interest-rate risk - We and ONEOK Partners manage interest-rate risk through the use of fixed-rate debt, floating-rate debt and interest-rate swaps. Interest-rate swaps are agreements to exchange interest payments at some future point based on specified notional amounts. ONEOK Partners has forward-starting interest-rate swaps designated as cash flow hedges of the variability of interest payments on a portion of forecasted debt issuances that may result from changes in the benchmark interest rate before the debt is issued. At June 30, 2014, ONEOK Partners had forward-starting interest-rate swaps with notional amounts totaling $400 million with settlement dates greater than 12 months and $500 million with settlement dates less than 12 months.

Accounting Treatment -We and ONEOK Partners record all derivative instruments at fair value, with the exception of normal purchases and normal sales that are expected to result in physical delivery.  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 and ONEOK Partners account for 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

Under certain conditions, we and ONEOK Partners designate derivative instruments as a hedge of exposure to changes in fair values or cash flows. We and ONEOK Partners formally document all relationships between hedging instruments and hedged items, as well as risk-management objectives, strategies for undertaking various hedge transactions and methods for assessing and testing correlation and hedge ineffectiveness. We and ONEOK Partners specifically identify the forecasted transaction that has been designated as the hedged item in a cash flow hedge relationship. We and ONEOK Partners assess the effectiveness of hedging relationships quarterly by performing an effectiveness analysis on fair value and cash flow hedging relationships to determine whether the hedge relationships are highly effective on a retrospective and prospective basis.  ONEOK Partners also documents normal purchases and normal sales transactions expected to result in physical delivery and that are exempted from derivative accounting treatment.

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

	June 30, 2014					December 31, 2013
	Assets (a)		(Liabilities) (a)			Assets (a)		(Liabilities) (a)
	(Thousands of dollars)
Derivatives designated as hedging instruments
Commodity contracts
Financial contracts	$	1,451	$	(7,799	)	$	6,469	$	(5,107	)
Physical contracts	1,462		(2,225		)	1,064		(3,463		)
Interest-rate contracts	26,649		(19,240		)	54,503		—
Total derivatives designated as hedging instruments	29,562		(29,264		)	62,036		(8,570		)
Derivatives not designated as hedging instruments
Commodity contracts
Physical contracts	64		—			959		—
Total derivatives not designated as hedging instruments	64		—			959		—
Total derivatives	$	29,626	$	(29,264	)	$	62,995	$	(8,570	)

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

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

		June 30, 2014					December 31, 2013
	Contract Type	Purchased/ Payor		Sold/ Receiver			Purchased/ Payor		Sold/ Receiver
Derivatives designated as hedging instruments:
Cash flow hedges
Fixed price
- Natural gas (Bcf)	Futures and swaps	—		(38.8		)	—		(48.1		)
- Crude oil and NGLs (MMbbl)	Futures, forwards and swaps	0.1		(3.0		)	—		(4.0		)
Basis
- Natural gas (Bcf)	Futures and swaps	—		(38.8		)	—		(48.1		)
Interest-rate contracts (Millions of dollars)	Forward-starting swaps	$	900.0	$	—		$	400.0	$	—

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

Cash Flow Hedges -Accumulated other comprehensive income (loss) at June 30, 2014, includes losses of approximately $2.9 million, net of tax, related to ONEOK Partners’ commodity derivative instruments that will be recognized within the next 18 months as the forecasted transactions affect earnings.  If prices remain at current levels, we will recognize $3.3 million in net losses over the next 12 months and net gains of $0.4 million thereafter.  The amount deferred in accumulated other comprehensive income (loss) attributable to our settled interest-rate swaps is a loss of $39.9 million, net of tax, which will be recognized over the life of the long-term, fixed-rate debt. We expect that losses of $4.7 million will be reclassified into earnings during the next 12 months as the hedged items affect earnings. The remaining amounts in accumulated other comprehensive income (loss) are attributable primarily to ONEOK Partners’ forward-starting interest-rate swaps with future settlement dates, which will be amortized to interest expense over the life of long-term, fixed-rate debt upon issuance of ONEOK Partners’ debt.

The following table sets forth the effects of cash flow hedges recognized in other comprehensive income (loss) for our continuing operations for the periods indicated:

Derivatives in Cash Flow Hedging Relationships	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2014			2013		2014			2013
	(Thousands of dollars)
Commodity contracts	$	(6,114	)	$	33,145	$	(41,876	)	$	13,377
Interest-rate contracts	(26,401		)	22,217		(47,094		)	29,005
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	$	(32,515	)	$	55,362	$	(88,970	)	$	42,382

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

Derivatives in Cash Flow Hedging Relationships	Location of Gain (Loss) Reclassified from  Accumulated Other Comprehensive Income (Loss) into Net Income (Effective Portion)	Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
		(Thousands of dollars)
Commodity contracts	Commodity sales revenues	$	(5,187	)	$	1,245		$	(31,606	)	$	3,811
Interest-rate contracts	Interest expense	(3,526		)	(3,707		)	(14,847		)	(7,144		)
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income on derivatives (effective portion)		$	(8,713	)	$	(2,462	)	$	(46,453	)	$	(3,333	)

Ineffectiveness related to our and ONEOK Partners’ cash flow hedges was not material for the three and six months ended June 30, 2014 and 2013.  In the event that it becomes probable that a forecasted transaction will not occur, ONEOK Partners will discontinue cash flow hedge treatment, which will affect earnings.

For the six months ended June 30, 2014, we reclassified losses of $4.6 million, net of taxes of $3.1 million, to interest expense from accumulated other comprehensive income (loss) due to the discontinuance of cash flow hedge treatment from the de-designation of interest-rate swaps related to the early retirement of long-term debt. See Note F for additional information. There were no gains or losses due to the discontinuance of cash flow hedge treatment during the three months ended June 30, 2014 and the three and six months ended June 30, 2013.

Credit Risk - In the first quarter 2014, outstanding commodity derivative positions with third parties entered into by our energy services business on ONEOK Partners’ behalf were transferred to ONEOK Partners. Beginning in the second quarter 2014, ONEOK Partners enters into all commodity derivative financial contracts directly with unaffiliated third parties.

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

Some of ONEOK Partners’ financial derivative instruments contain provisions that require it to maintain an investment-grade credit rating from S&P and/or Moody’s.  If ONEOK Partners’ credit ratings on 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 in a net liability position at June 30, 2014.

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

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LONG-TERM DEBT

6 Months Ended

Jun. 30, 2014

Long-term Debt, Unclassified [Abstract]

LONG-TERM DEBT

F. LONG-TERM DEBT

In January 2014, ONE Gas, which at the time was our wholly owned subsidiary, completed a private placement of three series of Senior Notes totaling $1.2 billion. The following table details information about each of the three series of Senior Notes:

	(In millions)
2.07% notes due February 1, 2019	$	300
3.61% notes due February 1, 2024	300
4.658% notes due February 1, 2044	600
Total	$	1,200

Our obligations related to the ONE Gas Senior Notes terminated when we completed the separation of ONE Gas on January 31, 2014.

ONE Gas made a cash payment to us of approximately $1.13 billion from the proceeds of this offering. In February 2014, we retired approximately $152.5 million of the 4.25 percent senior notes due 2022 through a tender offer. The total amount paid was approximately $150 million. In February 2014, we called our $400 million, 5.2 percent senior notes due in 2015. The full repayment occurred in March 2014 and totaled $430.1 million, including accrued but unpaid interest to the redemption date. We recorded a loss on extinguishment of $24.8 million related to the debt retirements, which is included in other expense in our Consolidated Statements of Income.

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EQUITY (Tables)

6 Months Ended

Jun. 30, 2014

Equity [Abstract]

Changes in equity, including other comprehensive income, net of tax

The following table sets forth the changes in equity attributable to us and our noncontrolling interests, including other comprehensive income, net of tax, for the periods indicated:

	Three Months Ended									Three Months Ended
	June 30, 2014									June 30, 2013
	ONEOK Shareholders’ Equity			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity			ONEOK Shareholders’ Equity			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity
	(Thousands of dollars)
Beginning balance	$	584,500		$	2,543,207		$	3,127,707		$	2,134,354		$	2,069,779		$	4,204,133
Net income	61,590			79,161			140,751			919			78,576			79,495
Other comprehensive income (loss)	(3,214		)	(16,199		)	(19,413		)	11,183			32,102			43,285
Common stock issued	6,325			—			6,325			4,919			—			4,919
Common stock dividends	(116,409		)	—			(116,409		)	(74,201		)	—			(74,201		)
Issuance of common units of ONEOK Partners	116,129			635,424			751,553			—			(264		)	(264		)
Distributions to noncontrolling interests	—			(104,687		)	(104,687		)	—			(91,186		)	(91,186		)
Other	7,504			—			7,504			8,175			—			8,175
Ending balance	$	656,425		$	3,136,906		$	3,793,331		$	2,085,349		$	2,089,007		$	4,174,356

	Six Months Ended									Six Months Ended
	June 30, 2014									June 30, 2013
	ONEOK Shareholders’ Equity			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity			ONEOK Shareholders’ Equity			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity
	(Thousands of dollars)
Beginning balance	$	2,337,851		$	2,507,329		$	4,845,180		$	2,129,609		$	2,102,841		$	4,232,450
Net income	155,105			192,157			347,262			113,440			131,760			245,200
Other comprehensive income (loss)	5,471			(33,508		)	(28,037		)	4,828			24,576			29,404
Common stock issued	13,904			—			13,904			7,750			—			7,750
Common stock dividends	(199,684		)	—			(199,684		)	(147,982		)	—			(147,982		)
Issuance of common units of ONEOK Partners	127,125			677,270			804,395			2,956			11,352			14,308
Distribution of ONE Gas to shareholders	(1,747,424		)	—			(1,747,424		)	—			—			—
Distributions to noncontrolling interests	—			(206,342		)	(206,342		)	—			(181,522		)	(181,522		)
Other	(35,923		)	—			(35,923		)	(25,252		)	—			(25,252		)
Ending balance	$	656,425		$	3,136,906		$	3,793,331		$	2,085,349		$	2,089,007		$	4,174,356

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CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE (Details) (USD $)	6 Months Ended
	Jun. 30, 2014	Mar. 31, 2014
Partnership Credit Agreement [Member]
Line of Credit Facility [Line Items]
Line Of Credit Facility Option To Increase Borrowing Capacity	$ 2,400,000,000
Maximum Amount Of Commercial Paper	1,700,000,000	1,200,000,000
Commercial paper	0
Letters of credit issued	14,000,000
Total short-term borrowings authorized by our general partner's Board of Directors	2,500,000,000
Interest rate description	borrowings, if any, will accrue at LIBOR plus 117.5 basis points
Annual fee descripton	the annual facility fee is 20 basis points
Indebtedness To Adjusted EBITDA Maximum	5.0
Acquisition price threshold for increase in permitted debt to EBITDA covenant ratio	25,000,000
Indebtedness To Adjusted EBITDA From Acquisitions Maximum	5.5
Indebtedness To Adjusted EBITDA Current	3.4
Partnership Credit Agreement sublimit for issuance of standby letters of credit	100,000,000
line of credit facility swingline subfacility	150,000,000
Maximum borrowing capacity	1,700,000,000
Short-term Bank Loans and Notes Payable	0.0
ONEOK Credit Agreement [Member]
Line of Credit Facility [Line Items]
Line Of Credit Facility Option To Increase Borrowing Capacity	500,000,000
Letters of credit issued	2,100,000
Interest rate description	borrowings, if any, will accrue at LIBOR plus 125 basis points
Annual fee descripton	the annual facility fee is 25 basis points
Indebtedness To Adjusted EBITDA Maximum	4.0
Indebtedness To Adjusted EBITDA Current	1.7
Partnership Credit Agreement sublimit for issuance of standby letters of credit	50,000,000
line of credit facility swingline subfacility	50,000,000
Maximum borrowing capacity	300,000,000
Write off of Deferred Debt Issuance Cost	$ 2,900,000

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UNCONSOLIDATED AFFILIATES

6 Months Ended

Jun. 30, 2014

Equity Method Investments and Joint Ventures [Abstract]

UNCONSOLIDATED AFFILIATES

K. UNCONSOLIDATED AFFILIATES

Equity Earnings from Investments -The following table sets forth ONEOK Partners’ equity earnings (losses) from investments for the periods indicated:

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2014			2013		2014			2013
	(Thousands of dollars)
Northern Border Pipeline	$	15,877		$	15,279	$	39,286		$	31,669
Overland Pass Pipeline Company	4,121			5,528		8,852			8,427
Fort Union Gas Gathering	4,280			3,080		8,409			6,949
Bighorn Gas Gathering	(873		)	626		(1,273		)	1,338
Other	2,030			1,908		3,820			3,893
Equity earnings from investments	$	25,435		$	26,421	$	59,094		$	52,276

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,
	2014		2013		2014		2013
	(Thousands of dollars)
Income Statement
Operating revenues	$	121,509	$	132,152	$	276,788	$	259,953
Operating expenses	$	51,870	$	61,124	$	123,549	$	125,395
Net income	$	60,878	$	65,746	$	139,551	$	123,950
Distributions paid to ONEOK Partners	$	42,579	$	39,311	$	77,649	$	69,504

ONEOK Partners incurred expenses in transactions with unconsolidated affiliates of $14.3 million and $12.6 million for the three months ended June 30, 2014 and 2013, respectively, and $28.4 million and $20.4 million for the six months ended June 30, 2014 and 2013, respectively, primarily related to Overland Pass Pipeline Company, which are included in cost of sales and fuel in our Consolidated Statements of Income. Accounts payable to ONEOK Partners’ equity method investees at June 30, 2014, and December 31, 2013, were not material.

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

Due to recent reductions in producer activity and declines in natural gas volumes gathered in the dry natural gas area of the Powder River Basin on the Bighorn Gas Gathering system in which ONEOK Partners owns a 49 percent interest, ONEOK Partners tested its investment for impairment at December 31, 2013. The estimated fair value exceeded the carrying value; however, a decline of 10 percent or more in the fair value of ONEOK Partners’ investment in Bighorn Gas Gathering would result in a noncash impairment charge. ONEOK Partners is not able to reasonably estimate a range of potential future impairment charges, as many of the assumptions that would be used in its estimate of fair value are dependent upon events beyond its control. The carrying amount of ONEOK Partners’ investment at June 30, 2014 was $85.7 million, which includes $53.4 million in equity method goodwill.

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FAIR VALUE MEASUREMENTS Fair Value Accounting Policy (Policies)

6 Months Ended

Jun. 30, 2014

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 groups of financial assets and liabilities consistent with how a market participant would price the net risk exposure at the measurement date.

In the first quarter 2014, outstanding commodity derivative positions with third parties entered into by our energy services business on ONEOK Partners’ behalf were transferred to ONEOK Partners. Beginning in the second quarter 2014, ONEOK Partners enters into all commodity derivative financial contracts directly with unaffiliated third parties.

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

In addition, as prescribed by the income approach, ONEOK Partners computes the fair value of its derivative portfolio by discounting the projected future cash flows from its derivative assets and liabilities to present value using interest-rate yields to calculate present-value discount factors derived from LIBOR, Eurodollar futures and interest-rate swaps.  ONEOK Partners also takes 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.  It considers current market data in evaluating counterparties’, as well as its own, nonperformance risk, net of collateral, by using specific and sector bond yields and monitoring the credit default swap markets.  Although ONEOK Partners uses its best estimates to determine the fair value of the derivative contracts it has executed, the ultimate market prices realized could differ from its estimates, and the differences could be material.

The fair value of ONEOK Partners’ forward-starting interest-rate swaps is 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 and ONEOK Partners utilize a fair value hierarchy to classify fair value amounts recognized or disclosed in the 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 in active markets, including NYMEX-settled prices and actively quoted prices for equity securities. These balances are comprised predominantly of exchange-traded derivative contracts for natural gas and crude oil. Also included in Level 1 are equity securities.

• 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 basis curves that incorporate observable and unobservable market data, NGL price curves from broker quotes, market volatilities derived from the most recent NYMEX close spot prices and forward LIBOR curves, and adjustments for the credit risk of ONEOK Partners’ counterparties.  ONEOK Partners corroborates the data on which its fair value estimates are based using its 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.  ONEOK Partners does not believe that its Level 3 fair value estimates have a material impact on its results of operations, as the majority of its derivatives are accounted for as hedges for which ineffectiveness is not material.

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES Part 2 (Details) (USD $) In Millions, unless otherwise specified	Jun. 30, 2014 MMcf	Dec. 31, 2013 MMcf
Derivative [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 0
Cash Flow Hedging [Member] | Fixed Price [Member] | Sold [Member] | Natural Gas [Member] | Swap [Member]
Derivative [Line Items]
Derivative nonmonetary notional amount	(38,800.0)	(48,100.0)
Cash Flow Hedging [Member] | Fixed Price [Member] | Sold [Member] | Crude oil and NGLs [Member] | Forwards and Swaps Contracts [Member]
Derivative [Line Items]
Derivative nonmonetary notional amount	(3.0)	(4.0)
Cash Flow Hedging [Member] | Fixed Price [Member] | Purchased [Member] | Natural Gas [Member] | Swap [Member]
Derivative [Line Items]
Derivative nonmonetary notional amount	0	0
Cash Flow Hedging [Member] | Fixed Price [Member] | Purchased [Member] | Crude oil and NGLs [Member] | Forwards and Swaps Contracts [Member]
Derivative [Line Items]
Derivative nonmonetary notional amount	0.1	0.0
Cash Flow Hedging [Member] | Basis [Member] | Sold [Member] | Natural Gas [Member] | Swap [Member]
Derivative [Line Items]
Derivative nonmonetary notional amount	(38,800.0)	(48,100.0)
Cash Flow Hedging [Member] | Basis [Member] | Purchased [Member] | Natural Gas [Member] | Swap [Member]
Derivative [Line Items]
Derivative nonmonetary notional amount	0	0
Cash Flow Hedging [Member] | Interest Rate Forward Starting Swaps [Member] | Sold [Member]
Derivative [Line Items]
Derivative, Notional Amount	0	0
Cash Flow Hedging [Member] | Interest Rate Forward Starting Swaps [Member] | Purchased [Member]
Derivative [Line Items]
Derivative, Notional Amount	900.0	400.0
Interest Rate Contract [Member] | Other Assets [Member] | Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, Notional Amount	$ 400.0

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $) In Millions, unless otherwise specified	6 Months Ended	12 Months Ended
	Jun. 30, 2014	Dec. 31, 2013
Entity [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	38.50%	41.20%
Reduction in deferred tax liabilities and deferred income tax expense	$ 34.6
Valuation allowance for deferred tax asset	8.2
Net change in deferred taxes from change in tax rate and valuation allowance	$ 26.4

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME Parenthetical (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Other comprehensive income (loss), net of tax
Unrealized gains (losses) on energy marketing and risk-management assets/liabilities, tax	$ 3,596	$ (13,840)	$ 13,824	$ (9,882)
Realized losses (gains) in net income, tax	(1,202)	2,614	(14,219)	(2,081)
Unrealized holding gains (losses) on available-for-sale securities, tax	25	(168)	37	(130)
Change in pension and postretirement benefit plan liability, tax	$ (1,356)	$ 4,340	$ (3,923)	$ 9,048

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CONSOLIDATED STATEMENT OF CHANGES IN EQUITY Parenthetical (USD $)	3 Months Ended			6 Months Ended
	Jun. 30, 2014	Mar. 31, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Statement of Stockholders' Equity [Abstract]
Common Stock, Dividends, Per Share, Cash Paid	$ 0.56	$ 0.40	$ 0.36	$ 0.96	$ 0.72

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UNCONSOLIDATED AFFILIATES (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Schedule of Equity Method Investments [Line Items]
Equity earnings from investments	$ 25,435,000	$ 26,421,000	$ 59,094,000	$ 52,276,000
Ownership in Bighorn Gas Gathering, LLC	49.00%		49.00%
Investments in unconsolidated affiliates	1,212,408,000	1,208,787,000	1,212,408,000	1,208,787,000	1,229,838,000
Income Statement
Operating revenues	121,509,000	132,152,000	276,788,000	259,953,000
Operating expenses	51,870,000	61,124,000	123,549,000	125,395,000
Net income	60,878,000	65,746,000	139,551,000	123,950,000
Distributions paid to ONEOK Partners	42,579,000	39,311,000	77,649,000	69,504,000
Northern Border Pipeline [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings from investments	15,877,000	15,279,000	39,286,000	31,669,000
Overland Pass Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings from investments	4,121,000	5,528,000	8,852,000	8,427,000
Fort Union Gas Gathering, L.L.C. [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings from investments	4,280,000	3,080,000	8,409,000	6,949,000
Bighorn Gas Gathering L.L.C. [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings from investments	(873,000)	626,000	(1,273,000)	1,338,000
Investments in unconsolidated affiliates	85,700,000		85,700,000
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	53,400,000		53,400,000
Other Unconsolidated Affiliate [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings from investments	2,030,000	1,908,000	3,820,000	3,893,000
Unconsolidated Affiliates [Member]
Schedule of Equity Method Investments [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	$ 14,300,000	$ 12,600,000	$ 28,400,000	$ 20,400,000

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES (Policies)

6 Months Ended

Jun. 30, 2014

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES [Abstract]

Accounting treatment for derivative instruments

Accounting Treatment -We and ONEOK Partners record all derivative instruments at fair value, with the exception of normal purchases and normal sales that are expected to result in physical delivery.  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 and ONEOK Partners account for 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

Under certain conditions, we and ONEOK Partners designate derivative instruments as a hedge of exposure to changes in fair values or cash flows. We and ONEOK Partners formally document all relationships between hedging instruments and hedged items, as well as risk-management objectives, strategies for undertaking various hedge transactions and methods for assessing and testing correlation and hedge ineffectiveness. We and ONEOK Partners specifically identify the forecasted transaction that has been designated as the hedged item in a cash flow hedge relationship. We and ONEOK Partners assess the effectiveness of hedging relationships quarterly by performing an effectiveness analysis on fair value and cash flow hedging relationships to determine whether the hedge relationships are highly effective on a retrospective and prospective basis.  ONEOK Partners also documents normal purchases and normal sales transactions expected to result in physical delivery and that are exempted from derivative accounting treatment.

The realized revenues and purchase costs of derivative instruments that are 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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UNCONSOLIDATED AFFILIATES (Tables)

6 Months Ended

Jun. 30, 2014

Equity Method Investments and Joint Ventures [Abstract]

Equity Earnings from Investments

Equity Earnings from Investments -The following table sets forth ONEOK Partners’ equity earnings (losses) from investments for the periods indicated:

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2014			2013		2014			2013
	(Thousands of dollars)
Northern Border Pipeline	$	15,877		$	15,279	$	39,286		$	31,669
Overland Pass Pipeline Company	4,121			5,528		8,852			8,427
Fort Union Gas Gathering	4,280			3,080		8,409			6,949
Bighorn Gas Gathering	(873		)	626		(1,273		)	1,338
Other	2,030			1,908		3,820			3,893
Equity earnings from investments	$	25,435		$	26,421	$	59,094		$	52,276

Unconsolidated Affiliates Financial Information [Table Text Block]

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,
	2014		2013		2014		2013
	(Thousands of dollars)
Income Statement
Operating revenues	$	121,509	$	132,152	$	276,788	$	259,953
Operating expenses	$	51,870	$	61,124	$	123,549	$	125,395
Net income	$	60,878	$	65,746	$	139,551	$	123,950
Distributions paid to ONEOK Partners	$	42,579	$	39,311	$	77,649	$	69,504

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EMPLOYEE BENEFIT PLANS

6 Months Ended

Jun. 30, 2014

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

EMPLOYEE BENEFIT PLANS

J. 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						Pension Benefits
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2014			2013			2014			2013
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	1,823		$	1,532		$	3,645		$	3,064
Interest cost	4,628			3,906			9,256			7,812
Expected return on assets	(4,934		)	(4,969		)	(9,869		)	(9,938		)
Amortization of unrecognized prior service cost	48			58			96			116
Amortization of net loss	3,756			4,755			7,511			9,510
Other	120			—			120			—
Net periodic benefit cost	$	5,441		$	5,282		$	10,759		$	10,564

	Postretirement Benefits						Postretirement Benefits
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2014			2013			2014			2013
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	179		$	118		$	358		$	236
Interest cost	611			298			1,222			596
Expected return on assets	(555		)	(314		)	(1,110		)	(628		)
Amortization of unrecognized net asset at adoption	—			7			—			14
Amortization of unrecognized prior service cost	(415		)	(171		)	(830		)	(342		)
Amortization of net loss	208			323			416			646
Other	(2		)	—			(2		)	—
Net periodic benefit cost	$	26		$	261		$	54		$	522