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, 2012

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

Yes __ No X

On July 27, 2012, the Company had 205,056,209 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)
	Consolidated Statements of Income - Three and Six Months Ended June 30, 2012 and 2011	6
	Consolidated Statements of Comprehensive Income - Three and Six Months Ended June 30, 2012 and 2011	7
	Consolidated Balance Sheets - June 30, 2012, and December 31, 2011	8-9
	Consolidated Statements of Cash Flows - Six Months Ended June 30, 2012 and 2011	11
	Consolidated Statement of Changes in Equity - Six Months Ended June 30, 2012	12-13
	Notes to Consolidated Financial Statements	14-36
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	37-62
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	62-63
Item 4.	Controls and Procedures	63
Part II.	Other Information
Item 1.	Legal Proceedings	64
Item 1A.	Risk Factors	64
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	65
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, Quarterly Reports, 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, 2011

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

Bcf/d Billion cubic feet per day

Btu(s) 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.

KCC Kansas Corporation Commission

KDHE Kansas Department of Health and Environment

LDCs Local distribution companies

LIBOR London Interbank Offered Rate

MBbl Thousand barrels

MBbl/d Thousand barrels per day

Mcf Thousand cubic feet

MDth/d Thousand dekatherms per day

MMBbl Million barrels

MMBtu Million British thermal units

MMBtu/d Million British thermal units per day

MMcf Million cubic feet

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 products Marketable natural gas liquid purity products, such as ethane, ethane/propane

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

NGL(s) Natural gas liquid(s)

NYMEX New York Mercantile Exchange

OCC Oklahoma Corporation Commission

ONEOK ONEOK, Inc.

ONEOK 2011 Credit Agreement ONEOK’s five-year, $1.2 billion revolving credit agreement dated April 5, 2011

ONEOK Partners ONEOK Partners, L.P.

ONEOK Partners 2011 Credit Agreement ONEOK Partners’ five-year, $1.2 billion revolving credit agreement dated

August 1, 2011

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

general partner of ONEOK Partners

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

POP Percent of Proceeds

S&P Standard & Poor’s Rating Services

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)	2012			2011			2012			2011
	(Thousands of dollars, except per share amounts)
Revenues	$	2,529,260		$	3,444,798		$	5,943,860		$	7,205,398
Cost of sales and fuel		1,980,298			2,925,965			4,751,311			6,056,688
Net margin		548,962			518,833			1,192,549			1,148,710
Operating expenses
Operations and maintenance		204,126			197,772			397,007			390,531
Depreciation and amortization		84,586			78,793			167,995			158,150
Goodwill impairment		-			-			10,255			-
General taxes		27,137			25,837			58,314			54,759
Total operating expenses		315,849			302,402			633,571			603,440
Gain (loss) on sale of assets		966			(212	)		1,023			(722	)
Operating income		234,079			216,219			560,001			544,548
Equity earnings from investments (Note K)		29,169			29,544			63,789			61,636
Allowance for equity funds used during construction		1,849			400			2,824			866
Other income		686			340			6,446			3,692
Other expense		(4,898	)		(772	)		(3,071	)		(3,057	)
Interest expense		(71,535	)		(75,498	)		(147,350	)		(154,847	)
Income before income taxes		189,350			170,233			482,639			452,838
Income taxes		(40,412	)		(35,904	)		(114,251	)		(120,224	)
Income from continuing operations		148,938			134,329			368,388			332,614
Income from discontinued operations, net of tax (Note B)		-			437			762			1,498
Gain on sale of discontinued operations, net of tax (Note B)		267			-			13,517			-
Net income		149,205			134,766			382,667			334,112
Less: Net income attributable to noncontrolling interests		88,212			79,624			198,809			148,840
Net income attributable to ONEOK	$	60,993		$	55,142		$	183,858		$	185,272
Amounts attributable to ONEOK:
Income from continuing operations	$	60,726		$	54,705		$	169,579		$	183,774
Income from discontinued operations		267			437			14,279			1,498
Net income	$	60,993		$	55,142		$	183,858		$	185,272
Basic earnings per share:
Income from continuing operations (Note I)	$	0.29		$	0.26		$	0.82		$	0.87
Income from discontinued operations		-			-			0.07			-
Net income	$	0.29		$	0.26		$	0.89		$	0.87
Diluted earnings per share:
Income from continuing operations (Note I)	$	0.29		$	0.25		$	0.80		$	0.85
Income from discontinued operations		-			-			0.07			-
Net income	$	0.29		$	0.25		$	0.87		$	0.85
Average shares (thousands)
Basic		207,292			210,674			207,454			212,358
Diluted		211,784			216,060			211,818			217,210
Dividends declared per share of common stock	$	0.330		$	0.260		$	0.635		$	0.520
See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
	Three Months Ended						Six Months Ended
	June 30,						June 30,
(Unaudited)	2012			2011			2012			2011
	(Thousands of dollars)
Net income	$	149,205		$	134,766		$	382,667		$	334,112
Other comprehensive income (loss), net of tax
Unrealized gains (losses) on energy marketing and risk-management
assets/liabilities, net of tax of $4,773, $(5,028), $(14,229) and
$(3,614), respectively		(12,634	)		16,819			34,939			(69	)
Realized (gains) losses in net income, net of tax of $8,449, $(301),
$6,835 and $11,934, respectively		(22,556	)		3,407			(23,736	)		(16,709	)
Unrealized holding gains (losses) on available-for-sale securities,
net of tax of $65, $31, $(76) and $94, respectively		(104	)		(49	)		120			(148	)
Change in pension and postretirement benefit plan liability, net of tax
of $3,644, $2,947, $7,288 and $5,895, respectively		(5,777	)		(4,672	)		(11,554	)		(9,345	)
Other, net of tax of $0, $39, $0 and $50, respectively		-			(62	)		-			(80	)
Total other comprehensive income (loss), net of tax		(41,071	)		15,443			(231	)		(26,351	)
Comprehensive income		108,134			150,209			382,436			307,761
Less: Comprehensive income attributable to noncontrolling interests		73,936			91,196			198,097			144,953
Comprehensive income attributable to ONEOK	$	34,198		$	59,013		$	184,339		$	162,808
See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS
	June 30,		December 31,
(Unaudited)	2012		2011
Assets	(Thousands of dollars)
Current assets
Cash and cash equivalents	$	114,920	$	65,953
Accounts receivable, net		793,842		1,339,933
Gas and natural gas liquids in storage		561,802		549,915
Commodity imbalances		37,716		63,452
Energy marketing and risk management assets (Notes C and D)		90,335		40,280
Other current assets		208,704		185,143
Assets of discontinued operations (Note B)		-		74,136
Total current assets		1,807,319		2,318,812
Property, plant and equipment
Property, plant and equipment		11,953,916		11,177,934
Accumulated depreciation and amortization		2,855,863		2,733,601
Net property, plant and equipment		9,098,053		8,444,333
Investments and other assets
Investments in unconsolidated affiliates (Note K)		1,210,268		1,223,398
Goodwill and intangible assets		1,000,039		1,014,127
Other assets		701,512		695,965
Total investments and other assets		2,911,819		2,933,490
Total assets	$	13,817,191	$	13,696,635
See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS
	June 30,			December 31,
(Unaudited)	2012			2011
Liabilities and equity	(Thousands of dollars)
Current liabilities
Current maturities of long-term debt	$	12,262		$	364,391
Notes payable (Note E)		595,931			841,982
Accounts payable		911,977			1,341,718
Commodity imbalances		201,515			202,206
Energy marketing and risk management liabilities (Notes C and D)		138,028			137,680
Other current liabilities		396,964			345,383
Liabilities of discontinued operations (Note B)		-			12,815
Total current liabilities		2,256,677			3,246,175
Long-term debt, excluding current maturities (Note F)		5,224,623			4,529,551
Deferred credits and other liabilities
Deferred income taxes		1,457,896			1,446,591
Other deferred credits		672,007			674,586
Total deferred credits and other liabilities		2,129,903			2,121,177
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
205,041,894 shares at June 30, 2012; issued 245,809,848 shares and
outstanding 206,509,960 shares at December 31, 2011		2,458			2,458
Paid-in capital		1,326,204			1,417,185
Accumulated other comprehensive loss (Note H)		(205,640	)		(206,121	)
Retained earnings		2,017,460			1,960,374
Treasury stock, at cost: 40,769,286 shares at June 30, 2012, and
39,299,888 shares at December 31, 2011		(1,050,942	)		(935,323	)
Total ONEOK shareholders' equity		2,089,540			2,238,573
Noncontrolling interests in consolidated subsidiaries		2,116,448			1,561,159
Total equity		4,205,988			3,799,732
Total liabilities and equity	$	13,817,191		$	13,696,635
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)	2012			2011
	(Thousands of dollars)
Operating activities
Net income	$	382,667		$	334,112
Depreciation and amortization		168,003			158,215
Impairment of goodwill		10,255			-
Gain on sale of discontinued operations		(13,517	)		-
Reclassified loss on energy price risk management assets and liabilities		29,861			-
Equity earnings from investments		(63,789	)		(61,636	)
Distributions received from unconsolidated affiliates		69,490			55,302
Deferred income taxes		111,172			108,504
Share-based compensation expense		16,928			29,615
Allowance for equity funds used during construction		(2,824	)		(866	)
Loss (gain) on sale of assets		(1,023	)		722
Other		(1,308	)		(1,013	)
Changes in assets and liabilities:
Accounts receivable		541,053			209,112
Gas and natural gas liquids in storage		(11,445	)		134,760
Accounts payable		(404,006	)		(20,199	)
Commodity imbalances, net		25,045			(12,452	)
Energy marketing and risk management assets and liabilities		(56,590	)		(4,437	)
Other assets and liabilities		(147,362	)		(54,140	)
Cash provided by operating activities		652,610			875,599
Investing activities
Capital expenditures (less allowance for equity funds used during construction)		(780,697	)		(523,772	)
Proceeds from sale of discontinued operations, net of cash sold		32,008			-
Contributions to unconsolidated affiliates		(7,237	)		(1,655	)
Distributions received from unconsolidated affiliates		14,705			15,750
Proceeds from sale of assets		1,828			788
Other		942			-
Cash used in investing activities		(738,451	)		(508,889	)
Financing activities
Borrowing (repayment) of notes payable, net		(246,051	)		(30,222	)
Issuance of debt, net of discounts		699,657			1,295,450
Long-term debt financing costs		(5,395	)		(10,986	)
Repayment of debt		(356,173	)		(631,316	)
Repurchase of common stock		(150,000	)		(300,105	)
Issuance of common stock		4,591			4,920
Issuance of common units, net of issuance costs		459,680			-
Dividends paid		(126,772	)		(111,356	)
Distributions to noncontrolling interests		(153,588	)		(136,556	)
Cash provided by financing activities		125,949			79,829
Change in cash and cash equivalents		40,108			446,539
Change in cash and cash equivalents included in discontinued operations		8,859			(4,701	)
Change in cash and cash equivalents from continuing operations		48,967			441,838
Cash and cash equivalents at beginning of period		65,953			30,341
Cash and cash equivalents at end of period	$	114,920		$	472,179
See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
		ONEOK Shareholders' Equity
										Accumulated
	Common									Other
		Stock		Common			Paid-in			Comprehensive
(Unaudited)		Issued			Stock		Capital			Income (Loss)
		(Shares)		(Thousands of dollars)
December 31, 2011			245,809,848		$	2,458	$	1,417,185		$	(206,121	)
Net income			-			-		-			-
Other comprehensive income			-			-		-			481
Repurchase of common stock			-			-		-			-
Common stock issued			1,332			-		(27,829	)		-
Common stock dividends -
$0.61 per share			-			-		-			-
Issuance of common units of ONEOK Partners			-			-		(51,100	)		-
Distributions to noncontrolling interests			-			-		-			-
Other			-			-		(12,052	)		-
June 30, 2012			245,811,180		$	2,458	$	1,326,204		$	(205,640	)
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
								Noncontrolling
									Interests in
		Retained			Treasury				Consolidated			Total
(Unaudited)		Earnings			Stock				Subsidiaries			Equity
	(Thousands of dollars)
December 31, 2011		$	1,960,374		$	(935,323	)		$	1,561,159		$	3,799,732
Net income			183,858			-				198,809			382,667
Other comprehensive income			-			-				(712	)		(231	)
Repurchase of common stock			-			(150,000	)			-			(150,000	)
Common stock issued			-			34,381				-			6,552
Common stock dividends -
$0.61 per share			(126,772	)		-				-			(126,772	)
Issuance of common units of ONEOK Partners			-			-				510,780			459,680
Distributions to noncontrolling interests			-			-				(153,588	)		(153,588	)
Other			-			-				-			(12,052	)
June 30, 2012		$	2,017,460		$	(1,050,942	)		$	2,116,448		$	4,205,988

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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 2011 year-end consolidated balance sheet data was derived from 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.  Due to the seasonal nature of our business, the results of operations for the three and six months ended June 30, 2012, are not necessarily indicative of the results that may be expected for a 12-month period.

Stock Split - In June 2012, we completed our previously announced two-for-one split of our common stock.  The two-for-one split was effected by a distribution on June 1, 2012, of one share of stock for each share outstanding and held by shareholders of record on May 24, 2012.  We have adjusted all share and per-share amounts contained herein, to be presented on a post-split basis.

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

Recently Issued Accounting Standards Update -In May 2011, the FASB issued ASU 2011-04, “Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and International Financial Reporting Standards (IFRS),” which provides a consistent definition of fair value and common requirements for measurement of and disclosure about fair value between GAAP and IFRS.  This new guidance changes some fair value measurement principles and disclosure requirements.  We adopted this guidance with our March 31, 2012, Quarterly Report, and the impact was not material.  See Note C for information on our fair value measurements.

In June 2011, the FASB issued ASU 2011-05, “Presentation of Comprehensive Income,” which provides two options for presenting items of net income, other comprehensive income and total comprehensive income either by creating one continuous statement of comprehensive income or two separate consecutive statements, and requires certain other disclosures.  In December 2011, the FASB issued ASU 2011-12, “Deferral of the Effective Date for Amendments to the Presentation of Reclassifications of Items Out of Accumulated Other Comprehensive Income in Accounting Standards Update No. 2011-05,” which deferred certain presentation requirements in ASU 2011-05 for items reclassified out of accumulated other comprehensive income.  We adopted this guidance, except for the portions deferred by ASU 2011-12, with our March 31, 2012, Quarterly Report, and the impact was not material.

In July 2012, the FASB issued ASU 2012-02, “Testing Indefinite-lived Intangible Assets for Impairment,” which allows companies to perform a “qualitative” assessment to determine whether further impairment testing of indefinite-lived intangible assets is necessary.  Under the revised standard, an entity is not required to calculate the fair value of an indefinite-lived intangible asset and perform the quantitative impairment test unless the entity determines that it is more likely than not that the asset is impaired.  An entity has the option to bypass the qualitative assessment and perform the quantitative impairment test for any indefinite-lived intangible assets in any period.  We are evaluating the impact of this recently issued guidance, which is required to be adopted for our annual assessments beginning in 2013.

B.           DISCONTINUED OPERATIONS

On February 1, 2012, we sold ONEOK Energy Marketing Company, our retail natural gas marketing business, to Constellation Energy Group, Inc. for $22.5 million plus working capital.  We received net proceeds of approximately $32.9 million, $0.9 million of which was received in July 2012, and recognized a gain on the sale of approximately $13.5 million, net of taxes of $8.3 million.  The proceeds from the sale were used to reduce short-term borrowings.  The financial information of ONEOK Energy Marketing Company is reflected as discontinued operations in this Quarterly Report.  All prior periods presented have been recast to reflect the discontinued operations.

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The amounts of revenue, costs and income taxes reported in discontinued operations are set forth in the table below for the periods indicated:

	One Month Ended		Three Months Ended				Six Months Ended
	January 31,			June 30,			June 30,
	2012			2011			2011
	(Thousands of dollars)
Revenues	$	27,607		$	69,677		$	175,966
Cost of sales and fuel		25,961			66,862			169,479
Net margin		1,646			2,815			6,487
Operating costs		408			2,084			4,017
Depreciation and amortization		8			33			65
Operating income		1,230			698			2,405
Other income (expense), net		-			(1	)		15
Income taxes		(468	)		(260	)		(922	)
Income from discontinued operations, net	$	762		$	437		$	1,498

The following table discloses the major classes of discontinued assets and liabilities included on our Consolidated Balance Sheet for the period indicated:

		December 31,
		2011
Assets	(Thousands of dollars)
Cash and cash equivalents		$	8,859
Accounts receivable, net			47,967
Gas in storage			2,101
Energy marketing and risk management assets			15,016
Other assets			193
Assets of discontinued operations		$	74,136
Liabilities
Accounts payable		$	11,435
Energy marketing and risk management liabilities			629
Other liabilities			751

Liabilities of discontinued operations $ 12,815

At December 31, 2011, the liabilities of our discontinued operations exclude $45.7 million of intercompany payables due to its parent or other affiliates.

C.           FAIR VALUE MEASUREMENTS

Fair Value Measurements -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 the 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.

While many of the contracts in our portfolio are executed in liquid markets where price transparency exists, some contracts are executed in markets for which market prices may exist, but the market may be relatively inactive.  This results in limited price transparency that requires management’s judgment and assumptions to estimate fair values.  Inputs into our fair value estimates include commodity exchange prices, over-the-counter quotes, volatility, historical correlations of pricing data and LIBOR and other liquid money market instrument rates.  We also utilize internally developed basis curves that incorporate

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

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

	June 30, 2012
	Level 1			Level 2			Level 3			Netting			Total
	(Thousands of dollars)
Assets
Derivatives (a)
Commodity contracts
Financial contracts	$	330,358		$	27,248		$	46,636		$	-		$	404,242
Physical contracts		-			12,308			2,944			-			15,252
Netting		-			-			-			(320,001	)		(320,001	)
Total derivatives		330,358			39,556			49,580			(320,001	)		99,493
Trading securities (b)		6,326			-			-			-			6,326
Available-for-sale investment securities (c)		2,145			-			-			-			2,145
Total assets	$	338,829		$	39,556		$	49,580		$	(320,001	)	$	107,964
Liabilities
Derivatives (a)
Commodity contracts
Financial contracts	$	(304,810	)	$	(5,171	)	$	(11,148	)	$	-		$	(321,129	)
Physical contracts		-			(2	)		(687	)		-			(689	)
Netting		-			-			-			299,848			299,848
Interest-rate contracts		-			(116,166	)		-			-			(116,166	)
Total derivatives		(304,810	)		(121,339	)		(11,835	)		299,848			(138,136	)
Fair value of firm commitments (d)		-			-			(4,250	)		-			(4,250	)
Total liabilities	$	(304,810	)	$	(121,339	)	$	(16,085	)	$	299,848		$	(142,386	)
(a) - Our derivative assets and liabilities are presented in our Consolidated Balance Sheets as energy marketing and risk management assets and liabilities and other assets on a net basis. We net derivative assets and liabilities, including cash collateral, when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and us. At June 30, 2012, we held $21.7 million of cash collateral and had posted $8.4 million of cash collateral with various counterparties.
(b) - Included in our Consolidated Balance Sheets as other current assets.
(c) - Included in our Consolidated Balance Sheets as other assets.
(d) - Included in our Consolidated Balance Sheets as other current liabilities and other deferred credits.

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	December 31, 2011
	Level 1			Level 2			Level 3			Netting			Total
	(Thousands of dollars)
Assets
Derivatives (a)
Commodity contracts
Financial contracts	$	545,247		$	13,874		$	32,931		$	-		$	592,052
Physical contracts		-			23,879			14,916			-			38,795
Netting		-			-			-			(569,243	)		(569,243	)
Total derivatives		545,247			37,753			47,847			(569,243	)		61,604
Trading securities (b)		5,749			-			-			-			5,749
Available-for-sale investment securities (c)		1,949			-			-			-			1,949
Total assets	$	552,945		$	37,753		$	47,847		$	(569,243	)	$	69,302
Liabilities
Derivatives (a)
Commodity contracts
Financial contracts	$	(479,073	)	$	(6,498	)	$	(20,995	)	$	-		$	(506,566	)
Physical contracts		-			(261	)		(1,748	)		-			(2,009	)
Netting		-			-			-			497,608			497,608
Interest-rate contracts		-			(128,666	)		-			-			(128,666	)
Total derivatives		(479,073	)		(135,425	)		(22,743	)		497,608			(139,633	)
Fair value of firm commitments (d)		-			-			(7,283	)		-			(7,283	)
Total liabilities	$	(479,073	)	$	(135,425	)	$	(30,026	)	$	497,608		$	(146,916	)
(a) - Our derivative assets and liabilities are presented in our Consolidated Balance Sheets as energy marketing and risk management assets and liabilities, other assets and other deferred credits on a net basis. We net derivative assets and liabilities, including cash collateral, when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and us. At December 31, 2011, we held $73.3 million of cash collateral and had posted $1.7 million of cash collateral with various counterparties.
(b) - Included in our Consolidated Balance Sheets as other current assets.
(c) - Included in our Consolidated Balance Sheets as other assets.
(d) - Included in our Consolidated Balance Sheets as other current liabilities and other deferred credits.

The December 31, 2011, table above includes balances for ONEOK Energy Marketing Company that have been reflected as discontinued operations in our Consolidated Balance Sheet.  At December 31, 2011, we had $15.0 million in derivative assets and $0.6 million in derivative liabilities related to this discontinued operation.

Our Level 1 fair value measurements are based on NYMEX-settled prices and actively quoted prices for equity securities.  These balances are comprised predominantly of exchange-traded derivative contracts, including futures and certain options for natural gas and crude oil, which are valued based on unadjusted quoted prices in active markets.  Also included in Level 1 are equity securities.

Our Level 2 fair value inputs are based on NYMEX-settled prices for natural gas and crude oil that are utilized to determine the fair value of certain nonexchange-traded financial instruments, including natural gas and crude oil swaps, as well as physical forwards.  Also, included in Level 2 are interest-rate swaps that are valued using financial models that incorporate the implied forward LIBOR yield curve for the same period as the future interest swap settlements.

Our Level 3 inputs include internally developed basis curves incorporating observable and unobservable market data, NGL price curves from independent broker quotes, market volatilities derived from the most recent NYMEX close spot prices and forward LIBOR curves, and adjustments for the credit risk of our counterparties.  We corroborate the data on which our fair value estimates are based using our market knowledge of recent transactions, analysis of historical correlations and validation with independent broker quotes.  The derivatives categorized as Level 3 include natural gas basis swaps, swing swaps, options, other commodity swaps and physical forward contracts.  Also included in Level 3 are the fair values of firm commitments.  We do not believe that our Level 3 fair value estimates have a material impact on our results of operations, as the majority of our derivatives are accounted for as hedges for which ineffectiveness is not material.  The significant unobservable inputs used in the fair value measurement of our swaps, forwards and firm commitments are the unpublished forward basis and index curves.  Significant increases or decreases in either of those inputs in isolation would not have a material impact on our fair value measurements.

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The following tables set forth the reconciliation of our Level 3 fair value measurements for the periods indicated:

	Derivative Assets (Liabilities)			Fair Value of Firm Commitments			Total
	(Thousands of dollars)
April 1, 2012	$	17,948		$	(3,770	)	$	14,178
Total realized/unrealized gains (losses):
Included in earnings (a)		(1,117	)		(480	)		(1,597	)
Included in other comprehensive income (loss)		20,942			-			20,942
Transfers into Level 3		(28	)		-			(28	)
June 30, 2012	$	37,745		$	(4,250	)	$	33,495
Total gains (losses) for the period included in    earnings attributable to the change in unrealized    gains (losses) relating to assets and liabilities    still held as of June 30, 2012 (a)	$	1,571		$	(1,318	)	$	253
(a) - Reported in revenues and cost of sales and fuel in our Consolidated Statements of Income.

	Derivative Assets (Liabilities)			Fair Value of Firm Commitments			Total
	(Thousands of dollars)
April 1, 2011	$	30,615		$	(28,991	)	$	1,624
Total realized/unrealized gains (losses):
Included in earnings (a)		(12,329	)		7,779			(4,550	)
Included in other comprehensive income (loss)		1,297			-			1,297
Transfers into Level 3		4,757			-			4,757
Transfers out of Level 3		(482	)		-			(482	)
June 30, 2011	$	23,858		$	(21,212	)	$	2,646
Total gains (losses) for the period included in    earnings attributable to the change in unrealized    gains (losses) relating to assets and liabilities    still held as of June 30, 2011 (a)	$	11,278		$	(3,672	)	$	7,606
(a) - Reported in revenues and cost of sales and fuel in our Consolidated Statements of Income.

	Derivative Assets (Liabilities)			Fair Value of Firm Commitments			Total
	(Thousands of dollars)
January 1, 2012	$	25,104		$	(7,283	)	$	17,821
Total realized/unrealized gains (losses):
Included in earnings (a)		(7,873	)		3,033			(4,840	)
Included in other comprehensive income (loss)		26,727			-			26,727
Sale of discontinued operations		(3,636	)		-			(3,636	)
Transfers out of Level 3		(2,577	)		-			(2,577	)
June 30, 2012	$	37,745		$	(4,250	)	$	33,495
Total gains (losses) for the period included in    earnings attributable to the change in unrealized    gains (losses) relating to assets and liabilities    still held as of June 30, 2012 (a)	$	(419	)	$	(640	)	$	(1,059	)
(a) - Reported in revenues and cost of sales and fuel in our Consolidated Statements of Income.

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	Derivative Assets (Liabilities)			Fair Value of Firm Commitments			Total
	(Thousands of dollars)
January 1, 2011	$	49,266		$	(29,536	)	$	19,730
Total realized/unrealized gains (losses):
Included in earnings (a)		(20,333	)		8,324			(12,009	)
Included in other comprehensive income (loss)		(8,558	)		-			(8,558	)
Transfers into Level 3		4,182			-			4,182
Transfers out of Level 3		(699	)		-			(699	)
June 30, 2011	$	23,858		$	(21,212	)	$	2,646
Total gains (losses) for the period included in    earnings attributable to the change in unrealized    gains (losses) relating to assets and liabilities    still held as of June 30, 2011 (a)	$	12,524		$	(6,634	)	$	5,890
(a) - Reported in revenues and cost of sales and fuel in our Consolidated Statements of Income.

Realized/unrealized gains (losses) include the realization of our derivative contracts through maturity and changes in fair value of our hedged firm commitments.  We recognize transfers into and out of the levels in the fair value hierarchy as of the end of each reporting period.  We had no transfers into or out of Level 1 during the periods presented.  Transfers into Level 3 represent existing assets or liabilities that were previously categorized at a higher level for which the unobservable inputs became a more significant portion of the fair value estimates.  Transfers out of Level 3 represent existing assets and liabilities that were classified previously as Level 3 for which the observable inputs became a more significant portion of the fair value estimates.

Our Level 3 fair value measurements based on unobservable inputs, excluding the portion of our fair value measurements based on third-party pricing information without adjustment, are not material at June 30, 2012.

Goodwill Impairment - As a result of the continued decline in natural gas prices and its effect on location and seasonal price differentials, we performed an interim impairment assessment of our Energy Services segment’s goodwill balance as of March 31, 2012. As a result of this assessment, goodwill with a carrying amount of $10.3 million was written down to its implied fair value of zero, with a resulting impairment charge of $10.3 million recorded in earnings for the three months ended March 31, 2012.  The fair value of our Energy Services reporting unit and the implied fair value of its goodwill were calculated using Level 3, significant unobservable inputs.

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 $5.9 billion at June 30, 2012, and $5.6 billion at December 31, 2011.  The book value of long-term debt, including current maturities, was $5.2 billion and $4.9 billion at June 30, 2012, and December 31, 2011, 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.  Our consolidated long-term debt is classified as Level 2.

D.           RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

Our Energy Services and ONEOK Partners segments are exposed to various risks that we manage by periodically entering into derivative instruments.  These risks include the following:

·   Commodity price risk - We are exposed to the risk of loss in cash flows and future earnings arising from adverse changes in the price of natural gas, NGLs and crude oil.  We use commodity derivative instruments such as futures, physical forward contracts, swaps and options to reduce the commodity price risk associated with a portion of the

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forecasted purchases and sales of commodities and natural gas and natural gas liquids in storage.  Commodity price volatility may have a significant impact on the fair value of our derivative instruments as of a given date;

·   Basis risk - We are exposed to the risk of loss in cash flows and future earnings arising from adverse changes in the price differentials between pipeline receipt and delivery locations.  Our firm transportation capacity allows us to purchase natural gas at a pipeline receipt point and sell natural gas at a pipeline delivery point.  As market conditions permit, our Energy Services segment periodically enters into basis swaps between the transportation receipt and delivery points in order to protect the fair value of these location price differentials related to our firm commitments;

·   Currency exchange rate risk - As a result of our Energy Services segment’s activities in Canada, we are exposed to the risk of loss in cash flows and future earnings from adverse changes in currency exchange rates on our commodity purchases and sales, primarily related to our firm transportation and storage contracts that are transacted in a currency other than our functional currency, the United States dollar.  To reduce our exposure to exchange-rate fluctuations, we use physical forward transactions, which result in an actual two-way flow of currency on the settlement date in which we exchange United States dollars for Canadian dollars with another party; and

·   Interest-rate risk -We are also subject to fluctuations in interest rates.  We manage interest-rate risk through the use of fixed-rate debt, floating-rate debt and interest-rate swaps.

The following derivative instruments are used to manage our exposure to these risks:

·   Futures contracts - Standardized exchange-traded contracts to purchase or sell natural gas and crude oil at a specified price, requiring delivery on or settlement through the sale or purchase of an offsetting contract by a specified future date under the provisions of exchange regulations;

·   Forward contracts - Commitments to purchase or sell natural gas, crude oil or NGLs for physical delivery at some specified time in the future.  We also may use currency forward contracts to manage our currency exchange-rate risk.  Forward contracts are different from futures in that forwards are customized and nonexchange traded;

·   Swaps - Financial trades involving the exchange of payments based on two different pricing structures for a commodity or other instrument.  In a typical commodity swap, parties exchange payments based on changes in the price of a commodity or a market index, while fixing the price they effectively pay or receive for the physical commodity.  As a result, one party assumes the risks and benefits of movements in market prices, while the other party assumes the risks and benefits of a fixed price for the commodity.  Interest-rate swaps are agreements to exchange interest payments at some future point based on specified notional amounts; and

·   Options - Contractual agreements that give the holder the right, but not the obligation, to buy or sell a fixed quantity of a commodity, at a fixed price, within a specified period of time.  Options may either be standardized and exchange traded or customized and nonexchange traded.

Our objectives for entering into such contracts include but are not limited to:

·   reducing the variability of cash flows by locking in the price for all or a portion of anticipated index-based physical purchases and sales, transportation fuel requirements, asset management transactions and customer-related business activities;

·   locking in a price differential to protect the fair value between transportation receipt and delivery points and to protect the fair value of natural gas or NGLs that are purchased in one month and sold in a later month;

·   reducing our exposure to fluctuations in interest and foreign currency exchange rates; and

·   reducing variability in cash flows from changes in interest rates associated with forecasted debt issuances.

Our Energy Services segment also enters into derivative contracts for financial trading purposes primarily to capitalize on opportunities created by market volatility, weather-related events, supply-demand imbalances and market liquidity inefficiencies, which allow us to capture additional margin.  Financial trading activities are executed generally using financially settled derivatives and are normally short term in nature.

With respect to the net open positions that exist within our marketing and financial trading operations, fluctuating commodity prices can impact our financial position and results of operations.  The net open positions are actively managed, and the impact of the changing prices on our financial condition at a point in time is not necessarily indicative of the impact of price movements throughout the year.

Our Natural Gas Distribution segment also uses derivative instruments to hedge the cost of a portion of anticipated natural gas purchases during the winter heating months to protect our customers from upward volatility in the market price of natural gas.  The use of these derivative instruments and the associated recovery of these costs have been approved by the OCC, KCC and regulatory authorities in certain Texas jurisdictions.

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ONEOK and ONEOK Partners each entered into 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.  ONEOK had interest-rate swaps with notional values totaling $500 million at December 31, 2011.  In January 2012, ONEOK entered into additional interest-rate swaps with notional amounts totaling $200 million.  Upon issuance in January 2012 of our $700 million, 4.25-percent senior notes due 2022, ONEOK settled all $700 million of its interest-rate swaps and realized a loss of $44.1 million in accumulated other comprehensive income that will be amortized to interest expense over the term of the hedged debt.  At June 30, 2012, and December 31, 2011, ONEOK Partners had forward-starting interest-rate swaps with notional amounts totaling $1 billion and $750 million, respectively.  In July 2012, ONEOK Partners entered into additional forward-starting interest-rate swaps with settlement dates greater than 12 months that were also designated as cash flow hedges with notional amounts totaling $400 million.

Accounting Treatment -We 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.

If certain conditions are met, we may elect to designate a derivative instrument as a hedge of exposure to changes in fair values, cash flows or foreign currency.  Certain nontrading derivative transactions, which are economic hedges of our accrual transactions such as our storage and transportation contracts, do not qualify for hedge accounting treatment.

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

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

Gains or losses associated with the fair value of derivative instruments entered into by our Natural Gas Distribution segment are included in, and recoverable through, the monthly purchased-gas cost mechanism.

We 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 specifically identify the asset, liability, firm commitment or forecasted transaction that has been designated as the hedged item.  We assess the effectiveness of hedging relationships quarterly by performing an effectiveness analysis on our cash flow and fair value hedging relationships to determine whether the hedge relationships are highly effective on a retrospective and prospective basis.  We also document our normal purchases and normal sales transactions that we expect to result in physical delivery and that we elect to exempt from derivative accounting treatment.

The presentation of settled derivative instruments on either a gross or net basis in our Consolidated Statements of Income is dependent on the relevant facts and circumstances of our different types of activities rather than based solely on the terms of the individual contracts.  All financially settled derivative instruments, as well as derivative instruments considered held for trading purposes that result in physical delivery, are reported on a net basis in revenues in our Consolidated Statements of Income.  The realized revenues and purchase costs of derivative instruments that are not considered held for trading purposes and nonderivative contracts are reported on a gross basis.  Derivatives that qualify as normal purchases or normal sales that are expected to result in physical delivery are also reported on a gross basis.

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Revenues in our Consolidated Statements of Income include financial trading margins, as well as certain physical natural gas transactions with our trading counterparties.  Revenues and cost of sales and fuel from such physical transactions are reported on a net basis.

Cash flows from futures, forwards, options 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 - The following table sets forth the fair values of our derivative instruments for our continuing and discontinued operations for the periods indicated:

	June 30, 2012						December 31, 2011
	Fair Values of Derivatives (a)						Fair Values of Derivatives (a)
	Assets			(Liabilities)			Assets			(Liabilities)
	(Thousands of dollars)
Derivatives designated as hedging instruments
Commodity contracts
Financial contracts	$	136,655	(b)	$	(48,014	)(b)	$	184,184	(c)	$	(73,346	)(c)
Physical contracts		165			(71	)		62			(344	)
Interest-rate contracts		-			(116,166	)		-			(128,666	)
Total derivatives designated as hedging instruments		136,820			(164,251	)		184,246			(202,356	)
Derivatives not designated as hedging instruments
Commodity contracts
Nontrading instruments
Financial contracts		190,780			(197,993	)		295,948			(323,170	)
Physical contracts		15,087			(618	)		38,733			(1,665	)
Trading instruments
Financial contracts		76,807			(75,122	)		111,920			(110,050	)
Total derivatives not designated as hedging instruments		282,674			(273,733	)		446,601			(434,885	)
Total derivatives	$	419,494		$	(437,984	)	$	630,847		$	(637,241	)
(a) - Included on a net basis in energy marketing and risk management assets and liabilities, other assets and other deferred credits on our Consolidated Balance Sheets.
(b) - Includes $7.5 million of derivative assets associated with cash flow purchase hedges tied to injections of inventory into storage that were adjusted to reflect the lower of cost or market value in a prior period. The deferred gains associated with these assets have been reclassified from accumulated other comprehensive loss.
(c) - Includes $88.9 million of derivative assets associated with cash flow hedges of inventory that were adjusted to reflect the lower of cost or market value. The deferred gains associated with these assets have been reclassified from accumulated other comprehensive loss.

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

		June 30, 2012					December 31, 2011
	Contract Type	Purchased/ Payor		Sold/ Receiver			Purchased/ Payor		Sold/ Receiver
Derivatives designated as hedging instruments:
Cash flow hedges
Fixed price
- Natural gas (Bcf)	Exchange futures		8.1		(16.7	)		21.2		(23.4	)
	Swaps		8.5		(90.3	)		19.5		(111.9	)
- Crude oil and NGLs (MMBbl)	Swaps		-		(2.6	)		-		(2.9	)
Basis
- Natural gas (Bcf)	Forwards and swaps		13.7		(45.5	)		3.2		(82.8	)
Interest-rate contracts (Millions of dollars)	Forward-starting swaps	$	1,000.0		-		$	1,250.0		-
Fair value hedges
Basis
- Natural gas (Bcf)	Forwards and swaps		91.0		(91.0	)		76.5		(77.0	)
Derivatives not designated as hedging instruments:
Fixed price
- Natural gas (Bcf)	Exchange futures		56.1		(44.7	)		76.9		(59.6	)
	Forwards and swaps		136.0		(149.2	)		235.8		(253.4	)
	Options		205.0		(205.3	)		33.6		(14.3	)
Basis
- Natural gas (Bcf)	Forwards and swaps		159.3		(164.6	)		216.9		(219.3	)
Index
- Natural gas (Bcf)	Forwards and swaps		34.5		(15.3	)		29.3		(22.1	)

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

Cash Flow Hedges -Our Energy Services and ONEOK Partners segments use derivative instruments to hedge the cash flows associated with anticipated purchases and sales of natural gas, NGLs and condensate and cost of fuel used in the transportation of natural gas.  Accumulated other comprehensive income (loss) at June 30, 2012, includes gains of approximately $15.2 million, net of tax, related to these hedges that will be recognized within the next 18 months as the forecasted transactions affect earnings.  If prices remain at current levels, we will recognize $8.9 million in net gains over the next 12 months, and we will recognize net gains of $6.3 million thereafter.  The remaining amounts deferred in accumulated other comprehensive income (loss) are primarily attributable to our interest-rate swaps, which will be amortized to interest expense over the life of long-term, fixed-rate debt upon issuance of the debt.

For the six months ended June 30, 2012, net margin in our Consolidated Statement of Income includes losses of $29.9 million related to certain financial contracts that were used to hedge forecasted purchases of natural gas.  As a result of the continued decline in natural gas prices, the combination of the cost basis of the forecasted purchases of inventory and the financial contracts exceed the amount expected to be recovered through sales of that inventory after considering related sales hedges, which requires reclassification of the loss from accumulated other comprehensive loss to current period earnings.

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

	Three Months Ended					Six Months Ended
Derivatives in Cash Flow	June 30,					June 30,
Hedging Relationships	2012			2011		2012			2011
	(Thousands of dollars)
Commodity contracts	$	35,349		$	21,847	$	80,914		$	3,545
Interest-rate contracts		(52,756	)		-		(31,746	)		-
Total gain (loss) recognized in other comprehensive income (loss) on    derivatives (effective portion)	$	(17,407	)	$	21,847	$	49,168		$	3,545

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The following tables set forth the effect of cash flow hedges on our Consolidated Statements of Income for the periods indicated:

	Location of Gain (Loss) Reclassified from	Three Months Ended
Derivatives in Cash Flow	Accumulated Other Comprehensive Income	June 30,
Hedging Relationships	(Loss) into Net Income (Effective Portion)	2012			2011
		(Thousands of dollars)
Commodity contracts	Revenues	$	33,660		$	(3,510	)
Commodity contracts	Cost of sales and fuel		(1,460	)		(108	)
Interest-rate contracts	Interest expense		(1,195	)		(90	)
Total gain (loss) reclassified from accumulated other comprehensive income (loss)    into net income on derivatives (effective portion)		$	31,005		$	(3,708	)

	Location of Gain (Loss) Reclassified from	Six Months Ended
Derivatives in Cash Flow	Accumulated Other Comprehensive Income	June 30,
Hedging Relationships	(Loss) into Net Income (Effective Portion)	2012			2011
		(Thousands of dollars)
Commodity contracts	Revenues	$	96,030		$	29,877
Commodity contracts	Cost of sales and fuel		(63,437	)		(936	)
Interest-rate contracts	Interest expense		(2,022	)		(298	)
Total gain (loss) reclassified from accumulated other comprehensive income (loss)    into net income on derivatives (effective portion)		$	30,571		$	28,643

Ineffectiveness related to our cash flow hedges was not material for the three months and six months ended June 30, 2012 and 2011.  In the event that it becomes probable that a forecasted transaction will not occur, we will discontinue cash flow hedge treatment, which will affect earnings.  For the three and six months ended June 30, 2012 and 2011, there were no gains or losses due to the discontinuance of cash flow hedge treatment as a result of the underlying transactions being no longer probable.

Other Derivative Instruments - The following table sets forth the effect of our derivative instruments that are not part of a hedging relationship in our Consolidated Statements of Income for our continuing and discontinued operations for the periods indicated:

		Three Months Ended					Six Months Ended
Derivatives Not Designated as		June 30,					June 30,
Hedging Instruments	Location of Gain (Loss)	2012		2011			2012		2011
		(Thousands of dollars)
Commodity contracts - trading	Revenues	$	491	$	(289	)	$	806	$	117
Commodity contracts - nontrading (a)	Cost of sales and fuel		1,361		7,959			4,324		10,507
Total gain recognized in income on derivatives		$	1,852	$	7,670		$	5,130	$	10,624
(a) - Amounts are presented net of deferred losses associated with derivatives entered into by our Natural Gas Distribution segment.

Our Natural Gas Distribution segment held natural gas call options with premiums totaling $6.3 million and $10.0 million at June 30, 2012, and December 31, 2011, respectively.  The premiums are recorded in other current assets as these contracts are included in, and recoverable through, the monthly purchased-gas cost mechanism.  Gains and losses associated with the change in value and expiration of these option contracts are deferred as part of our unrecovered purchase-gas costs and are not material for the three- and six-month periods ended June 30, 2012 and 2011.

Fair Value Hedges - Our Energy Services segment uses basis swaps to hedge the fair value of location price differentials related to certain firm transportation commitments.  Cost of sales and fuel in our Consolidated Statements of Income includes gains of $1.6 million and $1.1 million for the three and six months ended June 30, 2012, respectively, related to the change in fair value of derivatives designated as fair value hedges.  Revenues include losses of $2.2 million and $0.3 million for the three and six months ended June 30, 2012, respectively, to recognize the change in fair value of the related hedged firm commitments.  The ineffectiveness related to these hedges was not material for the three and six months ended June 30, 2012.

Cost of sales and fuel in our Consolidated Statements of Income includes gains of $4.2 million and $9.6 million for the three and six months ended June 30, 2011, respectively, related to the change in fair value of derivatives designated as fair value hedges.  Revenues include losses of $4.4 million and $9.4 million for the three and six months ended June 30, 2011,

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respectively, to recognize the change in fair value of the related hedged firm commitments.  The ineffectiveness related to these hedges was immaterial for the three and six months ended June 30, 2011.

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

Some of our derivative instruments contain provisions that require us to maintain an investment-grade credit rating from S&P and/or Moody’s.  If our credit ratings on senior unsecured long-term debt were to decline below investment grade, we would be in violation of these provisions, and the counterparties to the derivative instruments could request collateralization on derivative instruments in net liability positions.  The aggregate fair value of all financial derivative instruments with contingent features related to credit risk that were in a net liability position as of June 30, 2012, was $3.1 million.  If the contingent features underlying these agreements were triggered on June 30, 2012, we would have been required to post an additional $3.1 million of collateral to our counterparties.

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

The following table sets forth the net credit exposure from our derivative assets for the period indicated:

	June 30, 2012
	Investment		Noninvestment		Not
	Grade		Grade		Rated		Total
Counterparty sector	(Thousands of dollars)
Gas and electric utilities	$	17,911	$	-	$	108	$	18,019
Oil and gas		7,932		-		465		8,397
Financial		72,674		-		2		72,676
Other		-		6		395		401
Total	$	98,517	$	6	$	970	$	99,493

E.           CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE

ONEOK 2011 Credit Agreement -The ONEOK 2011 Credit Agreement, which is scheduled to expire in April 2016, contains certain financial, operational and legal covenants.  Among other things, these covenants include maintaining ONEOK’s stand-alone debt-to-capital ratio of no more than 67.5 percent at the end of any calendar quarter, limitations on the ratio of indebtedness secured by liens and indebtedness of subsidiaries to consolidated net tangible assets, a requirement that ONEOK maintains the power to control the management and policies of ONEOK Partners, and a limit on new investments in master limited partnerships.  The ONEOK 2011 Credit Agreement also contains customary affirmative and negative covenants, including covenants relating to liens, investments, fundamental changes in the nature of ONEOK’s businesses, transactions with affiliates, the use of proceeds and a covenant that limits ONEOK’s ability to restrict its subsidiaries’ ability to pay dividends.  The debt covenant calculations in the ONEOK 2011 Credit Agreement exclude the debt of ONEOK Partners.  Upon breach of certain covenants by ONEOK, amounts outstanding under the ONEOK 2011 Credit Agreement may become due and payable immediately.  At June 30, 2012, ONEOK’s stand-alone debt-to-capital ratio, as defined by the ONEOK 2011 Credit Agreement, was 50.5 percent, and ONEOK was in compliance with all covenants under the ONEOK 2011 Credit Agreement.

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Under the terms of the ONEOK 2011 Credit Agreement, ONEOK may request an increase in the size of the facility to an aggregate of $1.7 billion from $1.2 billion by either commitments from new lenders or increased commitments from existing lenders.  The ONEOK 2011 Credit Agreement is available to repay our commercial paper notes, if necessary.  Amounts outstanding under the commercial paper program reduce the borrowing capacity under the ONEOK 2011 Credit Agreement.

At June 30, 2012, ONEOK had $571.9 million of commercial paper outstanding, $1.7 million in letters of credit issued under the ONEOK 2011 Credit Agreement and approximately $22.8 million of cash and cash equivalents.  ONEOK had approximately $626.4 million of credit available at June 30, 2012, under the ONEOK 2011 Credit Agreement.

ONEOK Partners 2011 Credit Agreement - The ONEOK Partners 2011 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 2011 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 of the acquisition and the two following quarters.  Upon breach of certain covenants by ONEOK Partners in the ONEOK Partners 2011 Credit Agreement, amounts outstanding under the ONEOK Partners 2011 Credit Agreement, if any, may become due and payable immediately.  At June 30, 2012, ONEOK Partners’ ratio of indebtedness to adjusted EBITDA was 2.3 to 1, and ONEOK Partners was in compliance with all covenants under the ONEOK Partners 2011 Credit Agreement.

The ONEOK Partners 2011 Credit Agreement includes a $100-million sublimit for the issuance of standby letters of credit and also features an option to request an increase in the size of the facility to an aggregate of $1.7 billion from $1.2 billion by either commitments from new lenders or increased commitments from existing lenders.  The ONEOK Partners 2011 Credit Agreement is available to repay ONEOK Partners’ commercial paper notes, if necessary.  Amounts outstanding under the commercial paper program reduce the borrowing capacity under the ONEOK Partners 2011 Credit Agreement.  At June 30, 2012, ONEOK Partners had $24 million of commercial paper outstanding, no letters of credit issued and no borrowings under the ONEOK Partners 2011 Credit Agreement.

Effective August 1, 2012, ONEOK Partners extended the maturity date of its ONEOK Partners 2011 Credit Agreement from August 1, 2016, to August 1, 2017, pursuant to an extension agreement between ONEOK Partners and its lenders.

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.

F.           LONG-TERM DEBT

In January 2012, we completed an underwritten public offering of $700 million, 4.25-percent senior notes due 2022.  The net proceeds from the offering, after deducting underwriting discounts and offering expenses, of approximately $694.3 million were used to repay amounts outstanding under our $1.2 billion commercial paper program and for general corporate purposes.

The indenture governing ONEOK’s senior notes due 2022 includes an event of default upon the acceleration of other indebtedness of $100 million or more.  Such events of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of the outstanding senior notes due 2022 to declare those senior notes immediately due and payable in full.

ONEOK may redeem its senior notes due 2022 at a redemption price equal to the principal amount, plus accrued and unpaid interest, starting three months before the maturity date.  Prior to this date, ONEOK may redeem the senior notes due 2022, in whole or in part, at any time for a redemption price equal to the principal amount plus accrued and unpaid interest and a make-whole premium.  The redemption price will never be less than 100 percent of the principal amount of the respective note plus accrued and unpaid interest to the redemption date.  ONEOK’s senior notes due 2022 are senior unsecured obligations, ranking equally in right of payment with all of ONEOK’s existing and future unsecured senior indebtedness.

ONEOK Partners repaid its $350 million, 5.9-percent senior notes at maturity in April 2012 with a portion of the proceeds from its March 2012 equity issuance.

For the three-month periods ended June 30, 2012 and 2011, interest expense was net of capitalized interest of $9.7 million and $4.2 million, respectively.  For the six-month periods ended June 30, 2012 and 2011, interest expense was net of capitalized interest of $18.7 million and $7.4 million, respectively.

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G.           EQUITY

The following tables set 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, 2012										June 30, 2011
	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	$	2,256,152		$	2,123,303			$	4,379,455		$	2,499,084		$	1,457,934			$	3,957,018
Net income		60,993			88,212				149,205			55,142			79,624				134,766
Other comprehensive income (loss)		(26,795	)		(14,276	)			(41,071	)		3,871			11,572				15,443
Repurchase of common stock		(150,000	)		-				(150,000	)		(300,057	)		-				(300,057	)
Common stock issued		3,991			-				3,991			14,754			-				14,754
Common stock dividends		(63,397	)		-				(63,397	)		(55,705	)		-				(55,705	)
Issuance of common units of ONEOK Partners		-			(55	)			(55	)		-			-				-
Distributions to noncontrolling interests		-			(80,736	)			(80,736	)		-			(68,515	)			(68,515	)
Other		8,596			-				8,596			-			-				-
Ending balance	$	2,089,540		$	2,116,448			$	4,205,988		$	2,217,089		$	1,480,615			$	3,697,704

	Six Months Ended										Six Months Ended
	June 30, 2012										June 30, 2011
	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	$	2,238,573		$	1,561,159			$	3,799,732		$	2,448,623		$	1,472,218			$	3,920,841
Net income		183,858			198,809				382,667			185,272			148,840				334,112
Other comprehensive income (loss)		481			(712	)			(231	)		(22,464	)		(3,887	)			(26,351	)
Repurchase of common stock		(150,000	)		-				(150,000	)		(300,105	)		-				(300,105	)
Common stock issued		6,552			-				6,552			17,119			-				17,119
Common stock dividends		(126,772	)		-				(126,772	)		(111,356	)		-				(111,356	)
Issuance of common units of ONEOK Partners		(51,100	)		510,780				459,680			-			-				-
Distributions to noncontrolling interests		-			(153,588	)			(153,588	)		-			(136,556	)			(136,556	)
Other		(12,052	)		-				(12,052	)		-			-				-
Ending balance	$	2,089,540		$	2,116,448			$	4,205,988		$	2,217,089		$	1,480,615			$	3,697,704

Dividends - Dividends paid on our common stock to shareholders of record at the close of business on January 31, 2012, and April 30, 2012, each were $0.305 per share.  A dividend of $0.33 per share was declared for shareholders of record on August 6, 2012, payable August 15, 2012. Stock Repurchase Program - In June 2012, we entered into an accelerated share repurchase agreement (the ASR Agreement) with Goldman, Sachs & Co. (Goldman), pursuant to which we paid $150 million to Goldman and received from Goldman approximately 2.9 million shares of our common stock, representing approximately 80 percent of the estimated total number of shares to be repurchased.  The ASR Agreement is scheduled to end in September 2012, although the termination date may be accelerated.  We expect to receive the balance of the shares at the conclusion of the ASR Agreement.  The specific number of shares that we ultimately will repurchase will be based on the volume-weighted-average price per share of our common stock during the repurchase period, subject to other adjustments pursuant to the terms and conditions of the ASR Agreement.  At settlement, under certain circumstances, Goldman may be required to deliver additional shares of our common stock to us, or, under certain circumstances, we may be required to deliver shares of our common stock or we may elect to make a cash payment to Goldman.  We accounted for the repurchase as two separate transactions:  (i) as shares of common stock acquired in a treasury stock transaction recorded on the acquisition date; and (ii) as a forward contract indexed to ONEOK common stock that is classified as equity.

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The ASR Agreement is part of our three-year stock repurchase program that was authorized by our Board of Directors in October 2010 to buy up to $750 million of our common stock, subject to the limitation that purchases will not exceed $300 million in any one calendar year.  Following this transaction and our repurchase of $300 million in 2011, an additional $300 million may yet be purchased pursuant to our three-year repurchase program, of which a maximum of $150 million of additional shares of our common stock may be purchased in 2012.

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

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		Unrealized Holding Gains (Losses) on Investment Securities		Pension and Postretirement Benefit Plan Obligations		Accumulated Other Comprehensive Income (Loss)
		(Thousands of dollars)
December 31, 2011	$	(55,367)	$	987	$	(151,741)	$	(206,121)
Other comprehensive income (loss)    attributable to ONEOK		11,915		120		(11,554)		481
June 30, 2012	$	(43,452)	$	1,107	$	(163,295)	$	(205,640)

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, 2012
	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	$	60,726		207,292	$	0.29
Diluted EPS from continuing operations
Effect of options and other dilutive securities		-		4,492
Income from continuing operations attributable to ONEOK
available for common stock and common stock equivalents	$	60,726		211,784	$	0.29

	Three Months Ended June 30, 2011
	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	$	54,705		210,674	$	0.26
Diluted EPS from continuing operations
Effect of options and other dilutive securities		-		5,386
Income from continuing operations attributable to ONEOK
available for common stock and common stock equivalents	$	54,705		216,060	$	0.25

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	Six Months Ended June 30, 2012
	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	$	169,579		207,454	$	0.82
Diluted EPS from continuing operations
Effect of options and other dilutive securities		-		4,364
Income from continuing operations attributable to ONEOK
available for common stock and common stock equivalents	$	169,579		211,818	$	0.80

	Six Months Ended June 30, 2011
	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	$	183,774		212,358	$	0.87
Diluted EPS from continuing operations
Effect of options and other dilutive securities		-		4,852
Income from continuing operations attributable to ONEOK
available for common stock and common stock equivalents	$	183,774		217,210	$	0.85

There were no option shares excluded from the calculation of diluted EPS for the three and six months ended June 30, 2012 and 2011.

J.           EMPLOYEE BENEFIT PLANS

The following table sets forth the components of net periodic benefit cost for our pension and postretirement benefit plans for the periods indicated:

	Pension Benefits						Pension Benefits
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2012			2011			2012			2011
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	5,325		$	5,003		$	10,650		$	10,006
Interest cost		14,809			14,689			29,618			29,378
Expected return on assets		(20,689	)		(18,875	)		(41,378	)		(37,750	)
Amortization of unrecognized prior service cost		242			255			484			509
Amortization of net loss		12,111			8,927			24,222			17,855
Net periodic benefit cost	$	11,798		$	9,999		$	23,596		$	19,998

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	Postretirement Benefits						Postretirement Benefits
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2012			2011			2012			2011
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	1,240		$	1,257		$	2,477		$	2,515
Interest cost		3,473			3,958			6,946			7,916
Expected return on assets		(2,671	)		(2,568	)		(5,342	)		(5,136	)
Amortization of unrecognized net asset at adoption		718			797			1,436			1,594
Amortization of unrecognized prior service cost		(2,063	)		(501	)		(4,126	)		(1,002	)
Amortization of net loss		3,296			2,031			6,592			4,062
Net periodic benefit cost	$	3,993		$	4,974		$	7,983		$	9,949

K.           UNCONSOLIDATED AFFILIATES

Equity Earnings from Investments -The following table sets forth our equity earnings from investments for the periods indicated.  All amounts in the table below are equity earnings from investments in our ONEOK Partners segment:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2012		2011		2012		2011
	(Thousands of dollars)
Northern Border Pipeline Company	$	16,077	$	16,395	$	36,308	$	37,247
Overland Pass Pipeline		5,979		5,360		11,296		9,736
Fort Union Gas Gathering		3,195		3,711		7,403		6,676
Bighorn Gas Gathering		796		1,845		1,961		3,338
Other		3,122		2,233		6,821		4,639
Equity earnings from investments	$	29,169	$	29,544	$	63,789	$	61,636

Unconsolidated Affiliates Financial Information - The following tables set forth summarized combined financial information of our unconsolidated affiliates for the periods indicated:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2012		2011		2012		2011
	(Thousands of dollars)
Income Statement
Operating revenues	$	119,286	$	121,002	$	247,210	$	244,303
Operating expenses	$	57,727	$	51,988	$	112,295	$	106,224
Net income	$	59,812	$	59,244	$	125,066	$	122,409
Distributions paid to ONEOK Partners	$	43,254	$	38,541	$	84,195	$	71,052

L.           ONEOK PARTNERS

Equity Issuance -In March 2012, ONEOK Partners completed an underwritten public offering of 8,000,000 common units at a public offering price of $59.27 per common unit, generating net proceeds of approximately $460 million.  ONEOK Partners also sold 8,000,000 common units to us in a private placement, generating net proceeds of approximately $460 million.  In conjunction with the issuances, we contributed $19.1 million in order to maintain our 2-percent general partner interest in ONEOK Partners.  ONEOK Partners used the net proceeds from the offering to repay approximately $295 million under its $1.2 billion commercial paper program, to repay amounts on the maturity of its $350 million, 5.9-percent senior notes due April 2012 and for other general partnership purposes, including capital expenditures.  As a result of these transactions, our aggregate ownership interest in ONEOK Partners increased to 43.4 percent from 42.8 percent.

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We account for the difference between the carrying amount of our investment in ONEOK Partners and the underlying book value arising from issuance of common units by ONEOK Partners as an equity transaction.  As a result of ONEOK Partners’ issuance of common units, we recognized a decrease in paid-in capital of approximately $51.1 million in the first quarter of 2012.

Ownership Interest in ONEOK Partners - Our ownership interest in ONEOK Partners is shown in the table below as of June 30, 2012:

General partner interest	2.0%
Limited partner interest (a)	41.4%
Total ownership interest	43.4%
(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 our common and Class B units and our 2-percent general partner interest, which includes our incentive distribution rights.  Under ONEOK Partners’ partnership agreement, as amended, 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 ONEOK Partners’ partnership agreement, as amended.  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 ONEOK Partners’ partnership agreement, as amended, 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.

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2012		2011		2012		2011
	(Thousands, except per unit amounts)
Distribution per unit	$	0.635	$	0.575	$	1.245	$	1.145
General partner distributions	$	3,759	$	2,996	$	7,040	$	5,952
Incentive distributions		44,610		29,624		81,082		58,269
Distributions to general partner		48,369		32,620		88,122		64,221
Limited partner distributions to ONEOK		58,921		48,753		110,642		97,083
Limited partner distributions to noncontrolling interest		80,662		68,441		153,271		136,286
Total distributions paid	$	187,952	$	149,814	$	352,035	$	297,590

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,
	2012		2011		2012		2011
	(Thousands, except per unit amounts)
Distribution per unit	$	0.660	$	0.585	$	1.295	$	1.160
General partner distributions	$	3,979	$	3,078	$	7,738	$	6,074
Incentive distributions		49,886		31,580		94,496		61,204
Distributions to general partner		53,865		34,658		102,234		67,278
Limited partner distributions to ONEOK		61,240		49,601		120,161		98,354
Limited partner distributions to noncontrolling interest		83,838		69,631		164,500		138,072
Total distributions declared	$	198,943	$	153,890	$	386,895	$	303,704

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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 ONEOK Partners partnership agreement.  See Note N for more information on ONEOK Partners’ results.

Affiliate Transactions - We have certain transactions with ONEOK Partners and its subsidiaries, which comprise our ONEOK Partners segment.

ONEOK Partners sells natural gas from its natural gas gathering and processing operations to our Energy Services segment.  In addition, a portion of ONEOK Partners’ revenues from its natural gas pipelines business is from our Energy Services and Natural Gas Distribution segments, which contract with ONEOK Partners for natural gas transportation and storage services.  ONEOK Partners also purchases natural gas from our Energy Services segment for its natural gas liquids and its natural gas gathering and processing operations.

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.  For example, a service that applies equally to all employees is allocated based upon the number of employees in each affiliate.  However, an expense benefiting the consolidated company but having no direct basis for allocation is allocated by the modified Distrigas method, a method using a combination of ratios that include gross plant and investment, operating income and payroll expense.  It is not practicable to determine what these general overhead costs would be 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,
	2012		2011		2012		2011
	(Thousands of dollars)
Revenues	$	81,050	$	98,699	$	156,755	$	195,492
Expenses
Cost of sales and fuel	$	5,769	$	12,440	$	15,044	$	23,171
Administrative and general expenses		62,636		57,214		118,997		113,509
Total expenses	$	68,405	$	69,654	$	134,041	$	136,680

M.           COMMITMENTS AND CONTINGENCIES

Environmental Matters - We are subject to multiple historical and wildlife preservation laws and environmental regulations affecting many aspects of our present and future operations.  Regulated activities include those involving air emissions, storm water and wastewater discharges, handling and disposal of solid and hazardous wastes, hazardous materials transportation, and pipeline and facility construction.  These laws and regulations require us to obtain and 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 us to fines, penalties and/or interruptions in our operations that could be material to our results of operations.  If a leak or spill of hazardous substances or petroleum products occurs from pipelines or facilities that we own, operate or otherwise use, we could be held jointly and severally liable for all resulting liabilities, including response, investigation and cleanup costs, which could affect materially our results of operations and cash flows.  In addition, emission controls required under the Clean Air Act and other similar federal and state laws could require unexpected capital expenditures at our facilities.  We cannot assure that existing environmental regulations will not be revised or that new regulations will not be adopted or become applicable to us.  Revised or additional regulations that result in increased compliance costs or additional operating restrictions could have a material adverse effect on our business, financial condition, results of operations and cash flows.

We own or retain legal responsibility for the environmental conditions at 12 former manufactured natural gas sites in Kansas.  These sites contain potentially harmful materials that are subject to control or remediation under various environmental laws and regulations.  A consent agreement with the KDHE presently governs all work at these sites.  The terms of the consent agreement allow us to investigate these sites and set remediation activities based upon the results of the investigations and

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risk analysis.  Remediation typically involves the management of contaminated soils and may involve removal of structures and monitoring and/or remediation of groundwater.

Of the 12 sites, we have begun soil remediation on 11 sites.  Regulatory closure has been achieved at three locations, and we have completed or are near completion of soil remediation at eight sites.  We have begun site assessment at the remaining site where no active remediation has occurred.

Our expenditures for environmental evaluation, mitigation, remediation and compliance to date have not been material in relation to our financial position, results of operations or cash flows, and our expenditures related to environmental matters had no material effects on earnings or cash flows during the three and six months ended June 30, 2012 or 2011.

In May 2010, the EPA finalized the “Tailoring Rule” that will regulate greenhouse gas emissions at new or modified facilities that meet certain criteria.  Affected facilities will be required to review best available control technology, conduct air-quality analysis, impact analysis and public reviews with respect to such emissions.  The rule was phased in beginning January 2011, and at current emission threshold levels, we believe it will have a minimal impact on our existing facilities.  The EPA has stated it will consider lowering the threshold levels over the next five years, which could increase the impact on our existing facilities; however, potential costs, fees or expenses associated with the potential adjustments are unknown.

In addition, the EPA has issued a rule on air-quality standards, “National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines,” also known as RICE NESHAP, with a compliance date in 2013.  The rule will require capital expenditures over the next two years for the purchase and installation of new emissions-control equipment.  We do not expect these expenditures to have a material impact on our results of operations, financial position or cash flows.

In July 2011, the EPA issued a proposed rule that would change the air emission New Source Performance Standards, also known as NSPS, and Maximum Achievable Control Technology requirements applicable to the oil and gas industry, including natural gas production, processing, transmission and underground storage.  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 will become effective after it is published in the Federal Register.  It will require expenditures for updated emissions controls, monitoring and record keeping requirements at affected facilities.  We do not expect these expenditures to have a material impact on our results of operations, financial position or cash flows.

Pipeline Safety - We are subject to Pipeline and Hazardous Materials Safety Administration regulations, including 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 new law increased the 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 us.  These issues include but are not limited to:

·   an evaluation of whether hazardous natural gas liquid 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 liquid 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 pipelines previously untested in high-consequence areas operating above 30 percent yield strength.

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.  Various regulatory agencies, including the SEC and the CFTC, have proposed regulations for implementation of many of the provisions of the Dodd-Frank Act.  The CFTC has issued final regulations for certain provisions of the Dodd-Frank Act, but others remain outstanding.  In July 2012, the CFTC issued an order that further defers the effective date of the provisions of the Dodd-Frank Act that require a rulemaking, such as definitions of certain terms, until

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the earlier of the effective date of the final rule defining the referenced terms or December 31, 2012.  The CFTC issued the definitional rules in late May and early July 2012 that will become effective 60 days after publication in the Federal Register.  We are reviewing the rules to ascertain how we may be affected by them.  Based on our assessment of the regulations issued to date and those proposed, we expect to be able to continue to participate in financial markets for hedging certain risks inherent in our business, including commodity and interest-rate risks; however, the capital requirements and costs of hedging may increase as a result of the legislation.  We also may incur additional costs associated with our compliance with the new regulations and anticipated additional record keeping, reporting and disclosure obligations; however, we do not believe the costs will be material.  These requirements could affect adversely market liquidity and pricing of derivative contracts making it more difficult to execute our risk-management strategies in the future.  Also, the anticipated increased costs of compliance by dealers and counterparties likely will be passed on to customers, which could decrease the benefits of hedging to us and could reduce our profitability and liquidity.

Legal Proceedings - We are a party to various litigation matters and claims that have arisen in the normal course of our operations.  While the results of litigation and claims cannot be predicted with certainty, and we are unable to estimate reasonably possible losses, 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.

N.           SEGMENTS

Segment Descriptions - Our operations are divided into three reportable business segments as follows:

·   our ONEOK Partners segment reflects the consolidated operations of ONEOK Partners.  We own a 43.4-percent ownership interest and control ONEOK Partners through our ownership of its general partner interest.  ONEOK Partners gathers, processes, treats, transports, stores and sells natural gas and gathers, treats, fractionates, stores, distributes and markets NGLs.  We and ONEOK Partners maintain significant financial and corporate governance separations.  We seek to receive increasing cash distributions as a result of our investment in ONEOK Partners, and our investment decisions are made based on the anticipated returns from ONEOK Partners in total, not specific to any of its businesses individually;

·   our Natural Gas Distribution segment is comprised of our regulated public utilities that deliver natural gas to residential, commercial and industrial customers, and transport natural gas; and

·   our Energy Services segment markets natural gas to wholesale customers.

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

Accounting Policies - The accounting policies of the segments are the same as those described in Note A of the Notes to Consolidated Financial Statements in our Annual Report.  Intersegment sales are recorded on the same basis as sales to unaffiliated customers and are discussed in further detail in Note L.  Net margin is comprised of total revenues less cost of sales and fuel.  Cost of sales and fuel includes commodity purchases, fuel, and storage and transportation costs.

Customers - For the three and six months ended June 30, 2012, and the six months ended June 30, 2011, we had no single external customer from which we received 10 percent or more of our consolidated gross revenues.  For the three months ended June 30, 2011, our ONEOK Partners segment had one single customer from which it received 10 percent of our consolidated gross revenues.

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

Three Months Ended June 30, 2012	ONEOK Partners (a)		Natural Gas Distribution		Energy Services			Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	2,043,756	$	221,181	$	263,897		$	426		$	2,529,260
Intersegment revenues		81,050		2		5,028			(86,080	)		-
Total revenues	$	2,124,806	$	221,183	$	268,925		$	(85,654	)	$	2,529,260
Net margin	$	401,462	$	157,488	$	(10,412	)	$	424			548,962
Operating costs		123,364		103,774		4,626			(501	)		231,263
Depreciation and amortization		51,014		31,999		77			1,496			84,586
Gain on sale of assets		966		-		-			-			966
Operating income	$	228,050	$	21,715	$	(15,115	)	$	(571	)	$	234,079
Equity earnings from investments	$	29,169	$	-	$	-		$	-		$	29,169
Capital expenditures	$	355,443	$	72,917	$	-		$	3,900		$	432,260
(a) - Our ONEOK Partners segment has regulated and nonregulated operations. Our ONEOK Partners segment’s regulated operations had revenues of $160.2 million, net margin of $100.6 million and operating income of $54.1 million.

Three Months Ended June 30, 2011	ONEOK Partners (a)			Natural Gas Distribution		Energy Services			Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	2,685,520		$	253,917	$	504,756		$	605		$	3,444,798
Intersegment revenues		98,699			3,065		111,273			(213,037	)		-
Total revenues	$	2,784,219		$	256,982	$	616,029		$	(212,432	)	$	3,444,798
Net margin	$	359,540		$	159,141	$	(433	)	$	585		$	518,833
Operating costs		113,581			104,516		5,298			214			223,609
Depreciation and amortization		43,714			34,436		111			532			78,793
Loss on sale of assets		(212	)		-		-			-			(212	)
Operating income	$	202,033		$	20,189	$	(5,842	)	$	(161	)	$	216,219
Equity earnings from investments	$	29,544		$	-	$	-		$	-		$	29,544
Capital expenditures	$	265,333		$	61,899	$	3		$	1,858		$	329,093
(a) - Our ONEOK Partners segment has regulated and nonregulated operations. Our ONEOK Partners segment’s regulated operations had revenues of $153.0 million, net margin of $113.2 million and operating income of $53.5 million.

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Six Months Ended June 30, 2012	ONEOK Partners (a)		Natural Gas Distribution		Energy Services			Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	4,562,139	$	738,104	$	642,595		$	1,022		$	5,943,860
Intersegment revenues		156,755		843		87,138			(244,736	)		-
Total revenues	$	4,718,894	$	738,947	$	729,733		$	(243,714	)	$	5,943,860
Net margin	$	822,552	$	394,836	$	(25,858	)	$	1,019		$	1,192,549
Operating costs		239,234		208,760		9,465			(2,138	)		455,321
Depreciation and amortization		100,270		65,519		206			2,000			167,995
Goodwill impairment		-		-		10,255			-			10,255
Gain on sale of assets		1,023		-		-			-			1,023
Operating income	$	484,071	$	120,557	$	(45,784	)	$	1,157		$	560,001
Equity earnings from investments	$	63,789	$	-	$	-		$	-		$	63,789
Investments in unconsolidated    affiliates	$	1,210,268	$	-	$	-		$	-		$	1,210,268
Total assets	$	9,376,537	$	3,153,679	$	549,623		$	737,352		$	13,817,191
Noncontrolling interests in    consolidated subsidiaries	$	5,028	$	-	$	-		$	2,111,420		$	2,116,448
Capital expenditures	$	636,236	$	131,365	$	-		$	13,096		$	780,697
(a) - Our ONEOK Partners segment has regulated and nonregulated operations. Our ONEOK Partners segment’s regulated operations had revenues of $331.4 million, net margin of $223.5 million and operating income of $118.7 million.

Six Months Ended June 30, 2011	ONEOK Partners (a)			Natural Gas Distribution		Energy Services		Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	5,088,337		$	933,324	$	1,182,556	$	1,181		$	7,205,398
Intersegment revenues		195,492			7,840		325,212		(528,544	)		-
Total revenues	$	5,283,829		$	941,164	$	1,507,768	$	(527,363	)	$	7,205,398
Net margin	$	689,094		$	402,875	$	55,516	$	1,225		$	1,148,710
Operating costs		222,324			209,213		13,302		451			445,290
Depreciation and amortization		86,444			70,383		259		1,064			158,150
Loss on sale of assets		(722	)		-		-		-			(722	)
Operating income	$	379,604		$	123,279	$	41,955	$	(290	)	$	544,548
Equity earnings from investments	$	61,636		$	-	$	-	$	-		$	61,636
Investments in unconsolidated    affiliates	$	1,177,219		$	-	$	-	$	-		$	1,177,219
Total assets	$	8,642,136		$	3,134,134	$	559,976	$	700,087		$	13,036,333
Noncontrolling interests in    consolidated subsidiaries	$	5,185		$	-	$	-	$	1,475,430		$	1,480,615
Capital expenditures	$	410,159		$	109,049	$	3	$	4,561		$	523,772
(a) - Our ONEOK Partners segment has regulated and nonregulated operations. Our ONEOK Partners segment’s regulated operations had revenues of $308.5 million, net margin of $229.1 million and operating income of $113.1 million.

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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.  Due to the seasonal nature of our business, the results of operations for the three and six months ended June 30, 2012, are not necessarily indicative of the results that may be expected for a 12-month period.

RECENT DEVELOPMENTS

Growth Projects - Oil and gas producers continue to drill aggressively in crude oil and NGL-rich areas, and related development activities continue to progress in many regions where ONEOK Partners has operations.  ONEOK Partners expects continued development of the oil and natural gas reserves in the Bakken Shale and Three Forks formations in the Williston Basin and in the Cana-Woodford Shale, Woodford Shale, Granite Wash and Mississippian Lime 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 $5.7 billion to $6.6 billion in new capital projects, which includes additional projects announced in July 2012, to meet the needs of oil and natural gas producers and processors in the Bakken Shale, the Cana-Woodford Shale, Woodford Shale, and the Granite Wash and Mississippian Lime areas.  In addition, ONEOK Partners is investing in NGL infrastructure projects in the Rocky Mountain, Mid-Continent and Gulf Coast regions.  These assets will enhance ONEOK Partners’ ability to distribute NGL products to meet the increasing petrochemical industry and NGL export demand.  The execution of these capital investments aligns with ONEOK Partners’ focus to grow fee-based earnings.  Acreage dedications and supply commitments from producers and natural gas processors in regions associated with ONEOK Partners’ growth projects will provide incremental and long-term fee-based earnings and cash flows.

In July 2012, ONEOK Partners announced plans to invest an additional $980.0 million to $1.1 billion through 2014 to:

·   Build a new 100 MMcf/d natural gas processing facility, the Garden Creek II plant, in eastern McKenzie County, North Dakota, in the Williston Basin, and related infrastructure;

·   Increase capacity on the Bakken NGL Pipeline to 135 MBbl/d from 60 MBbl/d;

·   Build a new 75 MBbl/d natural gas liquids fractionator, MB-3, at Mont Belvieu, Texas, and related infrastructure; and

·   Build a new 40 MBbl/d Ethane/Propane splitter at Mont Belvieu, Texas.

See discussion of these projects and other ONEOK Partners’ growth projects in the “Financial Results and Operating Information” section for our ONEOK Partners segment.

Dividends/Distributions - We declared a quarterly dividend of $0.33 per share ($1.32 per share on an annualized basis) in July 2012.  A cash distribution from ONEOK Partners of $0.66 per unit ($2.64 per unit on an annualized basis) was declared in July 2012 for the second quarter of 2012, an increase of 2.5 cents from the previous quarter.  The quarterly dividend and distribution payments will be made August 15, 2012, to shareholders and unitholders of record at the close of business on August 6, 2012.

Stock Split - In June 2012, we completed our previously announced two-for-one split of our common stock.  The two-for-one split was effected by a distribution on June 1, 2012, of one share of stock for each share outstanding and held by shareholders of record on May 24, 2012.  We have adjusted all share and per-share amounts contained herein, to be presented on a post-split basis.

Retail Marketing Sale - On February 1, 2012, we sold ONEOK Energy Marketing Company, our retail natural gas marketing business, to Constellation Energy Group, Inc. for $22.5 million plus working capital.  We received net proceeds of approximately $32.9 million and recognized an after-tax gain on the sale of approximately $13.5 million.  The proceeds from the sale were used to reduce short-term borrowings.  The financial information of ONEOK Energy Marketing Company is reflected as discontinued operations in this Quarterly Report.  All prior periods presented have been recast to reflect the discontinued operations.

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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,						2012 vs. 2011					2012 vs. 2011
Financial Results	2012			2011			2012			2011			Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
Revenues	$	2,529.3		$	3,444.8		$	5,943.9		$	7,205.4		$	(915.5	)	(27	%)	$	(1,261.5	)	(18	%)
Cost of sales and fuel		1,980.3			2,926.0			4,751.4			6,056.7			(945.7	)	(32	%)		(1,305.3	)	(22	%)
Net margin		549.0			518.8			1,192.5			1,148.7			30.2		6	%		43.8		4	%
Operating costs		231.3			223.6			455.3			445.3			7.7		3	%		10.0		2	%
Depreciation and amortization		84.6			78.8			168.0			158.2			5.8		7	%		9.8		6	%
Goodwill impairment		-			-			10.3			-			-			-		10.3		100	%
Gain (loss) on sale of assets		1.0			(0.2	)		1.1			(0.7	)		1.2			*		1.8			*
Operating income	$	234.1		$	216.2		$	560.0		$	544.5		$	17.9		8	%	$	15.5		3	%
Interest expense	$	(71.5	)	$	(75.5	)	$	(147.4	)	$	(154.8	)	$	(4.0	)	(5	%)	$	(7.4	)	(5	%)
Net income	$	149.2		$	134.8		$	382.7		$	334.1		$	14.4		11	%	$	48.6		15	%
Net income attributable to    noncontrolling interests	$	88.2		$	79.6		$	198.8		$	148.8		$	8.6		11	%	$	50.0		34	%
Net income attributable to ONEOK	$	61.0		$	55.1		$	183.9		$	185.3		$	5.9		11	%	$	(1.4	)	(1	%)
Capital expenditures	$	432.3		$	329.1		$	780.7		$	523.8		$	103.2		31	%	$	256.9		49	%
* Percentage change is greater than 100 percent.

Revenues decreased for the three and six months ended June 30, 2012, compared with the same periods last year, due to lower natural gas and NGL product prices, offset partially by higher NGL sales volumes from ONEOK Partners’ completed capital projects and more favorable NGL price differentials.  The increase in natural gas supply resulting from the development of resource areas in North America has caused lower natural gas prices and narrower natural gas location and seasonal price differentials in the markets it serves.  NGL prices also have decreased in 2012 due primarily to increased NGL supply from the development of NGL-rich resource areas and lower NGL demand during the second quarter of 2012 because of scheduled maintenance at Gulf Coast petrochemical plants, as well as lower crude oil prices.

Operating income for the three-month period reflects higher results from our ONEOK Partners and Natural Gas Distribution segments, offset by lower results from our Energy Services segment.  The six-month period reflects higher results from our ONEOK Partners segment, offset by significantly lower results from our Energy Services segment and slightly lower results from our Natural Gas Distribution segment.

For the three and six month periods, our ONEOK Partners segment’s operating income increased due primarily to higher natural gas and NGL sales volumes from its completed capital projects, including the startup of the new Garden Creek natural gas processing plant in the Williston Basin in December 2011 and more favorable NGL price differentials, offset partially by lower natural gas and NGL product prices in its natural gas gathering and processing business.

For the three-month period, our Natural Gas Distribution segment’s operating income increased 6 percent, compared with the same period last year, due primarily to new rates and surcharge recoveries in Texas and Kansas.  Our Natural Gas Distribution segment’s operating income decreased 2 percent for the six months ended June 30, 2012, compared with the same period last year, due primarily to higher depreciation expense from new capital investments, which include its investment in automated meter reading, and reduced transportation margins due to warmer weather, offset partially by new rates and surcharge recoveries in Texas and Kansas.

Our Energy Services segment’s operating income decreased for the three months ended June 30, 2012, compared with the same periods last year, due primarily to lower transportation and premium services margins.  During the six-month period, the continued decline in natural gas prices resulted in a required $29.9 million reclassification of deferred losses from accumulated other comprehensive income into earnings on certain financial contracts, a $10.3 million goodwill impairment charge, lower realized seasonal storage price differentials, lower transportation margins and decreases due to unrealized fair value changes on nonqualifying economic hedges in our Energy Services segment.

Interest expense decreased for the three and six months ended June 30, 2012, compared with the same periods last year, primarily as a result of interest capitalized associated with ONEOK Partners’ growth projects, offset partially by interest costs from ONEOK’s $700 million debt issuance in January 2012.

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Net income attributable to noncontrolling interests for the three and six months ended June 30, 2012 and 2011, reflects primarily the portion of ONEOK Partners that we do not own and the increase reflects higher earnings in our ONEOK Partners segment during 2012.

Capital expenditures increased for the three and six months ended June 30, 2012, compared with the same periods last year, due primarily to the growth projects in ONEOK Partners’ natural gas gathering and processing and natural gas liquids businesses.

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

ONEOK Partners

Overview - ONEOK Partners is a diversified master limited partnership involved in the gathering, processing, storage and transportation of natural gas in the United States.  In addition, ONEOK Partners owns one of the nation’s premier natural gas liquids systems, connecting NGL supply in the Mid-Continent and Rocky Mountain regions with key market centers.

We own approximately 92.8 million common and Class B limited partner units, and the entire 2-percent general partner interest, which, together, represent a 43.4-percent ownership interest in ONEOK Partners.  We receive distributions from ONEOK Partners on our common and Class B units and our 2-percent general partner interest, which includes our incentive distribution rights.  See Note L of the Notes to Consolidated Financial Statements in this Quarterly Report for discussion of our incentive distribution rights.

We and ONEOK Partners maintain significant financial and corporate governance separations.  We seek to receive increasing cash distributions as a result of our investment in ONEOK Partners, and our investment decisions are made based on the anticipated returns from ONEOK Partners in total, not specific to any of ONEOK Partners’ businesses individually.  To aid in understanding the important business and financial characteristics of our ONEOK Partners segment, the following describes its business with reference to its underlying activities.

Natural gas gathering and processing business - ONEOK Partners’ natural gas gathering and processing business provides nondiscretionary services to producers that include gathering and processing of natural gas produced from crude oil and natural gas wells.  ONEOK Partners gathers and processes natural gas in the Mid-Continent region, which includes the NGL-rich Cana-Woodford Shale and Granite Wash formations; 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.  In the Powder River Basin, the natural gas that ONEOK Partners gathers is coal-bed methane, or dry, natural gas that 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.

Natural gas pipelines business - ONEOK Partners’ natural gas pipeline business owns and operates regulated natural gas transmission pipelines, natural gas storage facilities and natural gas gathering systems for unprocessed natural gas.  ONEOK Partners also provides interstate natural gas transportation and storage services in accordance with Section 311(a) of the Natural Gas Policy Act.

ONEOK Partners’ FERC-regulated interstate assets transport natural gas through pipelines that access supply from Canada and from the Mid-Continent, Rocky Mountain and Gulf Coast regions.  ONEOK Partners’ intrastate natural gas pipeline assets are located in Oklahoma, Texas and Kansas, and have access to major natural gas producing areas in those states.  ONEOK Partners owns underground natural gas storage facilities in Oklahoma, Kansas and Texas.

Natural gas liquids business - ONEOK Partners’ natural gas liquids business gathers, treats, fractionates, stores and transports NGLs and distributes and stores NGL products.  ONEOK Partners’ natural gas liquids gathering pipelines deliver unfractionated NGLs gathered from natural gas processing plants located in Oklahoma, Kansas, Texas and the Rocky Mountain region to fractionators it owns in Oklahoma, Kansas and Texas, as well as to third-party fractionators and pipelines.  The NGLs are then separated through the fractionation process into the individual NGL products that realize the greater economic value of the NGL components.  The individual NGL products are then stored or distributed to petrochemical manufacturers, heating-fuel users, refineries and propane distributors through ONEOK Partners’ FERC-regulated distribution pipelines that move NGL products from Oklahoma and Kansas to the Mid-Continent and Gulf Coast NGL market centers, as well as the Midwest markets near Chicago, Illinois.

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Growth Projects - Bakken Crude Express Pipeline - In April 2012, ONEOK Partners announced plans to invest $1.5 billion to $1.8 billion to build a 1,300-mile crude-oil pipeline, the Bakken Crude Express Pipeline, with the capacity to transport 200 MBbl/d.  The Bakken Crude Express Pipeline will transport light-sweet crude oil primarily from the Bakken Shale and Three Forks formations in the Williston Basin in North Dakota to the Cushing, Oklahoma, market hub.

ONEOK Partners is the largest independent gatherer and processor of natural gas in the Williston Basin and currently is constructing a natural gas liquids pipeline, the Bakken NGL Pipeline, to provide needed transportation capacity for the growing NGL production in the area.  The development of the Bakken Crude Express Pipeline is a natural extension to the suite of midstream services that ONEOK Partners currently provides to producers in the Williston Basin and is expected to generate additional fee-based earnings.  Additional crude-oil infrastructure is needed due to the continued crude-oil production growth that is expected to exceed the area’s current truck and railcar transportation capacity.  ONEOK Partners’ proposed pipeline will provide producers with efficient and reliable transportation capacity directly to one of the largest crude-oil market hubs in the U.S. and will enable producers to maintain the quality of the light-sweet crude oil during transportation.

Depending upon supply commitments received prior to construction, the capacity of this pipeline can be increased.  More than 80 percent of the proposed pipeline route is expected to parallel ONEOK Partners’ existing and planned natural gas liquids pipelines.  Supply commitments for the proposed pipeline are in various stages of negotiation with many of the same producers and natural gas processors that ONEOK Partners serves currently.  Following receipt of all necessary permits and compliance with customary regulatory requirements, construction is expected to begin in late 2013 or early 2014 and be completed by early 2015.

Natural gas gathering and processing projects - ONEOK Partners’ natural gas gathering and processing business is investing approximately $1.8 billion to $1.9 billion in growth projects in the Williston Basin and Cana-Woodford Shale areas that will enable ONEOK Partners to meet the rapidly growing needs of crude oil and natural gas producers in those areas.

Williston Basin Processing Plants and related projects - In July 2012, ONEOK Partners announced plans to invest approximately $310 to $345 million to construct the 100 MMcf/d Garden Creek II natural gas processing plant and related infrastructure.  The Garden Creek II plant is expected to be in service during the third quarter of 2014.  Combined, ONEOK Partners’ projects in this basin include four 100 MMcf/d natural gas processing facilities:  the Garden Creek and Garden Creek II plants located in eastern McKenzie County, North Dakota, and the Stateline I and II plants located in western Williams County, North Dakota.  ONEOK Partners has acreage dedications of more than 2.7 million acres supporting these plants.  In addition, ONEOK Partners is expanding and upgrading its existing natural gas gathering and compression infrastructure and also adding new well connections associated with these plants.  The Garden Creek plant was placed in service in December 2011 and cost approximately $360 million, excluding AFUDC.  Together, the Stateline I and II plants and related infrastructure projects are expected to cost approximately $560 million to $660 million, excluding AFUDC.  The 100 MMcf/d Stateline I natural gas processing facility is expected to be in service during the third quarter of 2012, and the 100 MMcf/d Stateline II natural gas processing facility is expected to be in service during the first half of 2013.

ONEOK Partners also announced in April 2012 plans to invest $140 million to $160 million to construct a 270-mile natural gas gathering system and related infrastructure in Divide County, North Dakota.  The new system will gather and deliver natural gas from producers in the Williston Basin to both of ONEOK Partners’ Stateline natural gas processing facilities in western Williams County, North Dakota.  ONEOK Partners has secured long-term supply commitments from producers for this new system, which are structured with POP and fee-based components.  This project is expected to be completed in the second half of 2013.

Horizontal wells drilled in the Williston Basin are justified primarily by crude-oil economics, which are currently very favorable.  In addition, ONEOK Partners expects its commodity price exposure to increase, particularly to NGLs and natural gas, as equity volumes increase under its POP contracts with its customers in the Williston Basin.

Cana Woodford Shale projects - In April 2012, ONEOK Partners announced plans to invest approximately $340 million to $360 million to construct a new 200 MMcf/d natural gas processing facility and related infrastructure in the Cana-Woodford Shale in Canadian County, Oklahoma, in close proximity to its existing natural gas and natural gas liquids pipelines.  The additional natural gas processing infrastructure is necessary to accommodate increased production of NGL-rich natural gas in the Cana-Woodford Shale where ONEOK Partners has substantial acreage dedications from active producers.  The new Canadian Valley plant will cost approximately $190 million, excluding AFUDC, and is expected to be in service in the first quarter 2014.  The related additional infrastructure will cost approximately $160 million, excluding AFUDC, and is expected to increase ONEOK Partners’ capacity to gather and process natural gas to approximately 390 MMcf/d in the Cana-Woodford Shale.

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In both the Williston Basin and Cana-Woodford Shale project areas, nearly all of the new gas production is from horizontally drilled and completed wells.  These wells tend to produce at higher initial volumes 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-lasting reserves.  ONEOK Partners expects the routine growth capital needed to connect to new wells and expand its infrastructure to increase compared with its previous experience.

Natural gas liquids projects - The growth strategy in ONEOK Partners’ natural gas liquids business is focused around the oil and NGL-rich natural gas drilling activity in shale and other 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 required ONEOK Partners to make additional capital investments in 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 over the next five years, and international demand for propane is expected to impact the NGL market in the future.  ONEOK Partners’ natural gas liquids business is investing approximately $2.4 billion to $2.9 billion in NGL-related projects through 2014.  These investments will accommodate the transportation and fractionation of growing NGL supplies from the shale and other resource areas across ONEOK Partners’ asset base and alleviate infrastructure constraints between the Mid-Continent and Texas Gulf Coast regions to meet the increasing petrochemical industry and NGL export demand in the Gulf Coast.  Over time, these growing fee-based NGL volumes will fill a portion of the capacity used to capture the NGL price differentials between the two market centers.  In addition, we believe the NGL price differentials between the Mid-Continent and Gulf Coast market centers will narrow over the long term as new fractionators and pipelines, including ONEOK Partners’ growth projects discussed below, begin to alleviate constraints affecting NGL prices and location price differentials between the two market centers.

Sterling III Pipeline - ONEOK Partners plans to build a 570-plus-mile natural gas liquids pipeline, the Sterling III Pipeline, which will have the flexibility to transport either unfractionated NGLs or NGL products from the Mid-Continent to the Texas Gulf Coast.  The Sterling III Pipeline will traverse the NGL-rich Woodford Shale that is currently under development, as well as provide transportation capacity for the growing NGL production from the Cana-Woodford Shale and Granite Wash areas, where the pipeline can gather unfractionated NGLs from the new natural gas processing plants that are being built as a result of increased drilling activity in these areas.  The Sterling III Pipeline will have an initial capacity to transport up to 193 MBbl/d of production from ONEOK Partners’ natural gas liquids infrastructure at 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.  Additional pump stations could expand the capacity of the pipeline to 250 MBbl/d.  Following the receipt of all necessary permits and the acquisition of rights-of-way, construction is scheduled to begin in 2013, with an expected completion late in the same year.

The investment also includes reconfiguring its existing Sterling I and II pipelines, which currently distribute NGL products between the Mid-Continent and Gulf Coast NGL market centers, to transport either unfractionated NGLs or NGL products.

The project costs for the new pipeline and reconfiguring projects are estimated to be $610 million to $810 million, excluding AFUDC.

MB-2 Fractionator - ONEOK Partners is constructing a 75-MBbl/d fractionator, MB-2, near its storage facility in Mont Belvieu, Texas.  The Texas Commission on Environmental Quality (TCEQ) approved the permit application to build this fractionator.  Construction began in June 2011 and is expected to be completed in the third quarter of 2013.  The cost of the new fractionator is estimated to be $300 million to $390 million, excluding AFUDC.  ONEOK Partners has multi-year supply commitments from producers and natural gas processors for all of the fractionator’s capacity.

MB-3 Fractionator - In July 2012, ONEOK Partners announced plans to construct a new 75 MBbl/d fractionator, MB-3, 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 the Arbuckle and Sterling II NGL pipelines.  The MB-3 fractionator and related infrastructure are expected to cost approximately $525 million to $575 million, excluding AFUDC.  The MB-3 fractionator is expected to be completed in the fourth quarter of 2014.  Supply commitments from third-party natural gas processors are in various stages of negotiation.

Ethane/Propane Splitter - In July 2012, ONEOK Partners announced plans to construct a new 40 MBbl/d ethane/propane splitter at its Mont Belvieu storage facility to split ethane/propane mix into purity ethane in order to meet the growing needs of petrochemical-industry customers.  The facility will be capable of producing 32 MBbl/d of purity ethane and 8 MBbl/d of propane and is expected to be in service during the second quarter of 2014.  The ethane/propane splitter is expected to cost approximately $45 million, excluding AFUDC.

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Bakken NGL Pipeline and related projects - ONEOK Partners is building a 525- to 615-mile natural gas liquids pipeline, the Bakken NGL Pipeline, to transport unfractionated NGLs from the Williston Basin to the Overland Pass Pipeline.  In July 2012, ONEOK Partners announced plans to invest an additional $100 million to install additional pump stations on the Bakken NGL Pipeline to increase its capacity to 135 MBbl/d from an initial capacity of 60 MBbl/d.  The unfractionated NGLs will then be delivered to ONEOK Partners’ existing natural gas liquids fractionation and distribution infrastructure in the Mid-Continent.  Project costs for the new pipeline, including the expansion, are estimated to be $550 million to $650 million, excluding AFUDC.  NGL supply commitments for the Bakken NGL Pipeline will be anchored by NGL production from ONEOK Partners’ natural gas processing plants and third-party natural gas processors in the Williston Basin.  The 12-inch diameter pipeline is expected to be in service during the first half of 2013, and the expansion is expected to be completed in the third quarter of 2014.

The unfractionated NGLs from the Bakken NGL Pipeline and other supply sources under development in the Rocky Mountain region will require installing additional pump stations and expanding existing pump stations on the Overland Pass Pipeline in which ONEOK Partners owns a 50-percent equity interest.  These additions and expansions will increase the capacity of Overland Pass Pipeline to 255 MBbl/d.  ONEOK Partners’ share of the costs for this project is estimated to be $35 million to $40 million, excluding AFUDC.

Bushton Fractionator expansion - To accommodate the additional volumes from the Bakken NGL Pipeline, ONEOK Partners is investing $110 million to $140 million, excluding AFUDC, to expand and upgrade its existing fractionation capacity at Bushton, Kansas, increasing its capacity to 210 MBbl/d from 150 MBbl/d.  This project is expected to be in service during the fourth quarter of 2012.

Cana-Woodford Shale and Granite Wash projects - ONEOK Partners has constructed approximately 230 miles of natural gas liquids pipelines that have expanded its existing Mid-Continent natural gas liquids gathering system in the Cana-Woodford Shale and Granite Wash areas.  These pipelines have expanded ONEOK Partners’ capacity to transport unfractionated NGLs from these Mid-Continent supply areas to fractionation facilities in Oklahoma and Texas and distribute NGL products to the Mid-Continent, Gulf Coast and upper Midwest market centers.  The pipelines are connected to three new third-party natural gas processing facilities and to three existing third-party natural gas processing facilities that have been expanded.  Additionally, ONEOK Partners has installed additional pump stations on the Arbuckle Pipeline to increase its capacity to 240 MBbl/d.  These projects are expected to add, through multi-year supply contracts, approximately 75 to 80 MBbl/d of unfractionated NGLs, to ONEOK Partners’ existing natural gas liquids gathering systems.  These projects were placed in service in April 2012 and cost approximately $220 million, excluding AFUDC.

Sterling I Pipeline expansion - In 2011, ONEOK Partners installed seven additional pump stations at a cost of approximately $30 million, excluding AFUDC, along its existing Sterling I natural gas liquids distribution pipeline, increasing its capacity by 15 MBbl/d, which is supplied by ONEOK Partners’ Mid-Continent natural gas liquids infrastructure.  The Sterling I Pipeline transports NGL products from ONEOK Partners’ fractionator in Medford, Oklahoma, to the Mont Belvieu, Texas, market center.

For a discussion of ONEOK Partners’ capital expenditure financing, see “Capital Expenditures” in “Liquidity and Capital Resources” on page 55.

Selected Financial Results and Operating Information - The following table sets forth certain selected financial results for our ONEOK Partners segment for the periods indicated:

	Three Months Ended					Six Months Ended					Three Months					Six Months
	June 30,					June 30,					2012 vs. 2011					2012 vs. 2011
Financial Results	2012		2011			2012		2011			Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
Revenues	$	2,124.8	$	2,784.2		$	4,718.9	$	5,283.8		$	(659.4	)	(24	%)	$	(564.9	)	(11	%)
Cost of sales and fuel		1,723.3		2,424.7			3,896.3		4,594.7			(701.4	)	(29	%)		(698.4	)	(15	%)
Net margin		401.5		359.5			822.6		689.1			42.0		12	%		133.5		19	%
Operating costs		123.4		113.6			239.2		222.3			9.8		9	%		16.9		8	%
Depreciation and amortization		51.0		43.7			100.3		86.4			7.3		17	%		13.9		16	%
Gain (loss) on sale of assets		1.0		(0.2	)		1.0		(0.8	)		1.2			*		1.8			*
Operating income	$	228.1	$	202.0		$	484.1	$	379.6		$	26.1		13	%	$	104.5		28	%
Capital expenditures	$	355.4	$	265.3		$	636.2	$	410.2		$	90.1		34	%	$	226.0		55	%
* Percentage change is greater than 100 percent.

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Revenues decreased for the three and six months ended June 30, 2012, compared with the same periods last year, due to lower natural gas and NGL product prices, offset partially by higher NGL sales volume from our completed capital projects and more favorable NGL price differentials.

The differential between the composite price of NGL products and the price of natural gas, particularly the differential between the price of ethane and the price of natural gas, may influence the volume of NGLs recovered from natural gas processing plants.  When economic conditions warrant, natural gas processors may elect not to recover the ethane component of the natural gas stream, also known as ethane rejection, and instead leave the ethane component in the higher value residue natural gas stream sold at the tailgate of natural gas processing plants.  Low commodity prices have resulted in periods of ethane rejection in the Mid-Continent region during 2012.  Ethane rejection did not have a material impact on our results for the three months ended June 30, 2012.

Net margin increased for the three months ended June 30, 2012, compared with the same period last year, due primarily to the following:

·   an increase of $25.7 million due primarily to volume growth in the Williston Basin from the new Garden Creek natural gas processing plant and increased drilling activity resulting in higher natural gas volumes gathered, compressed, processed, transported and sold, and higher fees, offset partially by lower natural gas volumes gathered as a result of continued production decline rates and reduced drilling activity in the Powder River Basin in ONEOK Partners’ natural gas gathering and processing business;

·   an increase of $18.0 million related to higher NGL volumes gathered in the Mid-Continent and Rocky Mountain regions, and Texas, higher NGL volumes fractionated in the Mid-Continent region and contract renegotiations for higher fees associated with ONEOK Partners’ NGL exchange services activities, offset partially by lower volumes fractionated in Texas due to scheduled maintenance in May 2012 at its Mont Belvieu fractionation facility in its natural gas liquids business;

·   an increase of $10.9 million in optimization and marketing margins, which resulted from a $24.8 million increase from more favorable NGL price differentials and additional transportation capacity available for optimization activities from ONEOK Partners’ completed expansions of the Arbuckle and Sterling I pipelines that enabled the increased transportation of NGLs between the Conway, Kansas, and Mont Belvieu, Texas, NGL market centers.  This increase was offset partially by a $13.8 million decrease due primarily to lower NGL product sales and higher NGL inventory held as a result of the scheduled maintenance of its Mont Belvieu fractionation facility.  ONEOK Partners expects to fractionate the NGL inventory and realize margins resulting from the physical-forward sale of this inventory by the end of 2012;

·   an increase of $6.0 million due to higher storage margins as a result of contract renegotiations at higher fees in ONEOK Partners’ natural gas liquids business; and

·   an increase of $1.6 million related to higher isomerization margins resulting from wider price differentials between normal butane and iso-butane, offset partially by lower isomerization volumes in ONEOK Partners’ natural gas liquids business; offset partially by

·   a decrease of $10.1 million due to lower natural gas and NGL product prices, particularly ethane and propane, offset partially by higher condensate prices in ONEOK Partners’ natural gas gathering and processing business;

·   a decrease of $8.6 million due primarily to higher compression costs and third-party transportation and processing costs associated with our volume growth primarily in the Williston Basin in ONEOK Partners’ natural gas gathering and processing business; and

·   a decrease of $2.2 million due to the impact of operational measurement losses in ONEOK Partners’ natural gas liquids business.

Net margin increased for the six months ended June 30, 2012, compared with the same period last year, due primarily to the following:

·   an increase of $71.2 million in optimization and marketing margins, which resulted from a $84.8 million increase from optimization margins in ONEOK Partners’ natural gas liquids business due primarily to favorable NGL price differentials and additional fractionation and transportation capacity available for optimization activities made available by ONEOK Partners’ 60 MBbl/d fractionation-services agreement with Targa Resources Partners that began in the second quarter 2011 and completed expansions of the Arbuckle and Sterling I pipelines that enabled the increased transportation of NGLs between the Conway, Kansas, and Mont Belvieu, Texas, NGL market centers.  This increase was offset partially by a decrease of $13.8 million due primarily to lower NGL product sales and higher NGL inventory held as a result of the scheduled maintenance of its Mont Belvieu fractionation facility.  ONEOK Partners expects to fractionate the NGL inventory and realize margins resulting from the physical-forward sale of this inventory by the end of 2012;

·   an increase of $52.9 million due primarily to volume growth in the Williston Basin from our new Garden Creek natural gas processing plant and increased drilling activity resulting in higher natural gas volumes gathered, compressed, processed, transported and sold, and higher fees, offset partially by lower natural gas volumes gathered

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as a result of continued production declines and reduced drilling activity by producers in the Powder River Basin in ONEOK Partners’ natural gas gathering and processing business;

·   an increase of $35.8 million from higher NGL volumes gathered and fractionated in Texas and the Mid-Continent and Rocky Mountain regions, and contract renegotiations for higher fees associated with ONEOK Partners’ NGL exchange services activities, offset partially by higher costs associated with NGL volumes fractionated by third parties in its natural gas liquids business;

·   an increase of $8.7 million due to higher storage margins as a result of contract renegotiations at higher fees in ONEOK Partners’ natural gas liquids business; and

·   an increase of $4.2 million due to the impact of operational measurement gains of approximately $1.1 million in the first six months of 2012, compared with a loss of approximately $5.3 million in the same period last year, in ONEOK Partners’ natural gas liquids business; offset partially by

·   a decrease of $15.3 million due to lower natural gas and NGL product prices, particularly ethane and propane, offset partially by higher condensate prices in ONEOK Partners’ natural gas gathering and processing business;

·   a decrease of $14.6 million due primarily to higher compression costs and third-party transportation and processing costs associated with our volume growth primarily in the Williston Basin in ONEOK Partners’ natural gas gathering and processing business;

·   a decrease of $3.7 million due to lower realized natural gas prices on the retained fuel position of ONEOK Partners’ natural gas pipeline business, offset partially by higher retained volumes; and

·   a decrease of $1.9 million related to lower isomerization volumes, offset partially by wider price differentials between normal butane and iso-butane in ONEOK Partners’ natural gas liquids business.

Operating costs increased for the three months ended June 30, 2012, compared with the same period last year, due primarily to the following:

·   an increase of $4.9 million from higher materials and outside services expenses associated primarily with scheduled maintenance and the growth of ONEOK Partners’ operations related to the completed capital projects in its natural gas liquids business; and

·   an increase of $4.7 million in higher labor costs and employee-related costs associated with growth of ONEOK Partners’ operations and completed capital projects.

Operating costs increased for the six months ended June 30, 2012, compared with the same period last year, due primarily to the following:

·   an increase of $7.7 million from higher materials, utilities and outside services expenses associated primarily with scheduled maintenance and the growth of ONEOK Partners’ operations related to the completed capital projects in its natural gas liquids business; and

·   an increase of $8.5 million in higher labor costs and employee-related costs associated with growth of ONEOK Partners’ operations and completed capital projects.

Depreciation and amortization expense increased for the three and six months ended June 30, 2012, compared with the same periods last year, due primarily to the depreciation associated with ONEOK Partners’ completed capital projects, which includes the completion of its Garden Creek plant, well connections and infrastructure projects supporting the volume growth in the Williston Basin.

Capital expenditures increased for the three and six months ended June 30, 2012, compared with the same periods last year, due primarily to the growth projects in ONEOK Partners’ natural gas gathering and processing and natural gas liquids businesses.

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

	Three Months Ended						Six Months Ended
	June 30,						June 30,
Operating Information	2012			2011			2012			2011
Natural gas gathering and processing business (a)
Natural gas gathered (BBtu/d)		1,079			1,026			1,062			1,009
Natural gas processed (BBtu/d) (b)		823			682			796			661
NGL sales (MBbl/d)		57			47			55			45
Residue gas sales (BBtu/d)		385			300			371			287
Realized composite NGL net sales price ($/gallon) (c)	$	1.01		$	1.09		$	1.05		$	1.09
Realized condensate net sales price ($/Bbl) (c)	$	86.17		$	82.43		$	87.86		$	79.35
Realized residue gas net sales price ($/MMBtu) (c)	$	3.79		$	5.77		$	3.77		$	5.95
Realized gross processing spread ($/MMBtu) (c)	$	8.03		$	8.38		$	8.31		$	8.36
Natural gas pipelines business (a)
Natural gas transportation capacity contracted (MDth/d)		5,236			5,295			5,394			5,466
Transportation capacity subscribed (e)		87	%		88	%		89	%		90	%
Average natural gas price
Mid-Continent region ($/MMBtu)	$	2.17		$	4.18		$	2.27		$	4.14
Natural gas liquids business
NGL sales (MBbl/d)		506			482			508			480
NGLs fractionated (MBbl/d) (d)		529			541			557			518
NGLs transported-gathering lines (MBbl/d) (a)		523			432			511			415
NGLs transported-distribution lines (MBbl/d) (a)		478			462			481			462
Conway-to-Mont Belvieu OPIS average price differential
Ethane in ethane/propane mix  ($/gallon)	$	0.23		$	0.20		$	0.24		$	0.17
(a) - For consolidated entities only.
(b) - Includes volumes processed at company-owned and third-party facilities.
(c) - Presented net of the impact of hedging activities and includes equity volumes only.
(d) - Includes volumes fractionated from company-owned and third-party facilities.
(e) - Prior periods have been recast to reflect current estimated capacity.

Natural gas gathered increased for the three and six months ended June 30, 2012, compared with the same periods last year, due to increased drilling activity in the Williston Basin and western Oklahoma, completion of additional gathering lines and compression to support ONEOK Partners’ new Garden Creek plant that was placed in service in December 2011 and the impact of weather-related outages in the first quarter 2011, offset partially by continued production declines and reduced drilling activity in the Powder River Basin in Wyoming.

Low natural gas prices and the relatively higher market prices of crude oil and NGLs compared with natural gas 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 Powder River Basin.  The reduced development activities and natural production declines in the Powder River Basin have resulted in lower volumes available to be gathered.  While the reserve potential in the Powder River Basin still exists, future drilling and development will be affected by commodity prices and producers’ alternative prospects.  A continued decline in volumes in this area may reduce ONEOK Partners’ ability to recover the carrying value of its assets and equity investments in this area and possibly result in noncash charges to earnings.

Natural gas processed, NGL sales and residue gas sales increased for the three and six months ended June 30, 2012, compared with the same periods last year, due to an increase in drilling activity in the Williston Basin and western Oklahoma, placing the new Garden Creek plant into service in December 2011 and the impact of weather-related outages in the first quarter of 2011.

Natural gas transportation capacity contracted decreased for the three and six months ended June 30, 2012, compared with the same periods last year due primarily to lower subscribed capacity on Midwestern Gas Transmission due to narrower natural gas price location differentials between the markets it serves; offset partially by higher subscribed capacity with producers to transport their increasing natural gas supply to market on our intrastate pipelines.

ONEOK Partners’ operating information above does not include its 50-percent interest in Northern Border Pipeline.  Substantially all of Northern Border Pipeline’s long-haul transportation capacity has been contracted through March 2013, and two-thirds of its long-haul capacity has been contracted through 2014.  Northern Border Pipeline operates pursuant to a 2007 rate case settlement and is required to file a rate case or reach a new settlement with its shippers on or before December 31, 2012, which may impact ONEOK Partners’ future equity earnings from Northern Border Pipeline.

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NGLs fractionated decreased for the three months ended June 30, 2012, compared with the same period last year, due to scheduled maintenance at ONEOK Partners’ Mont Belvieu fractionation facility in May 2012, offset partially by increased production from ONEOK Partners’ Mid-Continent fractionation facilities.  NGLs fractionated increased for the six months ended June 30, 2012, compared with the same period last year, due primarily to additional Gulf Coast fractionation capacity made available by ONEOK Partners’ 60 Mbl/d fractionation services agreement with Targa Resources Partners that began in the second quarter of 2011, offset partially by scheduled maintenance at our Mont Belvieu fractionation facility in May 2012.

NGLs gathered increased for the three and six months ended June 30, 2012, compared with the same periods last year, due primarily to increased throughput from existing connections in Texas and the Mid-Continent and Rocky Mountain regions, and new supply connections in the Mid-Continent and Rocky Mountain regions.  The increased capacity in the Mid-Continent and Texas was made available through ONEOK Partners’ Cana-Woodford Shale and Granite Wash projects, which were placed in service in April 2012.

NGLs transported on distribution lines increased for the three and six months ended June 30, 2012, compared with the same periods last year, due primarily to the completion of ONEOK Partners’ Sterling I Pipeline expansion.

Commodity Price Risk - The following tables set forth ONEOK Partners’ natural gas gathering and processing business’ hedging information for its equity volumes for the periods indicated, as of June 30, 2012.

	Six Months Ending
	December 31, 2012
	Volumes Hedged		(a)	Average Price		Percentage Hedged
NGLs (Bbl/d)		9,084		$	1.26   / gallon		70%
Condensate (Bbl/d)		1,757		$	2.42   / gallon		74%
Total (Bbl/d)		10,841		$	1.45   / gallon		71%
Natural gas (MMBtu/d)		48,967		$	4.25   / MMBtu		76%
(a) - Hedged with fixed-price swaps.

	Year Ending
	December 31, 2013
	Volumes Hedged		(a)	Average Price		Percentage Hedged
NGLs (Bbl/d)		367		$	2.55   / gallon		2%
Condensate (Bbl/d)		1,275		$	2.53   / gallon		47%
Total (Bbl/d)		1,642		$	2.54   / gallon		7%
Natural gas (MMBtu/d)		50,137		$	3.85   / MMBtu		80%
(a) - Hedged with fixed-price swaps.

ONEOK Partners expects its commodity price sensitivity in its gathering and processing business to increase in the future as volumes increase under POP contracts with ONEOK Partners’ customers.  ONEOK Partners’ commodity price sensitivity is estimated as a hypothetical change in the price of NGLs, crude oil and natural gas, excluding the effects of hedging, and assuming normal operating conditions.  ONEOK Partners’ 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 $2.5 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 natural gas would change annual net margin by approximately $2.3 million.

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

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

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Natural Gas Distribution

Overview - Our Natural Gas Distribution segment provides natural gas distribution services to more than 2 million customers in Oklahoma, Kansas and Texas through Oklahoma Natural Gas, Kansas Gas Service and Texas Gas Service.  We serve residential, commercial, industrial and transportation customers in all three states.  In addition, our LDCs serve wholesale and public authority customers.  We operate subject to regulations and oversight of various regulatory agencies.  Our regulatory strategy incorporates rate-design features that reduce earnings lag, protect margin and mitigate risks.

Selected Financial Results - The following table sets forth certain selected financial results for the continuing operations of our Natural Gas Distribution segment for the periods indicated:

	Three Months Ended				Six Months Ended				Three Months					Six Months
	June 30,				June 30,				2012 vs. 2011					2012 vs. 2011
Financial Results	2012		2011		2012		2011		Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
Gas sales	$	194.2	$	228.3	$	675.7	$	872.9	$	(34.1	)	(15	%)	$	(197.2	)	(23	%)
Transportation revenues		18.3		19.0		45.3		48.0		(0.7	)	(4	%)		(2.7	)	(6	%)
Cost of gas		63.6		97.8		344.1		538.3		(34.2	)	(35	%)		(194.2	)	(36	%)
Net margin, excluding other revenues		148.9		149.5		376.9		382.6		(0.6	)	(0	%)		(5.7	)	(1	%)
Other revenues		8.6		9.6		17.9		20.3		(1.0	)	(10	%)		(2.4	)	(12	%)
Net margin		157.5		159.1		394.8		402.9		(1.6	)	(1	%)		(8.1	)	(2	%)
Operating costs		103.8		104.5		208.7		209.2		(0.7	)	(1	%)		(0.5	)		-
Depreciation and amortization		32.0		34.4		65.5		70.4		(2.4	)	(7	%)		(4.9	)	(7	%)
Operating income	$	21.7	$	20.2	$	120.6	$	123.3	$	1.5		7	%	$	(2.7	)	(2	%)
Capital expenditures	$	72.9	$	61.9	$	131.4	$	109.0	$	11.0		18	%	$	22.4		21	%

The following table sets forth our net margin, excluding other revenues, by type of customer, for the periods indicated:

	Three Months Ended				Six Months Ended				Three Months					Six Months
	June 30,				June 30,				2012 vs. 2011					2012 vs. 2011
Net Margin, Excluding Other Revenues	2012		2011		2012		2011		Increase (Decrease)					Increase (Decrease)
Gas sales	(Millions of dollars)
Residential	$	107.9	$	105.9	$	273.0	$	271.1	$	2.0		2	%	$	1.9		1	%
Commercial		21.3		23.2		54.9		59.8		(1.9	)	(8	%)		(4.9	)	(8	%)
Industrial		0.8		0.8		1.4		1.6		-		0	%		(0.2	)	(13	%)
Wholesale/public authority		0.6		0.6		2.3		2.1		-		0	%		0.2		10	%
Net margin on gas sales		130.6		130.5		331.6		334.6		0.1		0	%		(3.0	)	(1	%)
Transportation margin		18.3		19.0		45.3		48.0		(0.7	)	(4	%)		(2.7	)	(6	%)
Net margin, excluding other revenues	$	148.9	$	149.5	$	376.9	$	382.6	$	(0.6	)	(0	%)	$	(5.7	)	(1	%)

Natural gas prices decreased during the three and six months ended June 30, 2012, compared with the same periods last year.  The decrease in natural gas prices had a direct impact on our revenues and cost of sales.

Net margin decreased for the three months ended June 30, 2012, compared with the same period last year, due primarily to the following:

·   a decrease of $4.2 million due to expiration of the Integrity Management Program (IMP) rider, which allowed Oklahoma Natural Gas to recover certain deferred pipeline-integrity costs in Oklahoma.  This decrease is offset by lower regulatory amortization in depreciation and amortization expense; offset partially by

·   an increase of $1.9 million from new rates and surcharge recoveries in Texas and Kansas.

Net margin decreased for the six months ended June 30, 2012, compared with the same period last year, due primarily to the following:

·   a decrease of $8.5 million due to expiration of the IMP rider.  This decrease is offset by lower regulatory amortization in depreciation and amortization expense; and

·   a decrease of $2.9 million from lower transportation volumes due to weather-sensitive customers in Kansas and Oklahoma; offset partially by

·   an increase of $4.2 million from new rates and surcharge recoveries in Texas and Kansas.

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Operating costs decreased for the three months ended June 30, 2012, compared with the same period last year, due primarily to the following:

·   a decrease of $3.3 million in share-based compensation costs from common stock awarded in the prior year to employees as part of ONEOK’s stock award program and the appreciation in ONEOK’s share price during 2011;

·   a decrease of $1.4 million in bad-debt expense; offset partially by

·   an increase of $1.8 million in legal costs;

·   an increase of $1.4 million in higher outside service costs due primarily to expenses associated with IMP activities, pipeline maintenance and other consulting services; and

·   an increase of $1.0 million in pension costs as a result of the annual change in our estimated discount rate.

Operating costs decreased for the six months ended June 30, 2012, compared with the same period last year, due primarily to the following:

·   a decrease of $10.3 million in share-based compensation costs from common stock awarded in the prior year to employees as part of ONEOK’s stock award program and the appreciation in ONEOK’s share price during 2011; offset partially by

·   an increase of $3.8 million from higher outside service costs due primarily to expenses associated with IMP activities in Oklahoma;

·   an increase of $3.3 million in legal costs; and

·   an increase of $2.0 million in pension costs as a result of the annual change in our estimated discount rate.

Depreciation and amortization expense decreased for the three and six months ended June 30, 2012, due primarily to a decrease of $4.2 million and $8.5 million, respectively, in regulatory amortization associated with the expiration of the IMP rider, which allowed us to defer recognition of certain pipeline-integrity costs in Oklahoma; offset partially by an increase of $1.6 million and $3.4 million, respectively, in higher depreciation expense associated with additional capital expenditures.

Capital Expenditures - Our capital expenditures program includes expenditures for pipeline integrity, automated meter reading, extending service to new areas, modifications to customer-service lines, increasing system capabilities, relocating facilities to accommodate government construction and replacements.  It is our practice to maintain and upgrade facilities to ensure safe, reliable and efficient operations.

Capital expenditures increased for the three and six months ended June 30, 2012, compared with the same periods last year, primarily as a result of increased spending on pipeline replacements.

Selected Operating Information - The following tables set forth certain selected information for the regulated operations of our Natural Gas Distribution segment for the periods indicated:

	Three Months Ended		Six Months Ended
	June 30,		June 30,
Number of Customers	2012	2011	2012	2011
Residential	1,933,646	1,924,608	1,939,201	1,931,569
Commercial	153,020	153,734	154,457	155,087
Industrial	1,214	1,237	1,232	1,242
Wholesale/public authority	2,750	2,736	2,726	2,760
Transportation	11,911	11,677	11,894	11,643
Total customers	2,102,541	2,093,992	2,109,510	2,102,301

	Three Months Ended		Six Months Ended
	June 30,		June 30,
Volumes (MMcf)	2012	2011	2012	2011
Gas sales
Residential	9,021	12,336	58,718	70,801
Commercial	3,593	4,343	16,690	19,898
Industrial	383	287	725	710
Wholesale/public authority	2,326	393	4,833	1,562
Total volumes sold	15,323	17,359	80,966	92,971
Transportation	45,842	46,433	103,375	108,882
Total volumes delivered	61,165	63,792	184,341	201,853

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Residential and commercial volumes decreased for the three and six months ended June 30, 2012, compared with the same periods last year, due primarily to warmer temperatures in the first and second quarters of 2012; however, the impact on margins was mitigated largely by weather normalization mechanisms.  Wholesale sales represent contracted gas volumes that exceed the needs of our residential, commercial and industrial customer base and are available for sale to other parties.  Wholesale volumes increased for 2012, compared to 2011; however, the impact to margins was minimal.

Regulatory Initiatives - Oklahoma - In March 2012, Oklahoma Natural Gas filed aPerformance Based Rate Change (PBRC) filing seeking to increase base rates by $16.2 million.  A Joint Stipulation was approved by the OCC in July 2012.  This agreement provides for a $9.5 million rate increase and modifications to Oklahoma Natural Gas’ PBRC tariff.  The modified tariff narrows the range of allowed regulated return on equity (ROE) to a range of 10.0 percent to 11.0 percent from our previous range of 9.75 percent to 11.25 percent; increases the ROE reflected in any rate increase resulting from a revenue deficiency to 10.5 percent from 10.25 percent; and reduces the number of allowed pro forma adjustments that can be proposed by Oklahoma Natural Gas.

In May 2011, the OCC approved a portfolio of conservation and energy-efficiency programs and authorized recovery of costs and performance incentives.  The agreement allows Oklahoma Natural Gas to pursue key energy-efficiency programs and allows the company to earn up to $1.5 million annually, if program objectives are achieved.  Based on customer interest in the rebate programs through June 2012, we anticipate several rebate programs being fully subscribed by customers during calendar 2012.

Kansas - In May 2012, Kansas Gas Service submitted an application to increase its overall annual revenues by $32.7 million.  The request includes a $50.7 million increase in base rates and an $18.0 million reduction in amounts currently recovered through surcharges.  The KCC has 240 days to issue an order and is expected to make a final ruling by January 14, 2013.

In March 2012, Kansas Gas Service submitted an application to the KCC to approve the implementation of a cast-iron pipeline-replacement program that would accelerate the rate at which we are replacing cast-iron pipe.  The application seeks a surcharge that would recover the carrying charges and depreciation expense associated with the investment as the costs are incurred.  The total cost of the replacement program is estimated to be $8.8 million annually over an eight-year period.

The KCC approved an application from Kansas Gas Service to increase the Gas System Reliability Surcharge by an additional $2.9 million effective January 2012.  This surcharge is a capital-recovery mechanism that allows for rate adjustment, providing recovery of and a return on incremental safety-related and government-mandated capital investments made between rate cases.

Texas - Texas Gas Service made annual filings for interim rate relief under the Gas Reliability Infrastructure Program (GRIP) statute with the cities of Austin, Texas, and surrounding communities in February 2012 and El Paso, Texas, in April 2012.  GRIP is a capital-recovery mechanism that allows for an interim rate adjustment providing recovery and a return on incremental capital investments made between rate cases.  In May 2012, the City of Austin, Texas, approved a $3.5 million increase pursuant to this filing.  In July 2012, the city of El Paso approved a $1.3 million increase.

In January 2012, the Texas Railroad Commission approved the settlement between Texas Gas Service and the City of El Paso that allows for recovery of 2010-2013 pipeline-integrity expenditures and partial recovery of rate-case expenses.  The settlement did not have a material impact on our results of operations.

In the normal course of business, Texas Gas Service has filed rate cases and requests for GRIP and cost-of-service adjustments in various other Texas jurisdictions to address investments in rate base and changes in expense.  Annual rate increases totaling $5.3 million associated with these filings have been approved in 2012.

Energy Services

Overview - Our Energy Services segment is a provider of natural gas supply and risk-management services for natural gas and electric utilities and commercial and industrial customers.  We use a network of leased storage and transportation capacity to supply natural gas to our customers.  This network connects the major supply and demand centers throughout the United States and into Canada and, coupled with our industry knowledge and market intelligence, allows us to provide our customers with customized services in a more efficient and reliable manner than they can achieve independently.

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We follow a strategy of optimizing our storage and cross-regional transportation capacity through the application of market knowledge and effective risk management.  We seek to maximize value by actively hedging the risks associated with seasonal and location price differentials that are inherent to storage and transportation contracts.  At the same time, we attempt to capitalize on opportunities created by market volatility, weather-related events, supply-demand imbalances and market inefficiencies, which allow us to capture additional margin.  Using market information, we manage these asset-based positions and seek to provide incremental margin in our trading portfolio.

To ensure natural gas is available when our customers need it, we offer premium services and products that satisfy our customers’ nonuniform supply needs such as swing and peaking natural gas load requirements on a year-round basis.  Types of premium services include next-day and no-notice services.  Next-day services allow our customers to call on additional gas supply, up to an amount agreed upon in a service contract, and expect delivery the following day.  No-notice services allow customers to call on additional natural gas supply and expect immediate delivery.  We also provide weather-related protection and other custom solutions based on our customers’ specific needs.  Our storage and transportation assets enable us to provide these services and provide us with opportunities to capture daily, monthly and seasonal value due to market inefficiencies.  We expect premium-services margins will be lower than the prior year due to lower natural gas prices.

As a result of significant increases in the supply of natural gas, primarily from shale production across North America, location and seasonal price differentials have narrowed significantly, resulting in reduced opportunities to capture margins with our firm transportation and storage capacity.  Additionally, price volatility in the natural gas markets remains relatively low as compared with volatility in the past, which, coupled with a fairly flat forward price curve, reduces the value of the demand fee we receive for premium services and further limits opportunities to optimize our assets.  We have undertaken several steps to better align fixed costs with the current business environment, including attempts to renegotiate various natural gas storage and transportation contracts.  Contract renegotiation activities that we have taken or expect to take include renewing contracts at current market rates at contract expiration, extending contracts in order to negotiate a more favorable rate or paying to terminate contracts in areas that are no longer strategic to our business.  For the six months ended June 30, 2012, we recognized charges to our earnings as a result of certain of these actions.  As we continue our contract renegotiation activities, it is possible we may recognize additional charges to our earnings in the future.  We expect these contractual changes to result in less storage and transportation capacity under lease and a better alignment of our contracted natural gas transportation and storage capacity with the needs of our premium-services customers.  We also expect the reduction in our contracted natural gas transportation and storage capacity will reduce our operating costs and working-capital requirements.

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

	Three Months Ended						Six Months Ended					Three Months					Six Months
	June 30,						June 30,					2012 vs. 2011					2012 vs. 2011
Financial Results	2012			2011			2012			2011		Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
Revenues	$	268.9		$	616.0		$	729.7		$	1,507.8	$	(347.1	)	(56	%)	$	(778.1	)	(52	%)
Cost of sales and fuel		279.3			616.4			755.6			1,452.3		(337.1	)	(55	%)		(696.7	)	(48	%)
Net margin		(10.4	)		(0.4	)		(25.9	)		55.5		(10.0	)		*		(81.4	)		*
Operating costs		4.6			5.3			9.4			13.3		(0.7	)	(13	%)		(3.9	)	(29	%)
Depreciation and amortization		0.1			0.1			0.2			0.2		-		0	%		-			-
Goodwill impairment		-			-			10.3			-		-			-		10.3		100	%
Operating income (loss)	$	(15.1	)	$	(5.8	)	$	(45.8	)	$	42.0	$	(9.3	)		*	$	(87.8	)		*
* Percentage change is greater than 100 percent.

The following table sets forth our margins by activity for the periods indicated:

	Three Months Ended						Six Months Ended						Three Months					Six Months
	June 30,							June 30,					2012 vs. 2011					2012 vs. 2011
	2012			2011				2012			2011		Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
Marketing, storage and transportation revenues, gross	$	26.7		$	39.4			$	55.5		$	136.7	$	(12.7	)	(32	%)	$	(81.2	)	(59	%)
Storage and transportation costs		37.6			39.6				82.1			81.4		(2.0	)	(5	%)		0.7		1	%
Marketing, storage and transportation, net		(10.9	)		(0.2	)			(26.6	)		55.3		(10.7	)		*		(81.9	)		*
Financial trading, net		0.5			(0.2	)			0.7			0.2		0.7			*		0.5			*
Net margin	$	(10.4	)	$	(0.4	)		$	(25.9	)	$	55.5	$	(10.0	)		*	$	(81.4	)		*
* Percentage change is greater than 100 percent.

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Marketing, storage and transportation revenues, gross, primarily includes marketing, purchases and sales, premium services and the impact of cash flow and fair value hedges and other derivative instruments used to manage our risk associated with these activities.  Storage and transportation costs primarily include the cost of leasing capacity, storage injection and withdrawal fees, fuel charges and gathering fees.  Risk-management and operational decisions have an impact on the net result of our marketing, premium services and storage activities.  We evaluate our strategies on an ongoing basis to optimize the value of our contracted assets and to minimize the financial impact of market conditions on the services we provide.

Our storage and transportation costs decreased 5 percent for the three months ended June 30, 2012, compared with the three months ended June 30, 2011, due primarily to reduced transportation capacity, offset partially by an increase in storage demand fees and a loss resulting from the release to a third party of contracted transportation capacity that expires in December 2012.

Our storage and transportation costs remained relatively unchanged for the six months ended June 30, 2012, compared with the six months ended June 30, 2011, due primarily to an increase in storage demand fees and a loss resulting from the release to a third party of contracted transportation capacity that expires in December 2012, offset by reduced transportation capacity.

For additional information on transportation and storage capacity refer to “Selected Operating Information” below.

Financial trading, net, includes activities that are executed generally using financially settled derivatives.  These activities are normally short term in nature, with a focus on capturing short-term price volatility.  Revenues in our Consolidated Statements of Income include financial trading margins, as well as certain physical natural gas transactions with our trading counterparties.  Revenues and cost of sales and fuel from such physical transactions are reported on a net basis.

Revenues and cost of sales and fuel decreased for the three and six months ended June 30, 2012, compared with the same periods last year, due primarily to lower natural gas prices.

Net margin decreased for the three months ended June 30, 2012, compared with the same period last year, due primarily to the following:

·   a decrease of $8.7 million in transportation margins, net of hedging, due primarily to lower hedge settlements in 2012;

·   a decrease of $2.1 million in premium-services margins, associated primarily with lower demand fees; and

·   storage and marketing margins, net of hedging activities, were relatively unchanged but reflect:

-   an increase of $12.8 million due to higher realized seasonal storage price differentials; offset by

-   a decrease of $6.8 million from unrealized fair value changes on nonqualifying economic hedges;

-   a decrease of $3.7 million due primarily to decreased marketing activities; and

-   a decrease of $1.4 million due to higher demand fees on storage contracts.

Net margin decreased for the six months ended June 30, 2012, compared with the same period last year, due primarily to the following:

·   a decrease of $65.4 million in storage and marketing margins, net of hedging activities, due primarily to the following:

-   a decrease of $29.9 million related to the reclassification of deferred losses into current earnings from accumulated other comprehensive income on certain financial contracts that were used to hedge forecasted purchases of natural gas, as a result of the continued decline in natural gas prices.  The combination of the cost basis of the forecasted inventory and the financial contracts exceeds the amount expected to be recovered through sales of that inventory after considering related sales hedges, requiring reclassification of the loss from accumulated other comprehensive income (loss) to current period earnings;

-   a decrease of $15.1 million due to lower realized seasonal storage price differentials;

-   a decrease of $9.3 million due to unrealized fair value changes on nonqualifying economic hedges;

-   a decrease of $6.2 million due primarily to decreased marketing activities; and

-   a decrease of $3.7 million due to higher demand fees on storage contracts;

·   a decrease of $13.6 million in transportation margins, net of hedging, due primarily to the following:

-   lower hedge settlements in 2012; and

-   release of contracted transportation capacity to a third party resulting in the recognition of a loss in the first half of 2012, which will reduce our overall loss on the transportation contract expiring in December 2012; and

·   a decrease of $3.2 million in premium-services margins, associated primarily with lower demand fees.

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Operating costs decreased for the three and six months ended June 30, 2012, compared with the same periods last year due primarily to lower employee related expenses.

We also recognized an expense of $10.3 million related to the impairment of our goodwill in the first quarter of 2012.  Given the continued significant decline in natural gas prices and its effect on location and seasonal price differentials, we performed an interim impairment assessment in the first quarter of 2012 that reduced our goodwill balance to zero.

Selected Operating Information - The following table sets forth certain selected operating information for our Energy Services segment for the periods indicated:

	Three Months Ended					Six Months Ended
	June 30,					June 30,
Operating Information	2012			2011		2012			2011
Natural gas marketed (Bcf)		150			192		368			452
Natural gas gross margin ($/Mcf)	$	(0.06	)	$	-	$	(0.06	)	$	0.13
Physically settled volumes (Bcf)		322			405		739			899

Natural gas volumes marketed and physically settled volumes decreased for the three and six months ended June 30, 2012, compared with the same periods last year, due primarily to lower transported volumes and reduced transportation capacity.  Transportation capacity in certain markets was not utilized due to the economics of the location differentials as a result of increased supply of natural gas, primarily from shale production, and increased pipeline capacity as a result of pipeline construction.

At June 30, 2012, our natural gas transportation capacity was 1.1 Bcf/d, of which 1.0 Bcf/d was contracted under long-term natural gas transportation contracts, compared with 1.2 Bcf/d of total capacity and 1.2 Bcf/d of long-term capacity at June 30, 2011.  Approximately 6 percent of our transportation capacity expires by the end of 2012, and approximately an additional 69 percent expires by the end of 2015.

Approximately 35.0 MMcf/d of transportation capacity expired in the first quarter of 2012, an additional 46.2 MMcf/d expired on April 1, 2012, and 59.8 MMcf/d will expire in the fourth quarter of 2012.  We do not expect to renew any of this transportation capacity.

Our natural gas in storage at June 30, 2012, was 58.6 Bcf, compared with 43.3 Bcf at June 30, 2011.  At June 30, 2012, our total natural gas storage capacity under lease was 72.4 Bcf, compared with 72.6 Bcf at June 30, 2011.  At June 30, 2012, our natural gas storage capacity under lease had a maximum withdrawal capability of 2.3 Bcf/d and maximum injection capability of 1.3 Bcf/d.  Approximately 15.2 Bcf of storage capacity expired on April 1, 2012, of which 12.7 Bcf was renewed at market rates.  We have no additional storage capacity contracts expiring for the remainder of 2012; approximately 88 percent expires by the end of 2015.

Reducing storage and transportation capacity continues to be a focus as we reduce fixed costs and align our capacity with the needs of our premium-services customers.  It is possible that we may recognize charges to our earnings in the future as a result of these actions.

CONTINGENCIES

Legal Proceedings - We are a party to various litigation matters and claims that have arisen in the normal course of our operations.  While the results of litigation and claims cannot be predicted with certainty, and we are unable to estimate reasonably possible losses, 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 our legal proceedings is included under Part I, Item 3, Legal Proceedings, in our Annual Report.

LIQUIDITY AND CAPITAL RESOURCES

General - ONEOK and ONEOK Partners have relied primarily on operating cash flow, commercial paper, bank credit facilities, debt issuances and/or the issuance of equity for their liquidity and capital resource requirements.  ONEOK and ONEOK Partners fund operating expenses, debt service, dividends to shareholders and distributions to unitholders primarily with operating cash flow.  Capital expenditures are funded by short- and long-term debt, issuances of equity and operating cash flow.  We expect to continue to use these sources for our liquidity and capital resource needs.  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.

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ONEOK’s and ONEOK Partners’ ability to continue to access capital markets for debt and equity financing under reasonable terms depends on market conditions and ONEOK’s and ONEOK Partners’ respective financial condition and credit ratings.  We anticipate that our cash flow generated from operations, existing capital resources, including proceeds from the issuance of our $700 million, 4.25-percent senior notes in January 2012 and distributions from ONEOK Partners will enable us to maintain our current and planned level of operations and fund any share repurchases under our three-year, $750-million stock repurchase program.  ONEOK Partners anticipates that its cash flow generated from operations, proceeds from its March 2012 equity offering, existing capital resources and ability to obtain financing will enable it to maintain its current and planned level of operations.  Additionally, ONEOK Partners expects to fund its future capital expenditures with short- and long-term debt, the issuance of equity and operating cash flows.

Capitalization Structure - The following table sets forth our consolidated capitalization structure as of the dates indicated:

	June 30,	December 31,
	2012	2011
Long-term debt	55%	56%
Total equity	45%	44%
Debt (including notes payable)	58%	60%
Total equity	42%	40%

For purposes of determining compliance with financial covenants in the ONEOK 2011 Credit Agreement, which are described below, the debt of ONEOK Partners is excluded.  The following table sets forth ONEOK’s capital structure, excluding the debt of ONEOK Partners, for the periods indicated:

	June 30,	December 31,
	2012	2011
Long-term debt	45%	31%
ONEOK shareholders' equity	55%	69%
Debt (including notes payable)	52%	45%
ONEOK shareholders' equity	48%	55%

Stock Repurchase Program - In June 2012, we entered into an accelerated share repurchase agreement (the ASR Agreement) with Goldman, Sachs & Co. (Goldman), pursuant to which we paid $150 million to Goldman and received from Goldman approximately 2.9 million shares of our common stock, representing approximately 80 percent of the estimated total number of shares to be repurchased.  The ASR Agreement is scheduled to end in September 2012, although the termination date may be accelerated.  We expect to receive the balance of the shares at the conclusion of the ASR Agreement.  The specific number of shares that we ultimately will repurchase will be based on the volume weighted average price per share of our common stock during the repurchase period, subject to other adjustments pursuant to the terms and conditions of the ASR Agreement.  At settlement, under certain circumstances, Goldman may be required to deliver additional shares of our common stock to us, or, under certain circumstances, we may be required to deliver shares of our common stock or we may elect to make a cash payment to Goldman.

The ASR Agreement is part of our three-year stock repurchase program that was authorized by our Board of Directors on October 21, 2010, to buy up to $750 million of our common stock, subject to the limitation that purchases will not exceed $300 million in any one calendar year.  Pursuant to the Board’s authorization, following this transaction and our repurchase of $300 million in 2011, an additional $300 million may yet be purchased pursuant to the program, of which a maximum of $150 million of additional shares of our common stock may be purchased in 2012.

Short-term Liquidity - ONEOK’s principal sources of short-term liquidity consist of cash generated from operating activities, quarterly distributions from ONEOK Partners and the issuance of commercial paper.  ONEOK Partners’ principal sources of short-term liquidity consist of cash generated from operating activities, the issuance of commercial paper and distributions received from unconsolidated affiliates.  To the extent commercial paper is unavailable, ONEOK’s and ONEOK Partners’ respective revolving credit agreements may be utilized.

ONEOK 2011 Credit Agreement - The ONEOK 2011 Credit Agreement, which is scheduled to expire in April 2016, contains certain financial, operational and legal covenants.  Among other things, these covenants include maintaining ONEOK’s stand-alone debt-to-capital ratio of no more than 67.5 percent at the end of any calendar quarter, limitations on the ratio of indebtedness secured by liens and indebtedness of subsidiaries to consolidated net tangible assets, a requirement that

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ONEOK maintains the power to control the management and policies of ONEOK Partners, and a limit on new investments in master limited partnerships.  The ONEOK 2011 Credit Agreement also contains customary affirmative and negative covenants, including covenants relating to liens, investments, fundamental changes in the nature of ONEOK’s businesses, transactions with affiliates, the use of proceeds and a covenant that limits ONEOK’s ability to restrict its subsidiaries’ ability to pay dividends.  The debt covenant calculations in the ONEOK 2011 Credit Agreement exclude the debt of ONEOK Partners.  In the event of a breach of certain covenants by ONEOK, amounts outstanding under the ONEOK 2011 Credit Agreement may become due and payable immediately.  At June 30, 2012, ONEOK’s stand-alone debt-to-capital ratio, as defined by the ONEOK 2011 Credit Agreement, was 50.5 percent, and ONEOK was in compliance with all covenants under the ONEOK 2011 Credit Agreement.

Under the terms of the ONEOK 2011 Credit Agreement, ONEOK may request an increase in the size of the facility to an aggregate of $1.7 billion from $1.2 billion by either commitments from new lenders or increased commitments from existing lenders.  The ONEOK 2011 Credit Agreement is available to repay our commercial paper notes, if necessary.  Amounts outstanding under the commercial paper program reduce the borrowing capacity under the ONEOK 2011 Credit Agreement.

The total amount of short-term borrowings authorized by ONEOK’s Board of Directors is $2.8 billion.  At June 30, 2012, ONEOK had $571.9 million of commercial paper outstanding, $1.7 million in letters of credit issued under the ONEOK 2011 Credit Agreement and approximately $22.8 million of cash and cash equivalents.  ONEOK had approximately $626.4 million of credit available at June 30, 2012, under the ONEOK 2011 Credit Agreement.  As of June 30, 2012, ONEOK could have issued $2.4 billion of additional short- and long-term debt under the most restrictive provisions contained in its various borrowing agreements.

ONEOK Partners 2011 Credit Agreement - The ONEOK Partners 2011 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 2011 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 of the acquisition and the two following quarters.  Upon breach of certain covenants by ONEOK Partners in the ONEOK Partners 2011 Credit Agreement, amounts outstanding under the ONEOK Partners 2011 Credit Agreement, if any, may become due and payable immediately.  At June 30, 2012, ONEOK Partners’ ratio of indebtedness to adjusted EBITDA was 2.3 to 1, and ONEOK Partners was in compliance with all covenants under the ONEOK Partners 2011 Credit Agreement.

The ONEOK Partners 2011 Credit Agreement includes a $100-million sublimit for the issuance of standby letters of credit and also features an option to request an increase in the size of the facility to an aggregate of $1.7 billion from $1.2 billion by either commitments from new lenders or increased commitments from existing lenders.  The ONEOK Partners 2011 Credit Agreement is available to repay ONEOK Partners’ commercial paper notes, if necessary.  Amounts outstanding under ONEOK Partners’ commercial paper program reduce the borrowing capacity under the ONEOK Partners 2011 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, 2012, ONEOK Partners had $24.0 million of commercial paper outstanding, no letters of credit issued, no borrowings outstanding under the ONEOK Partners 2011 Credit Agreement, approximately $92.2 million of cash and $1.2 billion of credit available under the ONEOK Partners 2011 Credit Agreement.  As of June 30, 2012, ONEOK Partners could have issued $4.8 billion of short- and long-term debt to meet its liquidity needs under the most restrictive provisions contained in its various borrowing agreements.

Effective August 1, 2012, ONEOK Partners extended the maturity date of its Partnership 2011 Credit Agreement from August 1, 2016, to August 1, 2017, pursuant to an extension agreement between ONEOK Partners and its lenders.

Recent events in the European economy could impact European banks.  Various European-based banks participate in the ONEOK 2011 Credit Agreement and ONEOK Partners 2011 Credit Agreement, representing an aggregate of $340 million and $342 million in committed capacity, respectively.  These banks are of significant scale and international diversification, which we believe minimizes the risk of these banks being unable to fulfill their commitments to us or ONEOK Partners under our respective credit agreements.  Should any of these banks be unable to fund any future borrowings under the credit agreements, we believe other funding sources would likely be available to replace the European banks’ commitments.

Long-term Financing - In addition to the principal sources of short-term liquidity discussed above, ONEOK expects to fund its longer-term cash requirements by issuing equity or long-term notes.  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 leaseback of facilities.

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ONEOK and ONEOK Partners are subject to changes in the debt and equity markets, and there is no assurance they will be able or willing to access the public or private markets in the future.  ONEOK and ONEOK Partners may choose to meet their cash requirements by utilizing some combination of cash flows from operations, borrowing under existing commercial paper  or credit facilities, altering the timing of controllable expenditures, restricting future acquisitions and capital projects, or pursuing other debt or equity financing alternatives.  Some of these alternatives could involve higher costs or negatively affect their respective credit ratings, among other factors.  Based on ONEOK’s and ONEOK Partners’ investment-grade credit ratings, general financial condition and market expectations regarding their future earnings and projected cash flows, ONEOK and ONEOK Partners believe that they will be able to meet their respective cash requirements and maintain their investment-grade credit ratings.

ONEOK Debt Issuance - In January 2012, we completed an underwritten public offering of $700 million, 4.25-percent senior notes due 2022.  The net proceeds from the offering, after deducting underwriting discounts and offering expenses, of approximately $694.3 million were used to repay amounts outstanding under our commercial paper program.  We will pay interest on the senior notes due 2022 on February 1 and August 1 of each year, beginning August 1, 2012.

The indenture governing ONEOK’s senior notes due 2022 includes an event of default upon acceleration of other indebtedness of $100 million or more.  Such events of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of the outstanding senior notes due 2022 to declare those senior notes immediately due and payable in full.

ONEOK may redeem its senior notes due 2022 at a redemption price equal to the principal amount, plus accrued and unpaid interest, starting three months before the maturity date.  Prior to this date, ONEOK may redeem the senior notes due 2022, in whole or in part, at any time for a redemption price equal to the principal amount plus accrued and unpaid interest and a make-whole premium.  The redemption price will never be less than 100 percent of the principal amount of the respective note plus accrued and unpaid interest to the redemption date.  ONEOK’s senior notes due 2022 are senior unsecured obligations, ranking equally in right of payment with all of ONEOK’s existing and future unsecured senior indebtedness.

ONEOK Partners’ Debt Maturities- ONEOK Partners repaid its $350 million, 5.9-percent senior notes upon maturity in April 2012 with a portion of the proceeds from its March 2012 equity issuance.

ONEOK Partners’ Equity Issuance - In March 2012, ONEOK Partners completed an underwritten public offering of 8,000,000 common units at a public offering price of $59.27 per common unit, generating net proceeds of approximately $460 million.  ONEOK Partners also sold 8,000,000 common units to us in a private placement, generating net proceeds of approximately $460 million.  In conjunction with the issuances, we contributed $19.1 million in order to maintain our 2-percent general partner interest in ONEOK Partners.  ONEOK Partners used the proceeds from the offerings to repay approximately $295.0 million of borrowing under its $1.2 billion commercial paper program, to repay amounts on the maturity of their $350 million, 5.9-percent senior notes due April 2012 and for other general partnership purposes, including capital expenditures.  As a result of these transactions, our aggregate ownership interest in ONEOK Partners increased to 43.4 percent from 42.8 percent.

Interest-rate Swaps - ONEOK and ONEOK Partners each 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.  ONEOK had interest-rate swaps with notional values totaling $500 million at December 31, 2011.  In January 2012, ONEOK entered into additional interest-rate swaps with notional amounts totaling $200 million.  Upon issuance in January 2012 of our $700 million, 4.25-percent senior notes due 2022, ONEOK settled all $700 million of its interest-rate swaps and realized a loss of $44.1 million in accumulated other comprehensive income that will be amortized to interest expense over the term of the hedged debt.  At June 30, 2012, and December 31, 2011, ONEOK Partners had forward-starting interest-rate swaps with notional amounts totaling $1 billion and $750 million, respectively.  In July 2012, ONEOK Partners entered into additional forward-starting interest-rate swaps with settlement dates greater than 12 months with notional amounts totaling $400 million.

Capital Expenditures - ONEOK’s and ONEOK Partners’ capital expenditures are financed typically through operating cash flows, short- and long-term debt and the issuance of equity.  Capital expenditures were $780.7 million and $523.7 million for the six months ending June 30, 2012 and 2011, respectively, exclusive of acquisitions.  Of these amounts, ONEOK Partners’ capital expenditures were $636.2 million and $410.2 million for the six months ended June 30, 2012 and 2011, respectively, exclusive of acquisitions.  Capital expenditures for 2012 increased, compared with the same period last year, due primarily to the growth projects in ONEOK Partners’ natural gas gathering and processing and natural gas liquids businesses.

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The following table sets forth our 2012 projected capital expenditures, excluding AFUDC:

2012 Projected Capital Expenditures
	(Millions of dollars)
ONEOK Partners	$	2,045
Natural Gas Distribution		272
Other		32
Total projected capital expenditures	$	2,349

Credit Ratings - Our credit ratings as of June 30, 2012, are shown in the table below:

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

ONEOK’s and ONEOK Partners’ commercial paper programs are each rated Prime-2 by Moody’s and A2 by S&P.  ONEOK’s and ONEOK Partners’ credit ratings, which currently are investment grade, may be affected by a material change in financial ratios or a material event affecting the business.  The most common criteria for assessment of credit ratings are the debt-to-capital ratio, business risk profile, pre-tax and after-tax interest coverage, and liquidity.  ONEOK and ONEOK Partners currently do not anticipate their respective credit ratings to be downgraded; however, if ONEOK’s or ONEOK Partners’ credit ratings were downgraded, the cost to borrow funds under their respective commercial paper programs and credit agreements would increase, and ONEOK or ONEOK Partners potentially could lose access to the commercial paper market.  In the event that ONEOK is unable to borrow funds under its commercial paper program and there has not been a material adverse change in its business, ONEOK would continue to have access to the ONEOK 2011 Credit Agreement, which expires in April 2016.  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 2011 Credit Agreement, which expires in August 2017.  An adverse rating change alone is not a default under the ONEOK 2011 Credit Agreement or the ONEOK Partners 2011 Credit Agreement.

Our Energy Services segment relies upon the investment-grade rating of ONEOK’s senior unsecured long-term debt to reduce its collateral requirements.  If ONEOK’s credit ratings were to decline below investment grade, our ability to participate in energy marketing and trading activities could be significantly limited.  Without an investment-grade rating, we may be required to fund margin requirements with our counterparties with cash, letters of credit or other negotiable instruments.  At June 30, 2012, ONEOK could have been required to fund approximately $3.1 million in margin requirements related to financial contracts upon such a downgrade.  A decline in ONEOK’s credit rating below investment grade also may impact significantly other business segments.

In the normal course of business, ONEOK’s and ONEOK Partners’ counterparties provide secured and unsecured credit.  In the event of a downgrade in ONEOK’s or ONEOK Partners’ credit ratings or a significant change in ONEOK’s or ONEOK Partners’ counterparties’ evaluation of our creditworthiness, ONEOK or 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.

Commodity Prices - We are subject to commodity price volatility.  Significant fluctuations in commodity prices will impact our overall liquidity due to the impact commodity price changes have on our 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.  We believe that ONEOK’s and ONEOK Partners’ available credit and cash and cash equivalents are adequate to meet liquidity requirements associated with commodity price volatility.  See Note D of the Notes to Consolidated Financial Statements; the discussion under ONEOK Partners’ “Commodity Price Risk” in Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations; and Energy Services’ discussion under “Commodity Price Risk” in Item 3, Quantitative and Qualitative Disclosures about Market Risk, for information on our hedging activities.

Pension and Postretirement Benefit Plans - Information about our pension and postretirement benefits plans, including anticipated contributions, is included under Note M 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.

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CASH FLOW ANALYSIS

We use the indirect method to prepare our Consolidated Statements of Cash Flows.  Under this method, we reconcile net income to cash flows provided by operating activities by adjusting net income for those items that impact net income but may not result in actual cash receipts or payments during the period.

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

	Six Months Ended							Variances
	June 30,							2012 vs. 2011
	2012			2011			Increase (Decrease)
	(Millions of dollars)
Total cash provided by (used in):
Operating activities	$	652.6		$	875.6			$      (223.0)
Investing activities		(738.4	)		(508.8	)			(229.6)
Financing activities		125.9			79.8				46.1
Change in cash and cash equivalents		40.1			446.6				(406.5)
Change in cash and cash equivalents included in discontinued operations		8.8			(4.7	)			13.5
Change in cash and cash equivalents from continuing operations		48.9			441.9				(393.0)
Cash and cash equivalents at beginning of period		66.0			30.3				35.7
Cash and cash equivalents at end of period	$	114.9		$	472.2			$      (357.3)

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

Cash flows from operating activities, before changes in operating assets and liabilities, were $705.9 million for the six months ended June 30, 2012, compared with $623.0 million for the same period in 2011.  The increase was due primarily to changes in net margin and operating expenses discussed in Financial Results and Operating Information on page 38.

The changes in operating assets and liabilities decreased operating cash flows $53.3 million for the six months ended June 30, 2012, compared with an increase of $252.6 million for the same period last year.  The change was due primarily to the collection and payment of trade receivables and payables, resulting from the timing of invoices collected from customers and paid to vendors and suppliers, which vary from period to period; and the change in gas and natural gas liquids in storage primarily at ONEOK Partners’ natural gas liquids business and our Energy Services segment.  The change in natural gas and natural gas liquids in storage results from changes in storage levels and the impact of commodity prices on the purchase cost of inventory, both which vary from period to period.

Investing Cash Flows - Cash used in investing activities increased for the six months ended June 30, 2012, compared with cash used in investing activities for the same period in 2011, due primarily to ONEOK Partners’ growth projects in its natural gas gathering and processing and natural gas liquids businesses, offset partially by proceeds from the sale of ONEOK Energy Marketing Company.

Financing Cash Flows - Cash provided by financing activities increased for the six months ended June 30, 2012, compared with the same period in 2011.  The change is a result of our January 2012 debt issuance and the ONEOK Partners equity issuances in March 2012, offset partially by increased distributions to noncontrolling interests and increased dividends.

REGULATORY

Financial Markets Legislation - The Dodd-Frank Act represents a far-reaching overhaul of the framework for regulation of United States financial markets.  Various regulatory agencies, including the SEC and the CFTC, have proposed regulations for implementation of many of the provisions of the Dodd-Frank Act.  The CFTC has issued final regulations for certain provisions of the Dodd-Frank Act, but others remain outstanding.  In July 2012, the CFTC issued an order that further defers the effective date of the provisions of the Dodd-Frank Act that require a rulemaking, such as definitions of certain terms, until the earlier of the effective date of the final rule defining the referenced terms or December 31, 2012.  The CFTC issued the definitional rules in late May and early July 2012 that will become effective 60 days after publication in the Federal Register.  We are reviewing the rules to ascertain how we may be affected by them.  Based on our assessment of the regulations issued to date and those proposed, we expect to be able to continue to participate in financial markets for hedging certain risks

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inherent in our business, including commodity and interest-rate risks; however, the capital requirements and costs of hedging may increase as a result of the legislation.  We also may incur additional costs associated with our compliance with the new regulations and anticipated additional record keeping, reporting and disclosure obligations; however, we do not believe the costs will be material.  These requirements could affect adversely market liquidity and pricing of derivative contracts making it more difficult to execute our risk-management strategies in the future.  Also, the anticipated increased costs of compliance by dealers and counterparties likely will be passed on to customers, which could decrease the benefits of hedging to us and could reduce our profitability and liquidity.

Other - Several regulatory initiatives impacted the earnings and future earnings potential for our Natural Gas Distribution segment.  See discussion of our Natural Gas Distribution segment’s regulatory initiatives beginning on page 48.

ENVIRONMENTAL AND SAFETY MATTERS

Environmental Matters -We are subject to multiple historical and wildlife preservation laws and environmental regulations affecting many aspects of our present and future operations.  Regulated activities include those involving air emissions; storm water and wastewater discharges; handling and disposal of solid and hazardous wastes; hazardous materials transportation; and pipeline and facility construction.  These laws and regulations require us to obtain and 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 us to fines, penalties and/or interruptions in our operations that could be material to our results of operations.  If a leak or spill of hazardous substances or petroleum products occurs from pipelines or facilities that we own, operate or otherwise use, we could be held jointly and severally liable for all resulting liabilities, including response, investigation and cleanup costs, which could affect materially our results of operations and cash flows.

In addition, emission controls required under the Clean Air Act and other similar federal and state laws could require unexpected capital expenditures at our facilities.  We cannot assure that existing environmental regulations will not be revised or that new regulations will not be adopted or become applicable to us.  Revised or additional regulations that result in increased compliance costs or additional operating restrictions could have a material adverse effect on our business, financial condition, results of operations and cash flows.

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

Pipeline Safety - We are subject to Pipeline and Hazardous Materials Safety Administration regulations, including 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 new 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 us.  These issues include but are not limited to:

·   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 liquid 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 pipelines previously untested in high-consequence areas operating above 30-percent yield strength.

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 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.  We 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 under way.  We are monitoring federal and state legislation to assess the potential impact on our operations.  The EPA’s Mandatory Greenhouse Gas Reporting Rule, released in September 2009, requires greenhouse gas emissions reporting for affected facilities on an annual

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basis and requires us to track the emission equivalents for the natural gas delivered by us to our distribution customers and emission equivalents for all NGLs delivered to customers of ONEOK Partners.  Our 2010 total reported emissions were less than 66.6 million metric tons of carbon dioxide equivalents.  This total includes 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, as if all such fuel and NGL products were combusted with the resulting carbon dioxide injected directly into disposal wells.  We reported 2011 greenhouse gas emissions for a portion of our facilities by March 31, 2012, as required by the EPA, and will report for the remainder of our facilities by September 30, 2012.  Also, the EPA released a subpart to the Mandatory Greenhouse Gas Reporting Rule that will require the reporting of vented and fugitive emissions of methane from our facilities.  The new requirements began in January 2011, with the first reporting of fugitive emissions due September 30, 2012.  We do not expect the cost to gather this emission data to have a material impact on our results of operations, financial position or cash flows.  In addition, Congress has considered, and may consider in the future, legislation to reduce greenhouse gas emissions, including carbon dioxide and methane.  At this time, no rule or legislation has been enacted that assesses any costs, fees or expenses on any of these emissions.

In May 2010, the EPA finalized the “Tailoring Rule” that will regulate greenhouse gas emissions at new or modified facilities that meet certain criteria.  Affected facilities will be required to review best available control technology, conduct air-quality analysis, impact analysis and public reviews with respect to such emissions.  The rule was phased in beginning January 2011, and at current emission threshold levels, we believe it will have a minimal impact on our existing facilities.  The EPA has stated it will consider lowering the threshold levels over the next five years, which could increase the impact on our existing facilities; however, potential costs, fees or expenses associated with the potential adjustments are unknown.

In addition, the EPA has issued a rule on air-quality standards, “National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines,” also known as RICE NESHAP, with a compliance date in 2013.  The rule will require capital expenditures over the next two years for the purchase and installation of new emissions-control equipment.  We do not expect these expenditures to have a material impact on our results of operations, financial position or cash flows.

In July 2011, the EPA issued a proposed rule that would change the air emission New Source Performance Standards, also known as NSPS, and Maximum Achievable Control Technology requirements applicable to the oil and gas industry, including natural gas production, processing, transmission and underground storage.  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 will become effective after it is published in the Federal Register.  It will require expenditures for updated emissions controls, monitoring and record keeping requirements at affected facilities.  We do not expect these expenditures to have a material impact on our results of operations, financial position or cash flows.

Superfund - The Comprehensive Environmental Response, Compensation and Liability Act, also known as CERCLA or Superfund, imposes liability, without regard to fault or the legality of the original act, on certain classes of persons that contributed to the release of a hazardous substance into the environment.  These persons include the owner or operator of a facility where the release occurred and 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.  Neither we nor ONEOK Partners expect our respective current responsibilities under CERCLA, for this facility and any other, to have a material impact on our respective 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.  We completed the Homeland Security assessments, and our 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 our facilities have been given a Tier 4 rating.  Facilities receiving a Tier 4 rating are required to complete Site Security Plans and possible physical security enhancements.  We do not expect the Site Security Plans and possible security enhancements cost to have a material impact on our results of operations, financial position or cash flows.

Pipeline Security - 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.”  We have reviewed our pipeline facilities according to the new guideline requirements, and there have been no material changes required to date.

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Environmental Footprint - Our environmental and climate change strategy focuses on taking steps to minimize the impact of our 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 our various pipelines, natural gas processing facilities and natural gas liquids fractionation facilities; (iii) following developing technologies for emission control; and (iv) following developing technologies to capture carbon dioxide to keep it from reaching the atmosphere.

ONEOK Partners participates in the EPA’s Natural Gas STAR Program to reduce voluntarily methane emissions.  We continue 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.  Our most recent calculation of our annual lost-and-unaccounted-for natural gas, for all of our business operations, is less than 1 percent of total throughput.

IMPACT OF NEW ACCOUNTING STANDARDS

Information about the impact of new accounting standards is included in Note A of the Notes to Consolidated Financial Statements in this Quarterly Report.

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 and Section 21E of the Exchange Act.  The forward-looking statements relate to our anticipated financial performance, liquidity, management’s plans and objectives for our future operations, 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, including energy sales and 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 status of deregulation of retail natural gas distribution;

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·   the capital intensive nature of our businesses;

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

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

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

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

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

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

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

·   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 the OCC, KCC, Texas regulatory authorities or any other local, state or federal regulatory body, including the FERC, the National Transportation Safety Board, the Pipeline and Hazardous Materials Safety Administration, 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;

·   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;

·   adverse labor relations;

·   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;

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·   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 possible loss of natural gas distribution franchises or other adverse effects caused by the actions of municipalities;

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

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

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

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

·   the impact of potential impairment charges;

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

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

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

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

COMMODITY PRICE RISK

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

Energy Services

Fair Value Component of the Energy Marketing and Risk Management Assets and Liabilities - The following table sets forth the fair value component of the energy marketing and risk management assets and liabilities, excluding $22.1 million and $80.7 million of net assets at June 30, 2012, and December 31, 2011, respectively, from derivative instruments declared as either fair value or cash flow hedges for the periods indicated:

Fair Value Component of Energy Marketing and Risk Management Assets and Liabilities
	(Thousands of dollars)
Net fair value of derivatives outstanding at December 31, 2011	$	12,609
Derivatives reclassified or otherwise settled during the period		(6,300	)
Fair value of new derivatives entered into during the period		6,480
Other changes in fair value		(3,849	)
Net fair value of derivatives outstanding at June 30, 2012 (a)	$	8,940
(a) - The maturities of derivatives are based on injection and withdrawal periods from April through March, which is consistent with our business strategy. The maturities are as follows: $7.3 million matures through March 2013 and $1.6 million matures through March 2016.

The change in the net fair value of derivatives outstanding includes the effect of settled energy contracts and current period changes resulting primarily from newly originated transactions and the impact of market movements on the fair value of energy marketing and risk management assets and liabilities.

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For further discussion of fair value measurements and derivative instruments, see the “Estimates and Critical Accounting Policies” section of Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations, in our Annual Report.  Also, see Notes C and D of the Notes to Consolidated Financial Statements in this Quarterly Report.

Value-at-Risk (VAR) Disclosure of Commodity Price Risk - The potential impact on our future earnings, as measured by VAR, was $3.2 million and $1.8 million at June 30, 2012 and 2011, respectively.  The following table sets forth the average, high and low VAR calculations for the periods indicated:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
Value-at-Risk	2012		2011		2012		2011
	(Millions of dollars)
Average	$	2.9	$	3.7	$	2.7	$	3.5
High	$	4.0	$	6.6	$	4.0	$	6.6
Low	$	1.8	$	1.6	$	1.8	$	1.6

Our VAR calculation includes derivatives, executory storage and transportation agreements and their related hedges.  The variations in the VAR data are reflective of market volatility and changes in our portfolio during the year.  The decrease in average VAR for June 30, 2012, compared with June 30, 2011, was due primarily to a decrease in total transportation capacity over the five-year period that VAR is calculated.

To the extent open commodity positions exist, fluctuating commodity prices can impact our financial results and financial position either favorably or unfavorably.  As a result, we cannot predict with precision the impact risk-management decisions may have on our business, operating results or financial position.

INTEREST-RATE RISK

We are subject to the risk of interest-rate fluctuation in the normal course of business.  We manage interest-rate risk through the use of fixed-rate debt, floating-rate debt and interest-rate swaps.  At June 30, 2012, the interest rate on all of ONEOK’s and ONEOK Partners’ long-term debt was fixed.

ONEOK and ONEOK Partners each 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.  ONEOK had interest-rate swaps with notional values totaling $500 million at December 31, 2011.  In January 2012, ONEOK entered into additional interest-rate swaps with notional amounts totaling $200 million.  Upon issuance in January 2012 of our $700 million, 4.25-percent senior notes due 2022, ONEOK settled all $700 million of its interest-rate swaps and realized a loss of $44.1 million in accumulated other comprehensive income that will be amortized to interest expense over the term of the hedged debt.  At June 30, 2012, and December 31, 2011, ONEOK Partners had forward-starting interest-rate swaps with notional amounts totaling $1 billion and $750 million, respectively.  In July 2012, ONEOK Partners entered into additional forward-starting interest-rate swaps with settlement dates greater than 12 months with notional amounts totaling $400 million.

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, 2012, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II - OTHER INFORMATION

ITEM 1.                      LEGAL PROCEEDINGS

Additional information about our legal proceedings is included under Part I, Item 3, Legal Proceedings, in our Annual Report.

ITEM 1A.                      RISK FACTORS

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

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

The following table sets forth information relating to our purchases of our common stock for the periods indicated:

Period	Total Number of Shares Purchased		Average Price Paid per Share	Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs		Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Be Purchased Under the Plans or Programs
April 1-30, 2012	3,200	(a)	$8.44		-
May 1-31, 2012	-		-		-
June 1-30, 2012	3,642,061	(a) (b)	$8.44		3,641,661
Total	3,645,261		$8.44		3,641,661	$	300,000,000	(c)
(a) - Includes shares withheld pursuant to attestation of ownership and deemed tendered to us in connection with the exercise
of stock options under the ONEOK, Inc. Long-Term Incentive Plan.
(b) - Includes an estimated 3,641,661 shares based on the June 11, 2012, closing stock price of $41.19, to be purchased pursuant to
our $150 million accelerated share repurchase agreement discussed under "Liquidity and Capital Resources" in Item 2,
Management's Discussion and Analysis of Financial Condition and Results of Operations in this Quarterly Report. In June
2012, we received approximately 2.9 million shares, representing approximately 80 percent of the estimated total number of
shares to be repurchased. We expect to receive the balance of the shares at the termination of the agreement, which is
scheduled for September, although the termination may be accelerated.
(c) - The maximum approximate dollar value of shares that may yet be purchased pursuant to our approximately $750 million
stock repurchase program that was announced on October 21, 2010, subject to the limitations that purchases will not exceed
$300 million in any one calendar year and that a maximum of $150 million of additional shares of our common stock may be
purchased in 2012. The program will terminate upon the completion of the repurchase of $750 million of common stock or on
December 31, 2013, whichever occurs first.

ITEM 3.                      DEFAULTS UPON SENIOR SECURITIES

Not Applicable.

ITEM 4.                      MINE SAFETY DISCLOSURES

Not Applicable.

ITEM 5.                      OTHER INFORMATION

Not Applicable.

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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

3.1 Amendment dated May 23, 2012, to the ONEOK, Inc. Amended and Restated Certificate of Incorporation (incorporated by reference to Exhibit 3.1 to ONEOK, Inc.’s Current Report on Form 8-K filed on May 25, 2012).

10.1 Accelerated Share Repurchase Agreement dated June 11, 2012, by and between ONEOK, Inc. and Goldman Sachs & Co.

10.2 ONEOK, Inc. Employee Stock Purchase Plan as amended and restated effective as of May 23, 2012.

10.3 Extension Agreement dated August 1, 2012, among ONEOK Partners, L.P., as Borrower, each of the existing Lenders, and Citibank, N.A., as Administrative Agent, Swing Line Lender and L/C Issuer (incorporated by reference to Exhibit 10.1 to ONEOK Partners, L.P.’s report on Form 10-Q filed on August 1, 2012, (File No. 1-12202)).

31.1 Certification of John W. Gibson pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2 Certification of Robert F. Martinovich pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1 Certification of John W. Gibson 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 Robert F. Martinovich 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, 2012 and 2011; (iii) Consolidated Statements of Comprehensive Income for the three and six months ended June 30, 2012 and 2011; (iv) Consolidated Balance Sheets at June 30, 2012, and December 31, 2011; (v) Consolidated Statements of Cash Flows for the six months ended June 30, 2012 and 2011; (vi) Consolidated Statement of Changes in Equity for the six months ended June 30, 2012; 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 1, 2012                                                                                By:           /s/ Robert F. Martinovich

Robert F. Martinovich

Executive Vice President,

Chief Financial Officer and Treasurer

(Principal Financial Officer)

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EX-3.1

Exhibit 3.1

FILED - Oklahoma Secretary of State #1900584812 05/15/2008 12:12

AMENDED AND RESTATED CERTIFICATE OF INCORPORATION

OF

ONEOK, INC.

This Amended and Restated Certificate of Incorporation of ONEOK, Inc., an Oklahoma corporation (the “Corporation”), which has been duly adopted in accordance with the provisions of Sections 1077 and 1080 of the Oklahoma General Corporation Act (the “OGCA”), amends and restates the Certificate of Incorporation of ONEOK, Inc. (originally incorporated under the name “WAI, Inc.”) filed with the Secretary of State of Oklahoma on May 16, 1997. Such previous Certificate of Incorporation, as previously amended, is hereby amended and restated to read, in its entirety, as follows:

FIRST

The name of the Corporation is ONEOK, Inc.

SECOND

The principal office or place of business of the Corporation in the State of Oklahoma is to be located at 100 West Fifth Street, in the City of Tulsa, County of Tulsa. The name of its resident agent is Corporation Service Company and the address of said resident agent is 115 S.W. 89th Street, Oklahoma City, Oklahoma, Oklahoma County 73139-8551.

THIRD

The purpose of the Corporation is to engage in any lawful act or activity for which corporations may be organized under the OGCA.

FOURTH

The total number of shares of all classes of capital stock which the Corporation shall have authority to issue is 400,000,000 shares divided into two classes, of which 100,000,000 shares, par value $0.01 per share, shall be designated Preferred Stock and 300,000,000 shares, par value $0.01 per share, shall be designated Common Stock.

1. Preferred Stock.

(a) Issuance. The Board of Directors is authorized, subject to limitations prescribed by law, to provide for issuance of shares of Preferred Stock in one or more series, to establish the number of shares to be included in each such series, and to fix the designations, powers, preferences, and rights of the shares of each such series, and any qualifications, limitations or restrictions thereof.

2. Common Stock.

(a) Dividends. Subject to the preferential rights, if any, of the Preferred Stock, the holders of shares of Common Stock shall be entitled to receive, when and if declared by the Board of Directors, out of the assets of the Corporation which are by law available therefor, dividends payable either in cash, in property, or in shares of Common Stock.

(b) Voting Rights. At every annual or special meeting of shareholders of the Corporation, every holder of Common Stock shall be entitled to one vote, in person or by proxy, for each share of Common Stock standing in his name on the books of the Corporation.

(c) Liquidation, Dissolution or Winding Up. In the event of any voluntary or involuntary liquidation, dissolution, or winding up of the affairs of the Corporation, after payment or provision for payment of the debts and other liabilities of the Corporation and of the preferential amounts, if any, to which the holders of Preferred Stock shall be entitled, the holders of all outstanding shares of Common Stock shall be entitled to share ratably in the remaining net assets of the Corporation.

FIFTH

The Corporation shall have perpetual existence.

SIXTH

The private property of the shareholders shall not be subject to the payment of the corporate debts to any extent whatever.

SEVENTH

1. The business of the Corporation shall be managed by the Board of Directors, except as otherwise required by law. The Board of Directors may by resolution or resolutions, passed by a majority of the whole Board, designate one or more committees, each committee to consist of one (1) or more of the Directors of the Corporation, which to the extent provided in said resolution or resolutions or in the Bylaws of the Corporation, shall have and may exercise the powers of the Board of Directors in the management of the business and affairs of the Corporation, and may have power to authorize the seal of the Corporation to be affixed to all papers which may require it. Such committee or committees shall have such name or names as may be stated in the Bylaws of the Corporation or as may be determined from time to time by resolution adopted by the Board of Directors.

2. The number of Directors of the Corporation shall be not less than nine (9) nor more than twenty-one (21) persons and shall be fixed from time to time by the Board of Directors. Directors shall be elected at each annual meeting of shareholders of the Corporation.

3. Newly created directorships resulting from any increase in the authorized number of Directors or any vacancies in the Board of Directors resulting from death, resignation, retirement, disqualification, removal from office or other cause shall be filled by the affirmative vote of a majority of the Directors then in office, though less than a quorum, or by the sole

2

remaining Director, or by the shareholders at their next annual meeting or at any special meeting of shareholders called for that purpose. Each Director so chosen shall hold office until the next annual meeting of shareholders of the Corporation or until his earlier death, resignation or removal. No decrease in the number of Directors constituting the Board of Directors shall shorten the term of any incumbent Director. Subject to the rights of the holders of any series of Preferred Stock then outstanding, any Director or the entire Board of Directors may be removed from office at any time, with or without cause, by the holders of a majority of the voting power of all outstanding Voting Shares (as defined in Article Tenth).

4. The shareholders and Directors of the Corporation may hold their meetings and have an office or offices outside of the State of Oklahoma if the Bylaws so provide.

5. None of the Directors need be a shareholder of the Corporation or a resident of the State of Oklahoma.

6. The Bylaws or any Bylaw may be adopted, amended or repealed only by the affirmative vote of not less than a majority of the Directors then in office at any regular or special meeting, or by the affirmative vote of the holders of at least eighty percent (80%) of the voting power of all outstanding Voting Shares, voting as a single class, at any annual meeting or any special meeting called for that purpose.

7. The Board of Directors shall have power from time to time to set apart out of any funds of the Corporation available for dividends a reserve or reserves for any proper purpose, and to abolish such reserve in the manner in which it was created and to fix and determine and to vary the amount of the working capital of the Corporation, and to direct and determine the use and disposition of the working capital and of any surplus or net profits over and above the capital stock paid in.

8. The shareholders and the Board of Directors shall have power to keep the books, documents and papers of the Corporation outside of the State of Oklahoma, except as otherwise required by the laws of the State of Oklahoma.

9. The Board of Directors from time to time shall determine whether and to what extent and at what times and places, and under what conditions and regulations the accounts and books of the Corporation, or any of them, shall be open to the inspection of the shareholders, and no shareholders shall have any right to inspect any account, book or documents of the Corporation except as conferred by statute or as authorized by resolution of the Board of Directors.

10. In the absence of fraud, no contract or other transaction of the Corporation shall be affected or invalidated in any way by the fact that any of the Directors of the Corporation are in any way interested in or connected with any other party to such contract or transaction or are themselves parties to such contract or transaction, provided that such interest shall be fully disclosed or otherwise known to the Board of Directors at the meeting of said Board at which such contract or transaction is authorized or confirmed, and provided further that at the meeting of the Board of Directors authorizing or confirming such contract or transaction there shall be present a quorum of Directors not so interested or connected and such contract or transaction

3

shall be approved by a majority of such quorum, and no such interested Director shall vote on any such contract or transaction. Any contract, transaction or act of the Corporation or of the Board of Directors or of any committee thereof which shall be ratified by a majority of a quorum of the shareholders of the Corporation having voting power at any annual meeting, or any special meeting called for such purpose, shall be as valid and as binding as though ratified by every shareholder of the Corporation. Any Director of the corporation may vote upon any contract or other transaction between the Corporation and any subsidiary corporation without regard to the fact that he is also a Director of such subsidiary corporation. No contract or agreement between the Corporation and any other corporation or party which owns a majority of the capital stock of the Corporation, or any subsidiary of any such other corporation shall be made or entered into without the affirmative vote of a majority of the whole Board of Directors at a regular meeting of the Board.

11. Notwithstanding anything to the contrary in the foregoing paragraph 10, in the case of contracts, transactions and acts of the Corporation, of the Board of Directors or of committees thereof that require shareholder approval under any provision of this Certificate or of applicable law by a higher proportion of the voting power of the outstanding Voting Shares than a majority of a quorum of the shareholders, ratification by the shareholders of such contracts, transactions and acts shall require the affirmative vote of such higher proportion of such voting power, and any contract, transaction, act or agreement referred to in such paragraph 10 shall be subject to any such applicable provisions of the Certificate or of applicable law.

12. All salaries and compensation paid by the Corporation to its Directors and executive officers shall be fixed from time to time by the Board of Directors at a meeting of the Board to be held as provided by the Bylaws, and any payment of any character to any Director or executive officer of the Corporation or any contract made with such Director or executive officer must be approved by a majority of the whole Board of Directors at a regular meeting of the Board, before such payment is made or contract executed.

13. No Director shall be personally liable to the Corporation or its shareholders for monetary damages for any breach of fiduciary duty by such Director as a Director, except (i) for breach of the Director’s duty of loyalty to the Corporation or its shareholders, (ii) for acts or omissions not in good faith or which involve intentional misconduct or a knowing violation of law, (iii) pursuant to Section 1053 of Title 18 of the OGCA, or (iv) for any transaction from which the Director derived an improper personal benefit. Any repeal or modification of this paragraph 13 shall not adversely affect any right to protection of a Director of the Corporation existing at the time of such repeal or modification with respect to acts or omissions occurring prior to such repeal or modification.

14. The affirmative vote of the holders of at least eighty percent (80%) of the voting power of all outstanding Voting Shares shall be required to amend, repeal, or adopt any provision inconsistent with paragraphs 2, 3, 6, 11 or 13 of this Article SEVENTH or this paragraph 14.

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EIGHTH

Whenever compromise or arrangement is proposed between this Corporation and its creditors or any class of them and/or between this Corporation and its shareholders or any class of them, any court of equitable jurisdiction within the State of Oklahoma may, on the application in a summary way of this Corporation or of any creditor or shareholder thereof, or on the application of any receiver or receivers appointed for this Corporation under the provisions of Section 1106 of Title 18 of the OGCA, or on the application of trustees in dissolution or of any receiver or receivers appointed for this Corporation under the provisions of Section 1100 of Title 18 of the OGCA, order a meeting of the creditors or class of creditors, and/or of the shareholders or class of shareholders of this Corporation, as the case may be, to be summoned in such manner as the said Court directs. If holders of liabilities representing three-fourths (3/4) in value of the creditors or class of creditors and/or if holders of shares representing three-fourths (3/4) of the shares held by such shareholders or class of shareholders of this Corporation, as the case may be, agree to any compromise or arrangement and to any reorganization of this Corporation as consequence of such compromise or arrangement, the said compromise or arrangement and the said reorganization shall, if sanctioned by the Court to which the said application has been made, be binding on all the creditors or class of creditors, and/or on all the shareholders or class of shareholders, of this Corporation, as the case may be, and also on this Corporation.

NINTH

No holder of stock of the Corporation of any class shall have any preferential, preemptive or other right to subscribe for or to purchase from the Corporation any stock of the Corporation of any class whether or not now authorized, or to purchase any bonds, certificates of indebtedness, debentures, notes, obligations or other securities which the Corporation may at any time issue, whether or not the same shall be convertible into stock of the Corporation of any class or shall entitle the owner or holder to purchase stock of the Corporation of any class.

TENTH

1. Higher Vote for Certain Business Combinations. A Business Combination (as hereinafter defined) with or upon a proposal by a Related Person (as hereinafter defined) shall require, in addition to such approvals as are required by law, the approval of the Business Combination by either (a) a majority vote of all of the Independent Directors or (b) the holders of at least two-thirds (66-2/3%) of the shares otherwise entitled to vote as a single class with the Common Stock to approve such Business Combination (the “Applicable Shares”), excluding any shares owned by such Related Person; provided, however, that the provisions of this Article TENTH shall not apply to any Related Person who becomes a Related Person pursuant to a single transaction in which such Related Person acquires 85% of the Applicable Shares then outstanding in a single transaction; provided, further, that for the purpose of the immediately preceding proviso, Applicable Shares owned by (i) persons who are directors and also officers of the Corporation and (ii) employee stock plans, shall be excluded.

2. Certain Definitions. For purposes of this Article TENTH:

5

(a) A “person” shall mean any individual, firm, corporation or other entity, or a group of “persons” acting or agreeing to act together in the manner set forth in Rule 13d-5 under the Securities Exchange Act of 1934 (the “1934 Act”).

(b) The term “Business Combination” shall mean any of the following transactions, when entered into by the Corporation or a subsidiary of the Corporation with, or upon a proposal by, a Related Person:

(1) The merger or consolidation of the Corporation or any subsidiary of the Corporation; or

(2) The sale, lease, exchange, mortgage, pledge, transfer or other disposition (in one or a series of transactions) of any assets of the Corporation or any subsidiary of the Corporation having an aggregate fair market value of Five Million Dollars ($5,000,000) or more; or

(3) The issuance or transfer by the Corporation or any subsidiary of the Corporation (in one or a series of transactions) of securities of the Corporation or that subsidiary having an aggregate fair market value of Five Million Dollars ($5,000,000) or more, provided that issuances of Common Stock pursuant to conversions of Preferred Stock shall not be deemed a “Business Combination”; or

(4) The adoption of a plan or proposal for the liquidation or dissolution of the Corporation; or

(5) The reclassification of securities (including a reverse stock split), recapitalization, consolidation or any other transaction (whether or not involving a Related Person) which has the direct or indirect effect of increasing the voting power, whether or not then exercisable, of a Related Person in any class or series of capital stock of the Corporation or any subsidiary of the Corporation; or

(6) Any agreement, contract or other arrangement providing directly or indirectly for any of the foregoing.

(c) The term “Related Person” shall mean any person (other than the Corporation, a subsidiary of the Corporation or any profit sharing, employee stock ownership or other employee benefit plan of the Corporation or a subsidiary of the Corporation or any trustee of or fiduciary with respect to any such plan acting in such capacity) that is the direct or indirect beneficial owner (as defined in Rule 13d-3 and Rule 13d-5 under the 1934 Act) of more than ten percent (10%) of the outstanding Voting Shares of the Corporation and any Affiliate or Associate of any such person.

(d) The term “Independent Director” shall mean any member of the Board of Directors who is not affiliated with or nominated by a Related Person.

(e) “Affiliate” and “Associate” shall have the respective meanings ascribed to such terms in Rule 12b-2 under the 1934 Act.

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(f) The term “Voting Shares”, at any time, shall mean the Common Stock and shares of any other class of capital stock of the Corporation then entitled to vote generally in the election of directors.

(g) A majority of all Independent Directors shall have the power to make all determinations with respect to this Article TENTH, including, without limitation, the transactions that are Business Combinations, the persons who are Related Persons, the time at which a Related Person became a Related Person, and the fair market value of any assets, securities or other property, and any such determinations of such directors shall be conclusive and binding.

3. Applicability of the OGCA. Section 1090.3 of Title 18 of the OGCA shall be applicable to this Corporation.

4. No Effect on Fiduciary Obligations of Related Persons. Nothing contained in this Article TENTH shall be construed to relieve any Related Person from any fiduciary obligation imposed by law.

5. Amendment, Repeal, etc. The affirmative vote of the holders of at least eighty percent (80%) of the voting power of all outstanding Voting Shares of the Corporation, voting together as a single class, shall be required in order to amend, repeal or adopt any provision inconsistent with this Article TENTH.

ELEVENTH

1. Unless otherwise specifically provided in this Certificate (including any Certificate of Designation with respect to any class or series of Preferred Stock), any action required or permitted to be taken by the shareholders of the Corporation must be effected by a vote of the shareholders at a duly called annual meeting or special meeting called for that purpose and may not be effected by any consent in writing of such shareholders.

2. The affirmative vote of the holders of at least eighty percent (80%) of the voting power of all outstanding Voting Shares, voting as a single class, shall be required to amend, repeal, or adopt any provision inconsistent with this Article ELEVENTH.

TWELFTH

1. Election. Section 1145 through 1155 of Title 18 of the OGCA, as the same may be amended, shall not apply to the Corporation as of January 17, 1998.

2. Amendment. The affirmative vote of the holders of at least sixty-six and two-thirds percent (66 2/3%) of the voting power of all outstanding equity securities of the Corporation, voting as a class, shall be required in order to amend this Article TWELFTH.

Each of the undersigned hereby certify that this Amended and Restated Certificate of Incorporation was duly proposed by the Directors of the Corporation through the adoption of a resolution setting forth this Amended and Restated Certificate of Incorporation, declaring its advisability and directing that it be considered at the next annual meeting of shareholders, in

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accordance with the provisions of Sections 1077 and 1080 of the OGCA, and that this Amended and Restated Certificate of Incorporation was subsequently adopted by the shareholders of the Corporation in the manner and by the vote prescribed in Section 1077 of the OGCA.

IN WITNESS WHEREOF, the Corporation has caused this certificate to be signed by its Chief Executive Officer and attested by its Secretary, this 15th day of May, 2008.

/s/ John W. Gibson

 John W. Gibson, Chief Executive Officer

ATTEST:

/s/ Eric Grimshaw

 Eric Grimshaw, Secretary

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FILED - Oklahoma Secretary of State #1900584812 11/06/2008 14:37

CERTIFICATE OF CORRECTION

TO THE SECRETARY OF STATE OF OKLAHOMA:

The undersigned corporation, for the purpose of correcting its amended and restated certificate of incorporation as that instrument was filed in the Office of the Secretary of State of Oklahoma on May 15, 2008, pursuant to Section 1007 of the Oklahoma General Corporation Act (as amended, the “OGCA”), hereby certifies:

1. The name of the corporation as it appears on the records of the Secretary of State of the State of Oklahoma is: “ONEOK, Inc.”

2. An Amended and Restated Certificate of Incorporation (the “Certificate”) was filed with the Secretary of State of the State of Oklahoma on May 15, 2008, and the Certificate requires correction as permitted by Section 1007(F) of the OGCA.

3. The inaccuracy or defect of the Certificate to be corrected is the inadvertent omission as exhibits thereto of two Certificates of Designation and the inadvertent omission of a reference to such Certificates of Designation in Article Fourth of the Certificate.

4. The Certificate is corrected first by adding the following paragraph after paragraph 1(a) of Article Fourth:

“(b) Designations. Of the Preferred Stock, 20,000,000 shares have been designated as Convertible Preferred Stock, Series A, 30,000,000 have been designated as Convertible Preferred Stock, Series B and 1,000,000 shares have  been designated as Series C Participating Preferred Stock. The Certificate of Designation for the Convertible Preferred Stock, Series A and Convertible Preferred Stock, Series B is attached hereto as Exhibit A, and the Certificate of Designation for the Series C Participating Preferred Stock is attached hereto as Exhibit B, and the voting powers, designations, preferences and relative, participating, optional or other special rights, and the qualifications, limitations or restrictions for each of the Convertible Preferred Stock, Series A, the Convertible Preferred Stock, Series B and the Series C Participating Preferred Stock contained in such Certificates of Designation are incorporated herein by reference.”

5. The Certificate is secondly corrected by attaching the following to the Certificate as Exhibit A:

EXHIBIT A

CERTIFICATE OF THE DESIGNATIONS, POWERS, PREFERENCES AND RELATIVE,

PARTICIPATING, OPTIONAL OR OTHER RIGHTS, AND THE QUALIFICATIONS,

LIMITATIONS OR RESTRICTIONS THEREOF, OF

CONVERTIBLE PREFERRED STOCK

OF

WAI, INC.

Pursuant to Section 1032 of the

General Corporation Act of the State of Oklahoma

WAI, INC., an Oklahoma corporation (the “Corporation”), does hereby certify that the Board of Directors of the Corporation duly adopted the following resolution, at a meeting duly convened and held on November 25, 1997, in respect of two series of Preferred Stock, par value $0.01 per share, of the Corporation, pursuant to authority conferred upon the Board by Article Fourth of the Certificate of Incorporation of the Corporation and in accordance with Section 1032 of the General Corporation Act of the State of Oklahoma:

BE IT RESOLVED, that the issuance of two series of Preferred Stock of the Corporation is hereby authorized, and the designation, amount, powers, preferences and relative, participating, optional and other special rights and qualifications, limitations and restrictions thereof, of the shares of such series of Preferred Stock of the Corporation, are hereby fixed as follows:

1. Designation; Class and Amount; Certain Definitions. The two series of Preferred Stock, the issuance of which is hereby authorized, shall comprise twenty million (20,000,000) shares the distinctive serial designation of which shall be “Preferred Stock, Series A”, which is sometimes herein referred to as “Convertible Preferred Stock, Series A” and thirty million (30,000,000) shares the distinctive serial designation of which shall be “Preferred Stock, Series B”, which is sometimes herein referred to as “‘Convertible Preferred Stock, Series B” and, together with the Convertible Preferred Stock, Series A, the “Convertible Preferred Stock”. Each share of Convertible Preferred Stock, Series A shall be identical in all respects with all other shares of Convertible Preferred Stock, Series A and each share of Convertible Preferred Stock, Series B shall be identical in all respects with all other shares of Convertible Preferred Stock, Series B. The number of shares of Convertible Preferred Stock which are purchased or otherwise acquired by the Corporation or converted into Common Stock shall be cancelled and shall revert to authorized but unissued shares of Convertible Preferred

Stock undesignated as to series. Certain capitalized terms used herein have the meanings specified therefor in Section 10 below.

2. Dividends; Priority.

(a) (i) Payments of Dividend: Convertible Preferred Stock, Series A. Each Holder of shares of Convertible Preferred Stock, Series A, shall be entitled to receive, when and if declared by the Board of Directors, in respect of each share of Convertible Preferred Stock, Series A, out of the funds of the Corporation legally available therefor, quarterly cash dividend payments for each Dividend Period or portion thereof during which such share of Convertible Preferred Stock, Series A is outstanding. Such dividend payments shall be made: (A) during the First Dividend Stage, in an amount determined by multiplying (x) the dividend amount declared in respect of each share of the Corporation’s common stock, par value $0.01 per share (the “Common Stock”) for such Dividend Period (such amount payable being adjusted appropriately as set forth in Section 7(d) to reflect any stock split, stock dividend, reverse stock split, reclassification or any transaction with a comparable effect upon the Common Stock), times (y) 1.5; and (B) during the Second Dividend Stage, in an amount determined by multiplying (x) the dividend amount declared in respect of each share of Common Stock of the Corporation for such Dividend Period (such amount payable being adjusted appropriately as set forth in Section 7(d) to reflect any stock split, stock dividend, reverse stock split. reclassification or any transaction with a comparable effect upon the Common Stock), times (y) 1.25, provided, however, that in no event during either the First or the Second Dividend Stage shall the aggregate annual dividend amount payable in respect of each share of Convertible Preferred Stock, Series A be less than $1.80. No interest, or sum of money in lieu of interest, shall be payable in respect of any dividend payment or payments on shares of Convertible Preferred Stock, Series A which are not paid.

(ii) Payments of Dividend: Convertible Preferred Stock, Series B. Each Holder of shares of Convertible Preferred Stock, Series B, shall be entitled to receive, when and if declared by the Board of Directors, in respect of each share of Convertible Preferred Stock, Series B, out of the funds of the Corporation legally available therefor, quarterly cash dividend payments for each Dividend Period or portion thereof during which such share of Convertible Preferred Stock, Series B is outstanding. Such dividend payments shall be made in an amount determined by multiplying (x) the dividend amount declared in respect of each share of Common Stock of the Corporation for such Dividend Period (such amount payable being adjusted appropriately as set forth in Section 7(d) to reflect any stock split, stock dividend, reverse stock split, reclassification or any transaction with a comparable effect upon the Common Stock) times (y) 1.25, provided, however, that in no event during the First Dividend Stage, shall the aggregate annual dividend amount payable in respect of each share of Convertible Preferred Stock, Series B be less than $1.50 and provided, further, that in no event during the Second Dividend Stage, shall the aggregate annual dividend amount payable in respect of each share of Convertible Preferred Stock, Series B be less than $1.80. No interest or sum of money in lieu of interest shall be payable in respect of any dividend payment or payments on shares of Convertible Preferred Stock, Series B which are not paid.

(b) Payment and Record Dates. Dividends accrued on the Convertible Preferred Stock in respect of each Dividend Period shall be payable, when and if declared by the Board of

Directors, in arrears prior to or concurrently with each date of payment (each such date, a “Dividend Payment Date”) by the Corporation of quarterly cash dividends on the Common Stock in respect of such Dividend Period; provided, however, that if any such day is not a Business Day the applicable Dividend Payment Date shall be the next succeeding day that is a Business Day; and provided, further that if no quarterly cash dividends are paid on the Common Stock in respect of any such Dividend Period, the Dividend Payment Date shall mean such date as may be determined by the Board of Directors within three months following the end of such Dividend Period. Dividends on the Convertible Preferred Stock shall accrue based on the then-current dividend amount on a daily basis from the commencement of each Dividend Period. Dividends will cease to accrue in respect of any shares of Convertible Preferred Stock on the Surrender Date (as defined below) in respect of a mandatory conversion pursuant to Section 7(c) or on the Surrender Date in respect of a voluntary conversion pursuant to Section 7(a). Dividends payable on the Convertible Preferred Stock for any Dividend Period constituting less than a full fiscal quarter shall be computed ratably on the basis of a 360-day year or 12 30-day months. Dividends for any Dividend Period shall not be cumulative to the extent not paid in full on each Dividend Payment Date. Dividends on the Convertible Preferred Stock in respect of any Dividend Period unpaid as of the Dividend Payment Date for such Dividend Period shall permanently remain unpaid. The foregoing notwithstanding, dividends on account of arrears for any past Dividend Periods may be declared and paid at any time, without reference to any regular Dividend Payment Date. Dividends shall be payable to the Holders as they appear on the Stock Books not exceeding 40 days preceding the relevant Dividend Payment Date. Dividends shall be paid in cash, by wire transfer in immediately available funds to the accounts designated by the respective Holders in written notices given to the Corporation at least five Business Days prior to the payment date or by such other means as may be agreed to by the Corporation and the respective Holders, such wire transfer to be effected for good value on or before the Dividend Payment Date.

(c) Dividend Rate: Calculation of Dividend Rate: Notice.

(i) The First Dividend Stage shall commence upon the initial issuance of Convertible Preferred Stock and shall cease upon the fifth anniversary of the Closing Date.

(ii) The Second Dividend Stage shall commence upon the fifth anniversary of the Closing Date and shall continue for so long as any shares of Convertible Preferred Stock shall remain outstanding.

(iii) Notwithstanding anything in this Certificate of Designations to the contrary, the holders of the Convertible Preferred Stock shall participate in all Special Dividends on a share for share basis with the holders of Common Stock, as if shares of the Convertible Preferred Stock were converted into Common Stock immediately prior to the record date with respect to each such Special Dividend, and Special Dividends shall not be taken into account in determining the annual dividend rate of the Convertible Preferred Stock for purposes of Section 2(a) hereof.

(d) The Corporation will cause written notice of each dividend amount on the Convertible Preferred Stock to be given to each Holder within five Business Days after it is determined by the Board of Directors. Notwithstanding the foregoing, if the Corporation shall

not declare quarterly cash dividends on its Common Stock for any Dividend Period, the dividend amount on the Convertible Preferred Stock for purposes of Section 2(a) hereof shall be computed by reference to the dividend amount on the Common Stock for the most recent Dividend Period in respect of which dividends (other than Special Dividends) were paid.

(e) Priority as to Dividends; Restriction on Dividends, Redemption, etc. The Corporation shall not, for so long as the Convertible Preferred Stock shall remain outstanding, directly or indirectly, declare or pay or set apart for payment any dividends (including cumulative dividends) or make (or permit any Subsidiary to make) any other distributions on, or payment on account of the purchase, redemption or other retirement or acquisition for value of the Common Stock, any other capital stock of the Corporation ranking junior to the Convertible Preferred Stock as to dividends or as to distribution of assets upon any liquidation, dissolution or winding up of the affairs of the Corporation or any options, warrants or rights to purchase or acquire Common Stock or any such capital stock or any securities convertible into or exchangeable for shares of Common Stock or any such capital stock, except that such payment of dividends and such other distributions and payments may be made so long as full dividends payable on the Convertible Preferred Stock for the Dividend Period commencing immediately prior to the date of such dividend, distribution or other payment have been or are concurrently paid (or a sum sufficient for the payment thereof set apart for such payment subject to declaration thereof); provided, however, that the foregoing restrictions shall not apply to: (i) any dividend payable solely in shares of any stock of the Corporation ranking, as to dividends and as to distribution of assets upon any liquidation, dissolution or winding-up of the affairs of the Corporation, junior to the Convertible Preferred Stock (or payable solely in options, warrants or rights to purchase or acquire any such stock) or (ii) any distribution pursuant to any employee or director incentive or benefit plan or arrangement (including any employment, severance or consulting agreement) of the Corporation or any Subsidiary heretofore or hereafter adopted; or (iii) any distribution pursuant to a redemption, at the stated redemption price, of any rights granted to Holders of Common Stock pursuant to a stockholder rights plan; or (iv) any dividend approved in writing by the holders of at least 66 2/3 percent of all shares of Convertible Preferred Stock then outstanding. Holders of shares of Convertible Preferred Stock shall be entitled to receive dividends in accordance with the foregoing clause (a) of this Section 2 in preference to and in priority over any dividend upon any securities junior to the Convertible Preferred Stock.

3. Voting Rights.

(a) Holders of shares of Convertible Preferred Stock, voting together as a single class with holders of shares of Common Stock (and with holders of any other class or series of stock which may similarly be entitled to vote with the holders of Common Stock) shall be entitled at any meeting of stockholders called for the purpose of voting on (or acting by written consent without need of any advance notice) Opt-out Amendment (as defined in the Merger Agreement) (ii) any proposed amendment to the Certificate of Incorporation or By-Laws which would reasonably have the effect of modifying in any way the Opt-out Amendment or would reasonably cause the Corporation to become subject to (a) the Control Share Acquisition Statute (as defined in the Merger Agreement) or (b) any other provisions which are substantially similar to the Control Share Acquisition Statute or (iii) any transaction or series of transactions submitted to a vote of the stockholders of the Corporation which, if consummated, would

constitute a Change in Control, to vote with respect to such transaction(s). When voting together with the holders of shares of Common Stock on any such transaction(s), each share of Convertible Preferred Stock shall carry, as of the record date applicable to such vote, a number of votes equal to the number of votes carried in the aggregate by the number of shares of Common Stock issuable upon conversion of one share of Convertible Preferred Stock into Common Stock in accordance with Section 7 below.

(b) Except as provided by this Section 3 and Sections 4 and 8 below, or as otherwise may be required by applicable law, the Holders of Convertible Preferred Stock shall not be entitled, by virtue of their being Holders thereof, to vote in any election of directors to the Board of the Corporation, or with respect to any other matter submitted to the stockholders of the Corporation. Where a vote of the Holders, voting as a separate class, may be required by applicable law or by this Section 3 or Section 4 or 8, each share of Convertible Preferred Stock Series A and each share of Convertible Preferred Stock, Series B, shall carry one vote.

4. Covenants.

So long as any shares of Convertible Preferred Stock are outstanding, the Corporation covenants and agrees with and for the benefit of the Holders of such shares that without the affirmative vote or consent of Holders of 66 2/3 percent of all shares of the Convertible Preferred Stock then outstanding, voting as a separate class in person or by proxy or by written consent delivered to the Secretary of the Corporation, the Corporation shall not amend, alter or repeal any provision of the Certificate of Incorporation of the Corporation, this Certificate of Designations, or any amendment or supplement to any of the foregoing, so as to affect adversely the rights, powers, preferences, qualifications, limitations or restrictions of any Holder of Convertible Preferred Stock.

5. Redemption. Shares of the Convertible Preferred Stock shall not be redeemable, in whole or in part, in any event, at the option of the Corporation.

6. Liquidation Preference. In the event of any voluntary or involuntary liquidation, dissolution or winding up of the affairs of the Corporation, the Holders of shares of Convertible Preferred Stock then outstanding shall be entitled to be paid out of the assets of the Corporation available for distribution to its stockholders an amount per share in cash equal to the amount that would be payable on one share of Common Stock (such amount payable being adjusted appropriately to reflect any stock split, stock dividend, reverse stock split, or any transaction with comparable effect upon the Common Stock and assuming conversion of all shares of Convertible Preferred Stock then outstanding into shares of Common Stock immediately prior to such liquidation, dissolution or winding up), plus all dividends then due on the Convertible Preferred Stock (the “Liquidation Preference”). This entitlement of the Holders of shares of Convertible Preferred Stock shall be satisfied before any similar payment shall be made or any assets distributed to the holders of the Common Stock or any other security junior in rank to the Convertible Preferred Stock as to distribution of assets upon such dissolution, liquidation or winding up. If the assets of the Corporation are not sufficient to pay in full the liquidation payments payable to all of the Holders of the outstanding shares of Convertible Preferred Stock, then the Holders of all such shares shall share ratably in such distribution of assets in accordance with the respective liquidation preferences to which they are entitled. For

the purposes of this section, neither the voluntary sale, conveyance, exchange or transfer (for cash, shares of stock, securities or other consideration) of all or substantially all of the property or assets of the Corporation nor the consolidation or merger of the Corporation with one or more other corporations shall be deemed to be a liquidation, dissolution or winding up, voluntary or involuntary; unless such voluntary sale, conveyance, exchange or transfer shall be in connection with a dissolution or winding up of the business of the Corporation.

7. Conversion. (a) Conversion Right. At any time after the occurrence of a Regulatory Change, each share of Convertible Preferred Stock shall be convertible at the option of the Holder thereof into one fully paid and nonassessable share of Common Stock (as adjusted pursuant to Section 7(d) hereof).

(b) (i) Conversion Procedures. Any Holder of shares of Convertible Preferred Stock desiring to convert such shares into Common Stock shall surrender the certificate(s) evidencing such shares of Convertible Preferred Stock of the Holder at the office of the transfer agent appointed for the purpose of such conversion by the Corporation. Such surrendered certificate(s), if the Corporation shall so require, shall be duty endorsed to the Corporation or in blank, or accompanied by proper instruments of transfer to the Corporation or in blank, and, in the case of any conversion other than a mandatory conversion pursuant to clause (c) of this Section 7 below, shall be accompanied by written notice to the Corporation that the Holder elects so to convert such shares of Convertible Preferred Stock, which notice shall specify the name or names (with address or addresses) in which the Holder wishes the certificate(s) evidencing shares of Common Stock to be issued in exchange for that certificate or those certificates so surrendered.

(ii) The Corporation shall, within five Business Days after such surrender of certificates evidencing shares of Convertible Preferred Stock accompanied by written notice and in compliance with any other conditions contained herein, issue and deliver, or cause to be issued and delivered, to the person(s) for whose account such certificate(s) evidencing shares of Convertible Preferred Stock were so surrendered, or to the nominee(s) of such Person(s), certificates representing the number of full shares of Common Stock to which such Person shall be entitled pursuant to the then-applicable conversion rate. Such conversion shall be deemed to have been made on the date of such surrender of the certificate(s) evidencing shares of Convertible Preferred Stock to be converted (the “Surrender Date”) and the Person(s) entitled to receive the Common Stock deliverable upon conversion of such Convertible Preferred Stock shall be treated for all purposes as the record holder(s) of such Common Stock on such date and thereafter. Conversion of Preferred Stock may otherwise be achieved in accordance with such procedures as the Corporation and a majority of the Holders may agree.

(iii) In the event that fewer than all shares of Convertible Preferred Stock represented by a surrendered certificate are to be converted hereunder, a new certificate shall be issued at the Corporation’s expense representing the shares of Convertible Preferred Stock not so converted.

(iv) Effective on the day following the Surrender Date, dividends shall cease to accrue on any shares of Convertible Preferred Stock surrendered for conversion, such shares of Convertible Preferred Stock shall no longer be   deemed outstanding, all rights of the Holders

thereof as preferred stockholders of the Corporation shall cease (other than the right to receive dividends declared or otherwise payable, to Holders of Convertible Preferred Stock on a record date prior to the Surrender Date) and thereupon the certificate(s) theretofore representing shares of Convertible Preferred Stock shall represent only the right to receive the Common Stock deliverable upon conversion in respect thereof.

(v) If any shares of Convertible Preferred Stock are surrendered for conversion subsequent to the record date preceding a Dividend Payment Date but on or prior to such Dividend Payment Dare (except shares called for redemption on a redemption date between such record date and such Dividend Payment Date), the Holder of such shares at the close of business on such record date shall be entitled to receive the dividend payable on such shares on such Dividend Payment Date notwithstanding the conversion thereof.

(c) Mandatory Conversion. Immediately upon the transfer of Beneficial Ownership of any share of Convertible Preferred Stock to any Person other than the Shareholder or an Affiliate of the Shareholder, such share of Convertible Preferred Stock shall convert into one fully-paid and non-assessable share of Common Stock (as adjusted pursuant to Section 7(d)), in accordance with the procedures provided in clause (b) of this Section 7.

(d) The conversion rate shall be adjusted from time to time as follows:

(i) In case the Corporation shall, at any time or from time to time while any of the shares of Convertible Preferred Stock are outstanding: (A) pay a dividend in shares of its Common Stock, (B) subdivide its outstanding shares of Common Stock into a smaller number of shares, or (C) combine its outstanding shares of Common Stock into a smaller number of shares, the conversion rate in effect immediately prior to such action shall be adjusted so that the Holder of any shares of Convertible Preferred Stock thereafter surrendered for conversion shall be entitled to receive the number of shares of Common Stock which such Holder would have owned or have been entitled to receive immediately following such action had such shares of Convertible Preferred Stock been converted immediately prior thereto. An adjustment made pursuant to this Section 7(d)(i) shall become effective retroactively to immediately after the opening of business on the Business Day following the record date in the case of a dividend and shall become effective immediately after the opening of business on the Business Day following the effective date in the case of a subdivision or combination. If, as a result of an adjustment made pursuant to this Section 7(d)(i), the Holder of any shares of Convertible Preferred Stock thereafter surrendered for conversion shall become entitled to receive shares of two or more classes of capital stock of the Corporation, the Board of Directors (whose determination shall be conclusive) shall determine the allocation of the adjusted conversion rate between or among shares of such classes of capital stock.

(ii) In case the Corporation shall, at any time or from time to time while any of the shares of Convertible Preferred Stock are outstanding, issue rights or warrants to all holders of shares of its Common Stock entitling them to subscribe for or purchase shares of Common Stock (or securities convertible into or exchangeable for Common Stock) at a price per share less than the current Market Price per share of Common Stock, at such record date, the conversion rate shall be adjusted so that it shall equal the rate determined by multiplying the conversion rate in effect immediately prior to the date of issuance of such rights or warrants by a

fraction, the numerator of which shall be the number of shares of Common Stock outstanding on the date of issuance of such rights or warrants plus the number of additional shares of Common Stock offered for subscription or purchase, and the denominator of which shall be the number of shares of Common Stock outstanding on the date of issuance of such rights or warrants plus the number of shares which the aggregate offering price of the total number of shares so offered would purchase at such current market price. For the purposes of this Section 7(d)(ii), the issuance of rights or warrants to subscribe for or purchase securities convertible into Common Stock shall be deemed to be the issuance of rights or warrants to purchase the shares of Common Stock into which such securities are convertible at an aggregate offering price equal to the aggregate offering price of such securities plus the minimum aggregate amount (if any) payable upon conversion of such securities into shares of Common Stock; provided, however, that if all of the shares of Common Stock subject to such rights or warrants have not been issued when such rights or warrants expire, then, the conversion rate shall promptly be readjusted to the conversion rate which would then be in effect had the adjustment upon the issuance of such rights or warrants been made on the basis of the actual number of shares of Common Stock issued upon the exercise of such rights or warrants. The foregoing provision shall not apply to issuances of rights pursuant to a stockholder rights plan provided that such rights are issued together with the Common Stock upon conversion of the Convertible Preferred Stock. An adjustment made pursuant to this Section 7(d)(ii) shall become effective retroactively immediately after the record date for the determination of stockholders entitled to receive such rights or warrants.

(iii) In case the Corporation shall, at any time or from time to time while any of the shares of Convertible Preferred Stock are outstanding, distribute to all holders of shares of its Common Stock evidences of its indebtedness or securities or assets (excluding cash dividends payable out of consolidated earnings or retained earnings or dividends payable in shares of Common Stock) or rights or warrants to subscribe for securities of the Corporation or any of its subsidiaries (excluding those referred to in Section 7(d)(ii)), then in each such case the conversion rate shall be adjusted so that it shall equal the rate determined by multiplying the conversion rate in effect immediately prior to the date of such distribution by a fraction, the numerator of which shall be the current Market Price per share of the Common Stock on the record date referred to below, and the denominator of which shall be such current market price per share of the Common Stock less the then fair market value of the portion of the assets or evidences of indebtedness or securities or assets so distributed or of such subscription rights or warrants applicable to one share of Common Stock. Such adjustment shall become effective retroactively immediately after the record date for the determination of stockholders entitled to receive such distribution.

(iv) The Corporation shall be entitled at its option to make such additional adjustments in the conversion rate, in addition to those required by subsections 7(d)(i), 7(d)(ii) and 7(d)(iii), as shall be necessary in order that any dividend or distribution in shares of stock, subdivision or combination of shares of Common Stock, issuance of rights or warrants, evidences of indebtedness or assets (other than cash dividends payable out of consolidated earnings or retained earnings) referred to above, shall not be taxable to the Holders of shares of Convertible Preferred Stock.

(v) In any case in which this Section 7(d) shall require that an adjustment be made retroactively immediately following a record date, the Corporation may elect to defer (but only for five (5) Business Days following the filing of the statement referred to in Section 7(d)(vii)) issuing to the holder of any shares of this Series converted after such record date (A) the shares of Common Stock and other capital stock of the Corporation issuable upon such conversion over and above (B) the shares of Common Stock and other capital stock of the Corporation issuable upon such conversion on the basis of the conversion rate prior to adjustment.

(vi) Notwithstanding any other provisions of this Section 7(d), the Corporation shall not be required to make any adjustment of the conversion rate (A) in respect of any Special Dividend in which the holders of Convertible Preferred Stock participate as provided in Section 2(c)(iii) or (B) unless such adjustment would require an increase or decrease of at least 1% in such rate (any lesser adjustment shall be carried forward and shall be made at the time of and together with the next subsequent adjustment which, together with any adjustment or adjustments so carried forward, shall amount to an increase or decrease of at least 1% in such rate).

(vii) Whenever an adjustment in the conversion rate is required, the Corporation shall forthwith place on file with its Transfer Agent a statement signed by its Chief Executive Officer, Chief Financial Officer or a Vice President and by its Secretary, Assistant Secretary, Treasurer or Assistant Treasurer, stating the adjusted conversion rate determined as provided herein. Such statements shall set forth in reasonable detail such facts as shall be necessary to show the reason and the manner of computing such adjustment. Promptly after the adjustment of the conversion rate, the Corporation shall mail a notice thereof to each holder of shares of Convertible Preferred Stock.

(e) Reservation of Shares; Etc. (i) The Corporation shall at all times reserve and keep available, free from preemptive rights, out of its authorized and unissued stock, such number of shares of its Common Stock as shall from time to time be sufficient to effect the conversion of all shares of the Convertible Preferred Stock from time to time outstanding, solely for the purpose of effecting such conversion. The Corporation shall, from time to time, in accordance with the laws of the State of Oklahoma, increase the authorized number of shares of Common Stock if at any time the number of shares of authorized and unissued Common Stock shall not be sufficient to permit the conversion of all the then-outstanding shares of Convertible Preferred Stock.

(ii) If any shares of Common Stock required to be reserved hereunder for purposes of conversion require registration with or approval of any governmental authority under any Federal or state law before such shares may be issued upon conversion, the Corporation shall, in good faith and as expeditiously as possible, cause such shares to be duly registered or approved as the case may be. If the Common Stock is listed on the New York Stock Exchange or any other national or foreign securities exchange, the Corporation shall, if permitted by the rules of such exchange, list and keep listed on such exchange, upon official notice of issuance, all shares of Common Stock issuable upon conversion of Convertible Preferred Stock.

(iii) The Corporation will pay any and all taxes that may be payable in respect of the issuance or delivery of shares of Common Stock upon conversion of shares of Convertible Preferred Stock pursuant hereto. The Corporation shall not, however, be required to pay any tax which may be payable in respect of any transfer involved in the issuance and delivery of shares of Common Stock in a name other than that in which the shares of Convertible Preferred Stock so converted were registered and no such issuance or delivery shall be made unless and until the person requesting such issuance has paid to the Corporation the amount of any such tax or has established to the satisfaction of the Corporation that such tax has been paid.

(f) Reclassifications, Consolidations, Mergers or Sales of Assets. In case of (i) any reclassification or change of outstanding shares of Common Stock (other than a change in par value or from par value to no par value or from no par value to par value, or as a result of a subdivision or combination) or (ii) any consolidation or merger of the Corporation with one or more other corporations (other than a consolidation or merger in which the Corporation is the continuing corporation and which does not result in any reclassification or change of outstanding shares of Common Stock issuable upon conversion of Convertible Preferred Stock), (iii) any sale or conveyance to another corporation or other entity of all or substantially all of the property of the Corporation, or (iv) any other transaction which would constitute a Change in Control of the Corporation, then the Corporation, or such successor corporation or other entity, as the case may be, shall make appropriate provision so that the holder of each share of Convertible Preferred Stock then outstanding shall have the right to convert such share into the kind and amount of shares of stock or other securities and property receivable upon such consolidation, merger, sale, reclassification, change or conveyance by a holder of the number of shares of Common Stock into which such shares of Convertible Preferred Stock might have been converted immediately prior to such consolidation, merger, sale, reclassification, change or conveyance, subject to adjustment which shall be as nearly equivalent as may be practicable to the adjustments provided for in Section 7(d). The provisions of this paragraph shall apply similarly to successive consolidations, mergers, sales or conveyances.

8. Priority. The Convertible Preferred Stock shall be senior in rank, both as to dividends and as to distribution of assets upon any liquidation, dissolution or winding up of the affairs of the Corporation, to the Common Stock, or any class of equity securities of the Corporation which by its terms are junior to the Convertible Preferred Stock, and shall not be junior in rank with respect to any class or series of preferred stock that may be issued by the Corporation, unless the Holders of 66 2/3 percent of the outstanding shares of the Convertible Preferred Stock shall consent to the creation, reclassification or authorization of any class or series of the Corporation’s capital stock ranking prior to the Convertible Preferred Stock as to dividends or as to distributions of assets upon liquidation, dissolution or winding up of the Corporation, whether voluntary or involuntary, or any security convertible into shares of such class or series. Except as otherwise provided in this Certificate of Designations, the Convertible Preferred Stock, Series A shall be deemed to rank on a parity with the Convertible Preferred Stock, Series B.

9. Notices. The Corporation shall provide notice to each Holder of any action taken or proposed to be taken or any determination made by the Corporation and/or the Shareholder under the terms of this Certificate of Designations. Notice of any such action or determination by the Corporation and/or the Shareholder and all other notices and other

communications provided for in this Certificate of Designations shall be delivered by facsimile and by reputable overnight courier:

	(a)	If to the Corporation, to:
		WAI, Inc. 100 West Fifth Street Tulsa, Oklahoma 74103 Facsimile: (918) 588-7960 Attn: President
		with a copy to:
		Gable Gotwals Mock Schwabe Kihle Gaberino 100 West Fifth Street. Suite 1000 Tulsa, Oklahoma 74103 Facsimile: (918) 583-7873 Attn: Donald H. Kihle, Esq.
		and
		Fried, Frank, Harris, Shriver & Jacobson One New York Plaza New York, New York 10004 Facsimile: (212) 859-4000 Attn: F. William Reindel, Esq.
or such other address as the Corporation shall have furnished to the Holders in writing,
	(b)	if to a Holder and/or the Shareholder, to the address and facsimile number of such Holder listed on the Stock Books of the Corporation.

10. Definitions. Certain capitalized terms are used herein as defined below:

“Affiliate” shall mean, with respect to any Person, any other Person that directly or indirectly through one or more intermediaries controls or is controlled by or is under common control with such Person. For the purposes of this definition, “control,” when used with respect to any particular Person, means the power to direct the management and policies of such Person, directly or indirectly, whether through the ownership of voting securities, by contract or otherwise; and the terms “controlling” and “controlled” have meanings correlative to the foregoing.

“Beneficial Owner” (and, with correlative meanings, “Beneficially Own” and, “Beneficial Ownership”) of any interest means a Person who, together with his, her or its Affiliates, is or may be deemed a beneficial owner of such interest for purposes of Rule 13d-3 or 13d-5 under the Exchange Act of 1934, or who, together with his, her, or its Affiliates, has the right to become such a beneficial owner of such interest (whether such right is exercisable immediately or only

after the passage of time) pursuant to any agreement, arrangement or understanding, or upon the exercise, conversion or exchange of any warrant, right or other instrument, or otherwise.

“Board” shall mean the Board of Directors of the Corporation in office at the applicable time, as elected in accordance with the By-Laws of the Corporation and with the Stockholder Agreement.

“Business Day” means any day other than a Saturday, a Sunday, a day on which the New York Stock Exchange is closed or a day on which state or federally chartered banking institutions in New York, New York are not required to be open.

“By-Laws” shall mean the By-Laws of the Corporation, in the form specified in the Merger Agreement, as they may be amended from time to time.

“Certificate of Designations” means this Certificate of Designations, Powers, Preferences and Relative, Participating, Optional or other Rights, and the Qualifications, Limitations or Restrictions Thereof, creating the Convertible Preferred Stock, Series A and Convertible Preferred Stock, Series B.

“Certificate of Incorporation” shall mean the Certificate of Incorporation of the Corporation, in the form specified in the Merger Agreement, as it may be amended from time to time.

“Change in Control” shall mean the occurrence of any one of the following events:

(1)    any Person (other than WRI and/or its Affiliates) becoming the Beneficial Owner, directly or indirectly, of Voting Securities, pursuant to the consummation of a merger, consolidation, sale of all or substantially all of the Corporation’s assets, share exchange or similar form of corporate transaction involving the Corporation or any of its subsidiaries that requires the approval of the Corporation’s shareholders, whether for such transaction or the issuance of securities in such transaction, so as to cause such Person’s Voting Ownership Percentage to exceed the Control Percentage (as defined below); provided, however, that the event described in this paragraph (1) shall not be deemed to be a Change in Control if it occurs as the result of any of the following acquisitions: (A) by any employee benefit plan sponsored or maintained by the Corporation or any Affiliate, or (B) by any underwriter temporarily holding securities pursuant to an offering of such securities;

(2) the consummation of a merger, consolidation, sale of all or substantially all of the Corporation’s assets, share exchange or similar form of corporate transaction involving the Corporation or any of its subsidiaries that requires the approval of the Corporation’s shareholders, whether for such transaction or the issuance of securities in such transaction, unless immediately following such transaction more than 50 percent of the total voting power of (x) the corporation resulting from such transaction, or (y) if applicable, the ultimate parent corporation that directly or indirectly has Beneficial Ownership of 100 percent of the voting securities eligible to elect directors of such resulting corporation, is represented by Voting

Securities that were outstanding immediately prior to such transaction (or, if applicable, shares into which such Voting Securities were converted pursuant to such transaction), and such voting power among the holders of such Voting Securities that were outstanding immediately prior to such transaction is in substantially the same proportion as the voting power of such Voting Securities among the holders thereof immediately prior to such transaction; or

(3) the consummation of a plan of complete liquidation or dissolution of the Corporation.

“Closing Date” means the date of consummation of the merger of ONEOK with and into the Corporation as provided in the Merger Agreement.

“Code” means the Internal Revenue Code of 1986, as amended.

“Common Stock” has the meaning specified in Section 2(a)(i) above.

“Control Percentage” shall mean a Voting Ownership Percentage of 15 percent, during the period prior to a Regulatory Change, and a Voting Ownership Percentage of 35 percent thereafter.

“Convertible Preferred Stock” has the meaning specified in Section 1 above.

“Dividend Period” means the applicable period from (and including) the Closing Date to the end of the first fiscal quarter after the Closing Date, and each fiscal quarter thereafter.

“Dividend Rate” has the meaning specified in Section 2(c) above.

“First Dividend Stage” has the meaning specified in Section 2(c)(iii) above.

“Holder” means a holder of record of a share or shares of Convertible Preferred Stock.

“Liquidation Preference” has the meaning specified in Section 6 above.

The “Market Price” for the Common Stock shall mean the average of the closing prices for such Common Stock for the twenty (20) Trading Days immediately prior to the date on which the Market Price is being determined; provided, however, that in the event that the current per share market price of the Common Stock is determined during a period following the announcement by the Corporation of (a) a dividend or distribution on the Common Stock payable in shares of Common Stock or securities convertible into Common Stock, or (b) any subdivision, combination or reclassification of the Common Stock and prior to the expiration of 20 Trading Days after the ex-dividend date for such dividend or distribution, or the record date for such subdivision, combination or reclassification, then, and in each such case, the current per share market price shall be appropriately adjusted to take into account ex-dividend trading or the effects of such subdivision, combination or reclassification. The closing price for each Trading Day shall be the last sale price, regular way, or, in case no such sale takes place on such day, the average of the closing bid and asked prices, regular way, in either case as reported in the principal consolidated transaction reporting system of the New York Stock Exchange or, if the

Common Stock is no longer listed or admitted to trading on the New York Stock Exchange, as reported in the principal consolidated transaction reporting system with respect to the principal national securities exchange on which the Common Stock is then listed or admitted to trading or if the Common Stock is no longer listed or admitted to trading on any national securities exchange, the last quoted price or, if not so quoted, the average of the high bid and low asked prices in the over-the-counter market, as reported by the National Association of Securities Dealers, Inc. Automated Quotations System or such other system then in use, or, if on any such date the Common Stock is not quoted by any such organization, the average of the closing bid and asked prices as furnished by a professional market maker making a market in such security selected by a majority of the Board or, if on any such date no market maker is making a market in such security, the fair value as determined in good faith by a majority of the Board based upon the opinion of an independent investment banking firm of recognized standing.

“Merger Agreement” means the Agreement, dated as of December 12, 1996, between ONEOK and WRI, as amended and/or restated from time to time.

“ONEOK” means Oneok, Inc., a Delaware corporation.

“Person” means any individual, corporation, partnership, joint venture, trust, unincorporated organization, government or any agency or political subdivision thereof, or any other entity.

A “Regulatory Change” will be deemed to have occurred upon the receipt by the Shareholder of an opinion of the Shareholder’s counsel (which counsel must be reasonably acceptable to the Corporation) to the effect that either (1) the Public Utility Holding Company Act of 1935 (the “1935 Act”) has been repealed, modified, amended or otherwise changed or (2) the Shareholder has received an exemption, or, in the unqualified opinion of such counsel, is entitled without any regulatory approval to claim an exemption, or has received an approval or no-action letter from the Securities and Exchange Commission or its staff under the 1935 Act or has registered under the 1935 Act, or any combination of the foregoing, and as a consequence of (1) and/or (2) the Shareholder may fully and legally exercise the rights set forth in the Shareholder Agreement which take effect in the period after a Regulatory Change has occurred.

“Second Dividend Stage” has the meaning specified in Section 2(c)(ii) above.

“Shareholder” means WRI.

“Shareholder Agreement” means the Shareholder Agreement, dated as of November 26, 1997 between WAI and WRI.

“Special Dividend” rneans a dividend declared or paid on the Common Stock in respect of a recapitalization, spin-off, reorganization or other extraordinary transaction of the Corporation.

“Stock Books” means the stock transfer books of the Corporation relating to its Common Stock and Preferred Stock.

“Surrender Date” has the meaning specified in Section 7 above.

“Total Voting Power” shall mean, calculated at a particular point in time, the aggregate Votes represented by all then outstanding Voting Securities.

“Trading Day” shall mean a day on which the principal national securities exchange on which the Common Stock is listed or admitted to trading is open for the transaction of business.

“Votes” shall mean votes entitled to be cast generally in the election of any member of the Board, as elected in accordance with the provisions of the By-Laws, not including the votes that would be able to be cast by holders of shares of Convertible Preferred Stock upon the conversion of such shares to shares of Common Stock, unless such conversion shall occur or be deemed to occur.

“Voting Ownership Percentage” shall mean, calculated at a particular point in time, the Voting Power represented by the Voting Securities Beneficially Owned by the Person whose Voting Ownership Percentage is being determined.

“Voting Power” shall mean, calculated at a particular point in time, the ratio, expressed as a percentage, of (a) the Votes represented by the Voting Securities with respect to which the Voting Power is being determined to (b) Total Voting Power.

“Voting Securities” shall mean the Common Stock and shares of any other class of capital stock of the Corporation then entitled to vote generally in the election of any member of the Board, as elected in accordance with the provisions of the By-Laws and shall not include the Convertible Preferred Stock (or other securities convertible into Voting Securities) prior to its conversion into Common Stock (or other Voting Securities).

“WRI” means Western Resources, Inc., a Kansas corporation.

IN WITNESS WHEREOF, WAI, INC. has caused this Certificate to be made under the seal of the Corporation and signed and attested by the undersigned officers of the Corporation this 26th day of November, 1997.

 WAI, INC.

By:	/s/ John K. Rosenberg
Name:	John K. Rosenberg
Title:	President

(Corporate Seal)

Attest:

By:	/s/ Richard D. Terrill
Name:	Richard D. Terrill
Title:	Secretary

6. The Certificate is thirdly corrected by attaching the following to the Certificate as Exhibit B:

EXHIBIT B

CERTIFICATE OF DESIGNATION, PREFERENCES AND

RIGHTS OF SERIES C PARTICIPATING

PREFERRED STOCK OF ONEOK, INC.

(PURSUANT TO SECTION 1032 OF THE GENERAL CORPORATION ACT OF THE STATE OF OKLAHOMA)

We, Larry W. Brummett, Chairman, President, and Chief Executive Officer and Deborah B. Barnes, Secretary of ONEOK, Inc. (the “Corporation”), a corporation organized and existing under the General Corporation Act of the State of Oklahoma, in accordance with the provisions of Section 1007 thereof, DO HEREBY CERTIFY as follows:

That pursuant to the authority conferred upon the Board of Directors by the Certificate of Incorporation of the said Corporation, said Board of Directors on November 26, 1997, voted to create a series of one million shares of Preferred Stock designated as Series C Participating Preferred Stock:

RESOLVED, that pursuant to the authority granted to and vested in the Board of Directors of this Corporation in accordance with the provisions of the Corporation’s Certificate of Incorporation and Section 1032(g) of the General Corporation Law of the State of Oklahoma, the Board of Directors hereby creates a series of Preferred Stock of the Company and hereby states the designation and number of shares, and fixes the relative rights, preferences and limitations thereof (in addition to the provisions set forth in the Corporation’s Certificate of Incorporation which are applicable to the Preferred Stock of all classes and series) as follows:

Section 1. Designation and Amount. There shall be a series of Preferred Stock, par value $0.01 per share, of the Corporation which shall be designated as “Series C Participating Preferred Stock,” par value $0.01 per share, and the number of shares constituting such series shall be one million. Such number of shares may be increased or decreased by resolution of the Board of Directors or by resolution of the Executive Committee of the Board of Directors; provided, that no decrease shall reduce the number of shares of Series C Participating Preferred Stock to a number less than that of the shares then outstanding plus the number of shares issuable upon exercise of outstanding rights, options or warrants or upon conversion of outstanding securities issued by the Corporation.

Section 2. Dividends and Distributions.

(A) Subject to the prior and superior rights of the holders of any shares of any series of Preferred Stock and Preferred Stock ranking prior and superior to the Series C Participating Preferred Stock with respect to dividends, the holders of shares of Series C Participating Preferred Stock in preference to the holders of shares of Common Stock, par value $0.01 per share (the “Common Stock”), of the Corporation and any other junior stock, shall be entitled to receive, when, as and if declared by the Board of Directors out of funds legally available for the

purpose, quarterly dividends payable in cash on the last day of each fiscal quarter of the Corporation in each year or such other dates as the Board of Directors of the Corporation shall approve (each such date being referred to herein as a “Quarterly Dividend Payment Date”), commencing on the first Quarterly Dividend Payment Date after the first issuance of a share or fraction of a share of Series C Participating Preferred Stock in an amount per share (rounded to the nearest cent) equal to the greater of (a) $1.00 or (b) subject to the provision for adjustment hereinafter set forth, 100 times the aggregate per share amount of all cash dividends, and 100 times the aggregate per share amount (payable in kind) of all non-cash dividends or other distributions other than a dividend payable in shares of Common Stock or a subdivision of the outstanding shares of Common Stock (by reclassification or otherwise), declared on the Common Stock since the immediately preceding Quarterly Dividend Payment Date, or, with respect to the first Quarterly Dividend Payment Date, since the first issuance of any share or fraction of a share of Series C Participating Preferred Stock. In the event the Corporation shall at any time after November 26, 1997 (the “Rights Declaration Date”) (i) declare any dividend on Common Stock payable in shares of Common Stock, (ii) subdivide (by a stock split or otherwise) the outstanding Common Stock, or (iii) combine (by a reverse stock split or otherwise) the outstanding Common Stock into a smaller number of shares, then in each such case the amount to which holders of shares of Series C Participating Preferred Stock were entitled immediately prior to such event under clause (b) of the preceding sentence shall be adjusted by multiplying such amount by a fraction the numerator of which is the number of shares of Common Stock outstanding immediately after such event and the denominator of which is the number of shares of Common Stock that were outstanding immediately prior to such event.

(B) The Corporation shall declare a dividend or distribution on the Series C Participating Preferred Stock as provided in paragraph (A) above at the time it declares a dividend or distribution on the Common Stock (other than a dividend payable in shares of Common Stock); provided, that in the event no dividend or distribution shall have been declared on the Common Stock during the period between any Quarterly Dividend Payment Date and the next subsequent Quarterly Dividend Payment Date, a dividend of $1.00 per share on the Series C Participating Preferred Stock shall nevertheless be payable on such subsequent Quarterly Dividend Payment Date.

(C) So long as any shares of the Series C Participating Preferred Stock are outstanding, no dividends or other distributions shall be declared, paid or distributed, or set aside for payment or distribution, on the Common Stock unless, in each case, the dividend required by this Section 2 to be declared on the Series C Participating Preferred Stock shall have been declared.

(D) The holders of the shares of the Series C Participating Preferred Stock shall not be entitled to receive any dividends or other distributions except as provided herein.

(E) Dividends shall begin to accrue and be cumulative on outstanding shares of Series C Participating Preferred Stock from the Quarterly Dividend Payment Date next preceding the date of issue of such shares of Series C Participating Preferred Stock unless the date of issue of such shares is prior to the record date for the first Quarterly Dividend Payment Date, in which case dividends on such shares shall begin to accrue from the date of issue of such shares, or unless the date of issue is a Quarterly Dividend Payment Date or is a date after the record date for the determination of holders of shares of Series C Participating Preferred Stock entitled to receive a

quarterly dividend and before such Quarterly Dividend Payment Date in either of which events such dividends shall begin to accrue and be cumulative from such Quarterly Dividend Payment Date. Accrued but unpaid dividends shall not bear interest. Dividends paid on the shares of Series C Participating Preferred Stock in an amount less than the total of such dividends at the time accrued and payable on such shares shall be allocated pro rata on a share-by-share basis among all such shares at the time outstanding. The Board of Directors may fix a record date for the determination of holders of shares of Series C Participating Preferred Stock entitled to receive payment of a dividend or distribution declared thereon, which record date shall be no more than sixty (60) days prior to the date fixed for the payment thereof.

Section 3. Voting Rights. The holders of shares of Series C Participating Preferred Stock shall have the following voting rights:

(A) Subject to the provision for adjustment hereinafter set forth, each share of Series C Participating Preferred Stock shall entitle the holder thereof to 100 votes on all matters submitted to a vote of the stockholders of the Corporation. In the event the Corporation shall at any time after the Rights Declaration Date (i) declare any dividend on Common Stock payable in shares of Common Stock, (ii) subdivide (by a stock split or otherwise) the outstanding Common Stock, or (iii) combine (by a reverse stock split or otherwise) the outstanding Common Stock into a smaller number of shares, then in each such case the number of votes per share to which holders of shares of Series C Participating Preferred Stock were entitled immediately prior to such event shall be adjusted by multiplying such number by a fraction the numerator of which is the number of shares of Common Stock outstanding immediately after such event and the denominator of which is the number of shares of Common Stock that were outstanding immediately prior to such event.

(B) Except as otherwise provided herein or by law, the holders of shares of Series C Participating Preferred Stock and the holders of shares of Common Stock shall vote together as one class on all matters submitted to a vote of stockholders of the Corporation.

(C) (i) If at any time dividends on any Series C Participating Preferred Stock shall be in arrears in an amount equal to at least six (6) full quarterly dividends (whether or not declared and whether or not consecutive) thereon, the occurrence of such contingency shall mark the beginning of a period (herein called a “default period”) which shall extend until such time when all accrued and unpaid dividends for all previous quarterly dividend periods and for the current quarterly dividend period on all shares of Series C Participating Preferred Stock then outstanding shall have been declared and paid or set apart for payment. During each default period, all holders of Preferred Stock (including holders of the Series C Participating Preferred Stock) with dividends in arrears in an amount equal to at least six (6) full quarterly dividends (whether or not declared and whether or not consecutive) thereon, voting as a class, irrespective of series, shall have the right to elect two (2) Directors.

(ii) During any default period, such voting right of the holders of Series C Participating Preferred Stock may be exercised initially at a special meeting called pursuant to subparagraph (C)(iii) of this Section 3 or at any annual meeting of stockholders, and thereafter at annual meetings of stockholders; provided, that neither such voting right nor the right of the holders of any other series of Preferred Stock or Preferred Stock, if any, to increase, in certain

cases, the authorized number of Directors shall be exercised unless the holders of one-third (1/3) in number of shares of Preferred Stock outstanding shall be present in person or by proxy. The absence of a quorum of the holders of Common Stock shall not affect the exercise by the holders of Preferred Stock of such voting right. At any meeting at which the holders of Preferred Stock shall exercise such voting right initially during an existing default period, they shall have the right, voting as a class, to elect Directors to fill such vacancies, if any, in the Board of Directors as may then exist up to two (2) Directors or, if such right is exercised at an annual meeting, to elect two (2) Directors. If the number which may be so elected at any special meeting does not amount to the required number, the holders of the Preferred Stock shall have the right to make such increase in the number of Directors as shall be necessary to permit the election by them of the required number. After the holders of the Preferred Stock shall have exercised their right to elect Directors in any default period and during the continuance of such period, the number of Directors shall not be increased or decreased except by vote of the holders of Preferred Stock as herein provided or pursuant to the rights of any equity securities ranking senior to or pari passu with the Series C Participating Preferred Stock.

(iii) Unless the holders of Preferred Stock shall, during an existing default period, have previously exercised their right to elect Directors, the Board of Directors may order, or any stockholder or stockholders owning in the aggregate not less than ten percent (10%) of the total number of Preferred Stock outstanding, irrespective of series, may request, the calling of a special meeting of the holders of Preferred Stock, which meeting shall thereupon be called by the Chairman of the Board or the President of the Corporation. Notice of such meeting and of any annual meeting at which holders of Preferred Stock are entitled to vote pursuant to this subparagraph (C)(iii) of Section 3 shall be given to each holder of record of Preferred Stock by mailing a copy of such notice to him at his last address as the same appears on the books of the Corporation. Such meeting shall be called for a time not earlier than ten (10) days and not later than sixty (60) days after such order or request, or in default of the calling of such meeting within sixty (60) days after such order or request, such meeting may be called on similar notice by any stockholder or stockholders owning in the aggregate not less than ten percent (10%) of the total number of shares of Preferred Stock outstanding. Notwithstanding the provisions of this subparagraph (C)(iii) of Section 3, no such special meeting shall be called during the period within sixty (60) days immediately preceding the date fixed for the next annual meeting of the stockholders.

(iv) In any default period, the holders of Common Stock, and other classes of stock of the Corporation if applicable, shall continue to be entitled to elect the whole number of Directors until the holders of Preferred Stock shall have exercised their right to elect two (2) Directors voting as a class, after the exercise of which right (x) the Directors so elected by the holders of Preferred Stock shall continue in office until their successors shall have been elected by such holders or until the expiration of the default period, and (y) any vacancy in the Board of Directors may (except as provided in subparagraph (C)(ii) of this Section 3) be filled by a vote of a majority of the remaining Directors theretofore elected by the holders of the class of stock which elected the Director whose office shall become vacant. References in this paragraph (C) to Directors elected by the holders of a particular class of stock shall include Directors elected by such Directors to fill vacancies as provided in clause (y) of the foregoing sentence.

(v) Immediately upon the expiration of a default period, (x) the right of the holders of Preferred Stock as a class to elect Directors shall cease, (y) the term of any Directors elected by the holders of Preferred Stock as a class shall terminate, and (z) the number of Directors shall be such number as may be provided for in the Corporation’s Certificate of Incorporation or By-laws irrespective of any increase made pursuant to the provisions of subparagraph (C)(ii) of this Section 3 (such number being subject, however, to change thereafter in any manner provided by law or in the Corporation’s Certificate of Incorporation or By-Laws). Any vacancies in the Board of Directors effected by the provisions of clauses (y) and (z) in the preceding sentence may be filled by a majority of the remaining Directors.

(D) Except as set forth herein, holders of Series C Participating Preferred Stock shall have no special voting rights and their consent shall not be required (except to the extent they are entitled to vote with holders of Common Stock as set forth herein) for taking any corporate action.

Section 4. Certain Restrictions.

(A) Whenever quarterly dividends or other dividends or distributions payable on the Series C Participating Preferred Stock as provided in Section 2 are in arrears, thereafter and until all accrued and unpaid dividends and distributions, whether or not declared, on shares of Series C Participating Preferred Stock outstanding shall have been paid in full, the Corporation shall not:

(i) Declare or pay dividends on, make any other distributions on, or redeem or purchase or otherwise acquire for consideration any shares of stock ranking junior (either as to dividends or upon liquidation, dissolution or winding up) to the Series C Participating Preferred Stock;

(ii) Declare or pay dividends on or make any other distributions on any shares of stock ranking on a parity (either as to dividends or upon liquidation, dissolution or winding up) with the Series C Participating Preferred Stock except dividends paid ratably on the Series C Participating Preferred Stock and all such parity stock on which dividends are payable or in arrears in proportion to the total amounts to which the holders of all such shares are then entitled;

(iii) Redeem or purchase or otherwise acquire for consideration shares of any stock ranking on a parity (either as to dividends or upon liquidation, dissolution or winding up) with the Series C Participating Preferred Stock; provided, however, that the Corporation may at any time redeem, purchase or otherwise acquire shares of any such parity stock in exchange for shares of any stock of the Corporation ranking junior (either as to dividends or upon dissolution, liquidation or winding up) to the Series C Participating Preferred Stock; or

(iv) Purchase or otherwise acquire for consideration any shares of Series C Participating Preferred Stock or any shares of stock ranking on a parity with the Series C Participating Preferred Stock except in accordance with a purchase offer made in writing or by publication (as determined by the Board of Directors) to all holders of such shares upon such terms as the Board of Directors, after consideration of the respective annual dividend rates and

other relative rights and preferences of the respective series and classes, shall determine in good faith will result in fair and equitable treatment among the respective series or classes.

(B) The Corporation shall not permit any subsidiary of the Corporation to purchase or otherwise acquire for consideration any shares of stock of the Corporation unless the Corporation could, under paragraph (A) of this Section 4, purchase or otherwise acquire such shares at such time and in such manner.

Section 5. Reacquired Shares. Any shares of Series C Participating Preferred Stock purchased or otherwise acquired by the Corporation in any manner whatsoever shall be retired and canceled promptly after the acquisition thereof. All such shares shall upon their cancellation become authorized but unissued shares of Preferred Stock and may be reissued as part of a new series of Preferred Stock to be created by resolution or resolutions of the Board of Directors, subject to the conditions and restrictions on issuance set forth herein.

Section 6. Liquidation, Dissolution or Winding Up.

(A) Upon any liquidation (voluntary or otherwise), dissolution or winding up of the Corporation, no distribution shall be made to the holders of shares of stock ranking junior (either as to dividends or upon liquidation, dissolution or winding up) to the Series C Participating Preferred Stock unless, prior thereto, the holders of shares of Series C Participating Preferred Stock shall have received per share, the amount of $1.00, plus an amount equal to accrued and unpaid dividends and distributions thereon, whether or not declared, to the date of such payment (the “Series C Liquidation Preference”). Following the payment of the full amount of the Series C Liquidation Preference, no additional distributions shall be made to the holders of shares of Series C Participating Preferred Stock unless, prior thereto, the holders of shares of Common Stock shall have received an amount per share (the “Common Adjustment”) equal to the quotient obtained by dividing (i) the Series C Liquidation Preference by (ii) 100 (as appropriately adjusted as set forth in paragraph (C) of this Section 6 below to reflect such events as stock splits, stock dividends and recapitalizations with respect to the Common Stock) (such number in clause (ii), the “Adjustment Number”). Following the payment of the full amount of the Series C Liquidation Preference and the Common Adjustment in respect of all outstanding shares of Series C Participating Preferred Stock and Common Stock, respectively, holders of Series C Participating Preferred Stock and holders of shares of Common Stock shall receive their ratable and proportionate share of the remaining assets to be distributed in the ratio of the Adjustment Number to 1 with respect to such Preferred Stock and Common Stock, on a per share basis, respectively.

(B) In the event there are not sufficient assets available to permit payment in full of the Series C Liquidation Preference and the liquidation preferences of all other series of Preferred Stock, if any, which rank on a parity with the Series C Participating Preferred Stock, then such remaining assets shall be distributed ratably to the holders of such parity shares in proportion to their respective liquidation preferences. In the event there are not sufficient assets available to permit payment in full of the Common Adjustment, then such remaining assets shall be distributed ratably to the holders of Common Stock.

(C) In the event the Corporation shall at any time after the Rights Declaration Date (i) declare any dividend on Common Stock payable in shares of Common Stock, (ii) subdivide the outstanding Common Stock, or (iii) combine the outstanding Common Stock into a smaller number of shares, then in each case the Adjustment Number in effect immediately prior to such event shall be adjusted by multiplying such Adjustment Number by a fraction the numerator of which is the number of shares of Common Stock outstanding immediately after such event and the denominator of which is the number of shares of Common Stock that were outstanding immediately prior to such event.

Section 7. Consolidation, Merger, etc. If the Corporation shall enter into any consolidation, merger, combination or other transaction in which the shares of Common Stock are exchanged for or changed into other stock or securities, cash and/or any other property, then in any such event the shares of Series C Participating Preferred Stock shall at the same time be similarly exchanged or changed in an amount per share (subject to the provision for adjustment hereinafter set forth) equal to the Adjustment Number times the aggregate amount of stock, securities, cash and/or any other property (payable in kind), as the case may be, into which or for which each share of Common Stock is changed or exchanged.

Section 8. No Redemption. The shares of Series C Participating Preferred Stock shall not be redeemable.

Section 9. Ranking. The Series C Participating Preferred Stock shall rank junior to all other series of the Corporation’s Preferred Stock as to the payment of dividends and the distribution of assets, unless the terms of any such series shall provide otherwise.

Section 10. Fractional Shares. The Series C Participating Preferred Stock may be issued in fractions of a share which shall entitle the holder, in proportion to such holder’s fractional shares, to exercise voting rights, receive dividends, participate in distributions and to have the benefit of all other rights of holders of Series C Participating Preferred Stock.

Section 11. Amendment. The Certificate of Incorporation of the Corporation shall not be further amended in any manner which would materially alter or change the powers, preferences or special rights of the Series C Participating Preferred Stock so as to affect them adversely without the affirmative vote of the holders of a majority or more of the outstanding shares of Series C Participating Preferred Stock, voting separately as a class.

Section 12. Effective Date. This Certificate of Designation, Preferences and Rights of Series C Participating Preferred Stock of ONEOK, Inc. shall be effective at 5:00 P.M., Eastern Standard Time, on ____________, 1997.

IN WITNESS WHEREOF, I have executed and subscribed this Certificate and do affirm the foregoing as true under penalties of perjury this day of 26th day of November, 1997.

ONEOK, INC.
By:	/s/ Larry W. Brummett
Name:	Larry W. Brummett
Title:	Chairman of the Board and Chief Executive Officer

Attest:
By:	/s/ Nancy Robertson
Name:	Nancy Robertson
Title:	Secretary

IN WITNESS WHEREOF, ONEOK, Inc. has caused this Certificate of Correction to be executed in its name by a Vice President and attested by its Assistant Secretary, this 5th day of November, 2008.

By:	/s/ Eric Grimshaw
Name:	Eric Grimshaw
Title:	Vice President, Associate General Counsel and Corporate Secretary

By:	/s/ John R. Barker
Name:	John R. Barker
Title:	Senior Vice President, General Counsel and Assistant Secretary

FILED - Oklahoma Secretary of State #1900584812 5/23/2012

TO:         OKLAHOMA SECRETARY OF STATE

2300 N. Lincoln Blvd., Room 101, State Capitol Building

Oklahoma City, Oklahoma 73105-4897

(405) 521-3912

AMENDED

CERTIFICATE OF INCORPORATION

OF

ONEOK, INC.

The undersigned Oklahoma corporation, for the purpose of amending its amended and restated certificate of incorporation as provided by Section 1077 of the Oklahoma General Corporation Act, hereby certifies that:

1.	The name of the corporation is ONEOK, Inc. (the “Corporation”).
2.	The name of the registered agent and the street address of the registered office in the State of Oklahoma is: National Registered Agents, Inc., 115 S.W. 89th Street, Oklahoma City, Oklahoma, Oklahoma County 73139-8505.
3.	The duration of the Corporation is perpetual.
4.	The aggregate number of authorized shares of the Corporation prior to the amendment described below is 400,000,000 shares, of which 100,000,000 shares, par value $0.01 per share, are designated Preferred Stock and 300,000,000 shares, par value $0.01 per share, are designated Common Stock.
5.	The Corporation’s amended and restated certificate of incorporation, as amended to date, shall be amended by deleting the initial paragraph of Article FOURTH thereof and replacing such paragraph with the following:

 “The total number of shares of all classes of capital stock which the Corporation shall have authority to issue is 700,000,000 shares divided into two classes, of which 100,000,000 shares, par value $0.01 per share, shall be designated Preferred Stock and 600,000,000 shares, par value $0.01 per share, shall be designated Common Stock.”

6.

At a meeting of the Corporation’s Board of Directors duly called and held on February 15, 2012, a resolution was duly adopted setting forth the foregoing proposed amendment to the amended and restated certificate of incorporation of the Corporation, declaring said amendment to be advisable and directing that the proposed amendment be considered at the next annual meeting of the Corporation’s shareholders.

7.

Pursuant to said resolution of the Corporation’s Board of Directors, at the annual meeting of shareholders of the Corporation duly called and held on May 23, 2012, the necessary number of shares as required by Section 1077 of the Oklahoma General Corporation Act were voted in favor of the proposed amendment, and the amendment was duly adopted in accordance with the provisions of Section 1077 of the Oklahoma General Corporation Act.

(00042293-1)

IN WITNESS WHEREOF, the Corporation has caused this certificate to be signed by its Chairman of the Board and Chief Executive Officer and attested by its Secretary, this 23rd day of May, 2012.

     ONEOK, INC.

 ATTEST:                                                                     By:             /s/ John W. Gibson                   

     Name:       John W. Gibson

     Title:         Chairman of the Board and

      Chief Executive Officer

     By:                /s/ Eric Grimshaw                  

     Name:           Eric Grimshaw

     Title:            Vice President, Associate

     General Counsel and Secretary

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(00042293-1)

EX-10.1

Exhibit 10.1

Execution Version

June 11, 2012

To: ONEOK, Inc.

100 West Fifth Street

Tulsa, OK  74103

Attn:  Robert Martinovich

Telephone:  918-588-7941

Facsimile:  918-588-7971

From Goldman, Sachs & Co.

200 West Street

New York, NY 10282-2198

Attn: Jason Lee

Telephone: 212-902-0923

Facsimile: 212-346-2126

Re: Issuer Forward Repurchase Transaction

(GS&Co. Reference Number:SDB 4166045216)

Ladies and Gentlemen:

The purpose of this communication (this “Confirmation”) is to confirm the terms and conditions of the Transaction entered into between Goldman, Sachs & Co.(“GS&Co.”) and ONEOK, Inc. (“Counterparty”) on the Trade Date specified below (the “Transaction”).  The terms of the Transaction shall be set forth in this Confirmation.  This Confirmation shall constitute a “Confirmation” as referred to in the ISDA Master Agreement specified below.

1.             This Confirmation is subject to, and incorporates, the definitions and provisions of the 2006 ISDA Definitions (including the Annex thereto) (the “2006 Definitions”) and the definitions and provisions of the 2002 ISDA Equity Derivatives Definitions (the “Equity Definitions,” and together with the 2006 Definitions, the “Definitions”), in each case as published by the International Swaps and Derivatives Association, Inc. (“ISDA”).  In the event of any inconsistency between the 2006 Definitions and the Equity Definitions, the Equity Definitions will govern.

This Confirmation evidences a complete and binding agreement between GS&Co. and Counterparty as to the terms of the Transaction to which this Confirmation relates.  This Confirmation shall be subject to and form a part of an agreement (the “Agreement”) in the form of the ISDA 2002 Master Agreement (the “ISDA Form”) as if GS&Co. and Counterparty had executed an agreement in such form (without any Schedule but with the following elections:  (i) the replacement of the word “first” in the third line of Section 5(a)(i) with the word “second,” (ii)the election that the “Cross Default” provisions of Section 5(a)(vi) shall apply to Counterparty and to GS&Co., with a “Threshold Amount”, in each case, of USD50 million; provided that Section 5(a)(vi) is amended to delete the phrase “, or becoming capable at such time of being declared,” from line 7 thereof, (iii) the deletion of both occurrences of the number “15” in Section 5(a)(vii) and their replacement with the number “30,” (iv) the insertion of “, absent manifest error” immediately before the period at the end of the last sentence of Section 6(d)(i), and (v) such other elections as may be set forth in this Confirmation).  The Transaction shall be the only Transaction under the Agreement.

All provisions contained in, or incorporated by reference to, the Agreement will govern this Confirmation except as expressly modified herein.  In the event of any inconsistency between this Confirmation and either the Definitions or the Agreement, this Confirmation shall govern.  The Transaction is a Share Forward Transaction within the meaning set forth in the Equity Definitions.

2.             The terms of the particular Transaction to which this Confirmation relates are as follows:

General Terms:

Trade Date: June 11, 2012

Seller: GS&Co.

Buyer: Counterparty

Shares: The common stock of Counterparty, par value USD 0.01 per share (Ticker Symbol: “OKE”)

Prepayment: Applicable

Prepayment Amount: As provided in Annex B to this Confirmation.

Prepayment Date: The first Exchange Business Day following the Trade Date

Exchange: New York Stock Exchange

Related Exchange(s): All Exchanges

Calculation Agent: GS&Co.; provided that, following the occurrence of an Event of Default pursuant to Section 5(a)(vii) of the Agreement with respect to which GS&Co. is the Defaulting Party, Counterparty shall have the right to designate a nationally recognized third-party dealer in over-the-counter corporate equity derivatives to act, during the period commencing on the date such Event of Default occurred and ending on the Early Termination Date with respect to such Event of Default, as the Calculation Agent.  Following any determination or calculation by the Calculation Agent hereunder, upon a written request by Counterparty, the Calculation Agent will, as promptly as practicable (but in any event no later than five (5) Exchange Business Days following the later of (i) the date of such written request and (ii) the date of such determination or calculation), provide to Counterparty by e-mail, to the e-mail address provided by Counterparty in such written request, a report (in a commonly used file format for the storage and manipulation of financial data without disclosing any proprietary models of the Calculation Agent or any information that GS&Co. determines, based on the advice of outside counsel, is subject to a duty, whether arising by contract, regulation or operation of law, of confidentiality GS&Co. owes to any third party) displaying in reasonable detail the basis for such determination or calculation.

Valuation Terms:

Averaging Dates: Each of the consecutive Exchange Business Days commencing on, and including, the Exchange Business Day immediately following the Trade Date and ending on, and including, the Final Averaging Date.

Final Averaging Date: The Scheduled Final Averaging Date; provided that GS&Co. shall have the right, in its absolute discretion, at any time to accelerate the Final Averaging Date, in whole or in part, to any date that is on or after the Scheduled Earliest Acceleration Date by written notice to Counterparty no later than 8:00 P.M., New York City time, on the Exchange Business Day immediately following the accelerated Final Averaging Date.

In the case of  any acceleration of the Final Averaging Date in part (a “Partial Acceleration”), GS&Co. shall specify in its written notice to Counterparty accelerating the Final Averaging Date the corresponding percentage of the Prepayment Amount that is subject to valuation on the related Valuation Date, and Calculation Agent shall adjust the terms of the Transaction as it deems appropriate, acting in good faith and in a commercially reasonable manner, in order to take into account the occurrence of such Partial Acceleration

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(including cumulative adjustments to take into account all Partial Accelerations that occur during the term of the Transaction).

Scheduled Final Averaging Date: As provided in Annex B to this Confirmation.

Scheduled Earliest Acceleration Date: As provided in Annex B to this Confirmation.

Valuation Date: The Final Averaging Date.

Averaging Date Disruption: Modified Postponement; provided that, notwithstanding anything to the contrary in the Equity Definitions, if a Market Disruption Event occurs on any Averaging Date, the Calculation Agent may, if appropriate in light of market conditions, regulatory considerations or otherwise, take any or all of the following actions: (i) postpone the Scheduled Final Averaging Date in accordance with Modified Postponement (as modified herein) and/or (ii) determine that such Averaging Date is a Disrupted Day only in part, in which case the Calculation Agent shall (x) determine the VWAP Price for such Disrupted Day based on Rule 10b-18 eligible transactions in the Shares on such Disrupted Day taking into account the nature and duration of such Market Disruption Event and (y) determine the Settlement Price based on an appropriately weighted average instead of the arithmetic average described under “Settlement Price” below.  Any Exchange Business Day on which, as of the date hereof, the Exchange is scheduled to close prior to its normal close of trading shall be deemed not to be an Exchange Business Day; if a closure of the Exchange prior to its normal close of trading on any Exchange Business Day is first scheduled following the date hereof, then such Exchange Business Day shall be deemed to be a Disrupted Day in full.

Market Disruption Events: Section 6.3(a) of the Equity Definitions is hereby amended (A) by deleting the words “during the one hour period that ends at the relevant Valuation Time, Latest Exercise Time, Knock-in Valuation Time or Knock-out Valuation Time, as the case may be” in clause (ii) thereof and inserting the words “on any Scheduled Trading Day during the Relevant Period,” after “material,” in the third line thereof and (B) by replacing the words “or (iii) an Early Closure” therein with “(iii) an Early Closure, or (iv) a Regulatory Disruption”.

Section 6.3(d) of the Equity Definitions is hereby amended by deleting the remainder of the provision following the term “Scheduled Closing Time” in the fourth line thereof.

Regulatory Disruption: Any event that GS&Co., in its good faith, commercially reasonable discretion based on the advice of nationally recognized outside counsel, determines makes it appropriate with regard to any legal, regulatory or self-regulatory requirements or related policies and procedures (provided that such requirements, policies or procedures relate to legal or regulatory issues and are generally applicable in similar situations and applied to the Transaction in a non-discriminatory manner) for GS&Co. to refrain from or decrease any market activity in connection with the Transaction. GS&Co. shall notify Counterparty as soon as reasonably practicable that a Regulatory Disruption has occurred and the Averaging Dates affected by it and shall subsequently promptly notify Counterparty in writing

3

on the day GS&Co. determines that it may resume its market activity in connection with the Transaction.

Settlement Terms:

Initial Share Delivery: On the Initial Share Delivery Date, GS&Co. shall deliver to Counterparty the Initial Shares.

Initial Share Delivery Date: The first Exchange Business Day following the Trade Date.

Initial Shares: As provided in Annex B to this Confirmation.

Settlement Date: The date that falls one Settlement Cycle following the Valuation Date.

Settlement: On the Settlement Date, GS&Co. shall deliver to Counterparty the Number of Shares to be Delivered, if a positive number. If the Number of Shares to be Delivered is a negative number, the Counterparty Settlement Provisions in Annex A shall apply.

Number of Shares to be Delivered: A number of Shares equal to (a) the Prepayment Amount divided by (b) the Divisor Amount; provided that the Number of Shares to be Delivered as so determined shall be reduced by the number of Shares delivered on the Initial Share Delivery Date.

Divisor Amount: The greater of (i) the Settlement Price minus the Discount and (ii) $1.00.

Settlement Price: The arithmetic average of the VWAP Prices for all Averaging Dates.

VWAP Price: For any Averaging Date, the Rule 10b-18 dollar volume weighted average price per Share for such day based on transactions executed during such day, as reported on Bloomberg Page “OKE <Equity> AQR_SEC” (or any successor thereto) or, in the event such price is not so reported on such day for any reason or is manifestly incorrect, as determined by the Calculation Agent using a volume weighted method.

Discount: As provided in Annex B to this Confirmation.

Excess Dividend Amount: For the avoidance of doubt, all references to the Excess Dividend Amount in Section 9.2(a)(iii) of the Equity Definitions shall be deleted.

Other Applicable Provisions: To the extent either party is obligated to deliver Shares hereunder, the provisions of the last sentence of Section 9.2 and Sections 9.8, 9.9, 9.10, 9.11 (except that the Representation and Agreement contained in Section 9.11 of the Equity Definitions shall be modified by excluding any representations therein relating to restrictions, obligations, limitations or requirements under applicable securities laws arising as a result of the fact that Counterparty is the Issuer of the Shares) and 9.12 of the Equity Definitions will be applicable as if “Physical Settlement” applied to the Transaction.

Dividends:

Dividend: Any dividend or distribution on the Shares other than any dividend or distribution of the type described in Sections 11.2(e)(i), 11.2(e)(ii)(A) or 11.2(e)(ii)(B) of the Equity Definitions.

Share Adjustments:

Method of Adjustment: Calculation Agent Adjustment; provided that the declaration or payment of Dividends shall not be a Potential Adjustment Event.

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It shall constitute an additional Potential Adjustment Event if the Scheduled Final Averaging Date is postponed pursuant to “Averaging Date Disruption” above, in which case the Calculation Agent may, in its good faith and commercially reasonable discretion, adjust any relevant terms of the Transaction as the Calculation Agent determines appropriate to account for the economic effect on the Transaction of such postponement, based on the volatility, expected dividends, stock loan rate or liquidity relative to the relevant Shares.

Extraordinary Events:

Consequences of Merger Events:

(a)  Share-for-Share: Modified Calculation Agent Adjustment

(b)  Share-for-Other: Cancellation and Payment on that portion of the Other Consideration that consists of cash; Modified Calculation Agent Adjustment on the remainder of the Other Consideration

(c)  Share-for-Combined: Component Adjustment

Tender Offer: Applicable

Consequences of Tender Offers:

(a)  Share-for-Share: Modified Calculation Agent Adjustment

(b)  Share-for-Other: Modified Calculation Agent Adjustment

(c)  Share-for-Combined: Modified Calculation Agent Adjustment

provided that, without limiting the generality of clause (ii) of Section 12.3(d) of the Equity Definitions, if, in respect of any of clauses (a) through (c) of “Tender Offer” above, GS&Co. concludes, in its good faith and commercially reasonable discretion and based on the advice of nationally recognized outside counsel, that, as a result of any legal, regulatory or self-regulatory requirements or related policies and procedures (whether or not such requirements, policies or procedures are imposed by law or have been voluntarily adopted generally by GS&Co., but provided that such policies or procedures are related to legal, regulatory or self-regulatory issues and are generally applicable in similar situations and applied to the Transaction in a non-discriminatory manner):

(i)  it is appropriate to cancel the Transaction; or

(ii)  it is no longer advisable to hedge the Transaction in the manner contemplated on the Trade Date for such Transaction,

then, in each case, Cancellation and Payment shall apply to the Transaction; provided further that, solely for purposes of clauses (i) and (ii) above, and notwithstanding “Consequences of Announcement Events” below, Sections 12.3(a) and 12.3(d) of the Equity Definitions shall each be amended by replacing each occurrence of the words “Tender Offer Date” by “Announcement Date.”

Modified Calculation Agent Adjustment: For greater certainty, the definition of “Modified Calculation Agent Adjustment” in Sections 12.2 and 12.3 of the Equity Definitions shall be amended by (i) adding the following italicized language after the stipulated parenthetical provision: “(including adjustments to account 

5

for changes in volatility, expected dividends, stock loan rate or liquidity relevant to the Shares or to the Transaction) from the Exchange Business Day immediately preceding the Announcement Date to the first Exchange Business Day immediately following the Merger Date (Section 12.2) or Tender Offer Date (Section 12.3).” and (ii) deleting the phrase “expected dividends,” from such stipulated parenthetical provision.

Composition of Combined Consideration: Not Applicable

Consequences of Announcement Events: Modified Calculation Agent Adjustment as set forth in Section 12.3(d) of the Equity Definitions; provided that references to “Tender Offer” shall be replaced by references to “Announcement Event” and references to “Tender Offer Date” shall be replaced by references to “Announcement Date.”  An Announcement Event shall be an “Extraordinary Event” for purposes of the Equity Definitions, to which Article 12 of the Equity Definitions is applicable.

Announcement Event: The occurrence of an Announcement Date in respect of a potential Acquisition Transaction (as defined in Section 9 below).

Announcement Date: The date of the first public announcement in relation to an Acquisition Transaction, or any publicly announced change or amendment to the announcement giving rise to an Announcement Date.

Provisions applicable to Merger Events and Tender Offers: The consequences set forth opposite “Consequences of Merger Events” and “Consequences of Tender Offers” above shall apply regardless of whether a particular Merger Event or Tender Offer relates to an Announcement Date for which an adjustment has been made pursuant to Consequences of Announcement Events, without duplication of any such adjustment.

New Shares: In the definition of New Shares in Section 12.1(i) of the Equity Definitions, the text in clause (i) thereof shall be deleted in its entirety (including the word “and” following such clause (i)) and replaced with “publicly quoted, traded or listed on any of the New York Stock Exchange, The NASDAQ Global Select Market or The NASDAQ Global Market (or their respective successors)”.

Nationalization, Insolvency or Delisting: Cancellation and Payment (Calculation Agent Determination); provided that in addition to the provisions of Section 12.6(a)(iii) of the Equity Definitions, it shall also constitute a Delisting if the Exchange is located in the United States and the Shares are not immediately re-listed, re-traded or re-quoted on any of the New York Stock Exchange, The NASDAQ Global Market or The NASDAQ Global Select Market (or their respective successors); if the Shares are immediately re-listed, re-traded or re-quoted on any such exchange or quotation system, such exchange or quotation system shall thereafter be deemed to be the Exchange.

Additional Disruption Events:

Change in Law: Applicable; provided that in respect of the Transaction a Change in Law shall occur only if the Hedging Party (x) was unable, after using good faith and commercially reasonable efforts, to replace its existing 

6

Hedge Positions on commercially reasonable pricing terms with alternative Hedge Positions in respect of the Transaction to avoid the Change in Law that would have otherwise occurred absent such change in the Hedge Positions and (y) in the event (x) applies, has used good faith and commercially reasonable efforts to transfer its rights and obligations under the Transaction to the extent necessary to avoid such Change in Law and failed to so effect such transfer on commercially reasonable pricing terms pursuant to Section 10(f) below.

Failure to Deliver: Applicable

Insolvency Filing: Applicable

Hedging Disruption: Applicable

Increased Cost of Hedging: Applicable

Loss of Stock Borrow: Applicable

MaximumStock Loan Rate: As provided in Annex B to this Confirmation.

Increased Cost of Stock Borrow: Applicable

Initial Stock Loan Rate: As provided in Annex B to this Confirmation.

Hedging Party: For all applicable Potential Adjustment Events and Extraordinary Events, GS&Co..

Determining Party: For all Extraordinary Events, GS&Co.; provided that, upon receipt of written request from Counterparty, Determining Party shall promptly (but in no event later than within five Scheduled Trading Days from the receipt of such request) provide Counterparty with a written explanation describing in reasonable detail any determination made by Determining Party (including any quotations, market data or information from internal sources used in making such calculations, but without requiring any disclosure of confidential information or GS&Co.’s proprietary models or any information that GS&Co. determines, based on the advice of outside counsel, is subject to a duty, whether arising by contract, regulation or operation of law, of confidentiality GS&Co. owes to any third party).  Whenever the Determining Party is required to act or to exercise judgment in any way, it will do so in good faith and in a commercially reasonable manner.

Non-Reliance: Applicable

Agreements and Acknowledgments Regarding Hedging Activities: Applicable

Additional Acknowledgments: Applicable

3.             Account Details:

(a)  Account for delivery of Shares to Counterparty: To be advised

(b)  Account for payments to Counterparty: To be advised

(c)  Account for payments to GS&Co. To be advised

Chase Manhattan Bank New York

For A/C Goldman, Sachs & Co.

A/C #930-1-011483

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ABA: 021-000021

4.             Offices:

(a)  The Office of Counterparty for the Transaction is: Counterparty is not a Multibranch Party

(b)  The Office of GS&Co. for the Transaction is:

Goldman, Sachs & Co.

200 West Street

New York, NY 10282-2198

5.             Notices:  For purposes of this Confirmation:

(a)  Address for notices or communications to Counterparty:

ONEOK, Inc.

100 West Fifth Street

Tulsa, OK  74013

Attn:

Telephone:

Facsimile:

(b)  Address for notices or communications to GS&Co.:

Goldman, Sachs & Co.

200 West Street

New York, NY 10282-2198

Attention: Jason Lee, Equity Capital Markets

Telephone: 212-902-0923

Facsimile: 212-346-2126

Email: jason.lee@ny.ibd.email.gs.com

With a copy to:

Attention: Daniel Josephs

Equity Capital Markets

Telephone: +1-212-902-8193

Facsimile: +1-917-977-3943

Email: daniel.jospehs@ny.ibd.email.gs.com

And email notification to the following address:

Eq-derivs-notifications@am.ibd.gs.com

6.             Additional Provisions Relating to Transactions in the Shares.

(a)           Counterparty acknowledges and agrees that the Initial Shares delivered on the Initial Share Delivery Date may be sold short to Counterparty. Counterparty further acknowledges and agrees that GS&Co. may, during (i) the period from the date hereof to the Valuation Date or, if later, the Scheduled Earliest Acceleration Date without regard to any adjustment thereof pursuant to “Special Provisions regarding Transaction Announcements” below, and (ii) the period from and including the first Settlement Valuation Date to and including the last Settlement Valuation Date, if any (together, the “Relevant Period”), purchase Shares in connection with the Transaction, which Shares may be used to cover all or a portion of such short sale or may be delivered to Counterparty.  Such purchases will be conducted independently of Counterparty.  The timing of such purchases by GS&Co., the number of Shares purchased by GS&Co. on any day, the price paid per Share pursuant to such purchases and the manner in which such purchases are made, including without limitation whether such purchases are made on any securities exchange or privately, shall be within the absolute discretion of GS&Co..  It is the intent of the parties that the Transaction comply with the requirements of Rule 10b5-1(c)(1)(i)(B) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), and the parties agree that this Confirmation shall be interpreted to comply with the requirements of Rule 10b5-1(c), and Counterparty shall not take 

8

any action that results in the Transaction not so complying with such requirements.  Without limiting the generality of the preceding sentence, Counterparty acknowledges and agrees that (A) Counterparty does not have, and shall not attempt to exercise, any influence over how, when or whether GS&Co. effects any purchases of Shares in connection with the Transaction, (B) during the period beginning on (but excluding) the date of this Confirmation and ending on (and including) the last day of the Relevant Period, neither Counterparty nor its officers or employees shall, directly or indirectly, communicate (except pursuant to a public disclosure) any information regarding Counterparty or the Shares to any employee of GS&Co. or its Affiliates identified or known to them as being responsible for trading the Shares in connection with the transactions contemplated hereby, (C) Counterparty is entering into the Transaction in good faith and not as part of a plan or scheme to evade compliance with federal securities laws including, without limitation, Rule 10b-5 promulgated under the Exchange Act and (D) Counterparty will not alter or deviate from this Confirmation or enter into or alter a corresponding hedging transaction with respect to the Shares.  Counterparty also acknowledges and agrees that any amendment, modification, waiver or termination of this Confirmation must be effected in accordance with the requirements for the amendment or termination of a “plan” as defined in Rule 10b5-1(c) under the Exchange Act.  Without limiting the generality of the foregoing, any such amendment, modification, waiver or termination shall be made in good faith and not as part of a plan or scheme to evade the prohibitions of Rule 10b-5 under the Exchange Act, and no such amendment, modification or waiver shall be made at any time at which Counterparty or any officer or director of Counterparty is aware of any material nonpublic information regarding Counterparty or the Shares.

(b)           Counterparty agrees that neither Counterparty nor any of its Affiliates or agents shall take any action that would cause Regulation M to be applicable to any purchases of Shares, or any security for which the Shares are a reference security (as defined in Regulation M), by Counterparty or any of its affiliated purchasers (as defined in Regulation M) during the Relevant Period.

(c)           Counterparty shall, at least one day prior to the first day of the Relevant Period, have notified GS&Co. of the total number of Shares purchased in Rule 10b-18 purchases of blocks pursuant to the once-a-week block exception contained in Rule 10b-18(b)(4) by or for Counterparty or any of its affiliated purchasers during each of the four calendar weeks preceding the first day of the Relevant Period and during the calendar week in which the first day of the Relevant Period occurs (“Rule 10b-18 purchase,” “blocks” and “affiliated purchaser” each being used as defined in Rule 10b-18), which notice shall be substantially in the form set forth as Appendix A hereto.

(d)           During the Relevant Period, Counterparty shall (i) notify GS&Co. prior to the opening of trading in the Shares on any day on which Counterparty makes, or expects to be made, any public announcement (as defined in Rule 165(f) under the Securities Act of 1933, as amended (the “Securities Act”)), of any merger, acquisition or similar transaction involving a recapitalization relating to Counterparty (other than any such transaction in which the consideration consists solely of cash and there is no valuation period), (ii) promptly notify GS&Co. following any such announcement that such announcement has been made and (iii) promptly deliver to GS&Co. following the making of any such announcement a certificate indicating (A) Counterparty’s average daily Rule 10b-18 purchases (as defined in Rule 10b-18) during the three full calendar months preceding the date of the announcement of such transaction and (B) Counterparty’s block purchases (as defined in Rule 10b-18) effected pursuant to paragraph (b)(4) of Rule 10b-18 during the three full calendar months preceding the date of the announcement of such transaction.  In addition, Counterparty shall promptly notify GS&Co. of the earlier to occur of the completion of such transaction and the completion of the vote by target shareholders.  Counterparty acknowledges that any such public announcement may result in a Regulatory Disruption and may cause the Relevant Period to be suspended.  Accordingly, Counterparty acknowledges that its actions in relation to any such announcement or transaction must comply with the standards set forth in Section 6(a) above.

(e)           Without the prior written consent of GS&Co., Counterparty shall not, and shall cause its Affiliates and affiliated purchasers (each as defined in Rule 10b-18) not to, directly or indirectly (including, without limitation, by means of a cash-settled or other derivative instrument) purchase, offer to purchase, place any bid or limit order that would effect a purchase of, or commence any tender offer relating to, any Shares (or an equivalent interest, including a unit of beneficial interest in a trust or limited partnership or a depository share) or any security convertible into or exchangeable for Shares during the Relevant Period.

7.             Representations and Agreements.

(a)           In addition to the representations and agreements in the Agreement and those contained elsewhere herein, Counterparty represents to and for the benefit of, and agrees with, GS&Co. as follows:

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(i)            As of the Trade Date, and as of the date of any election by Counterparty of the Share Termination Alternative under (and as defined in) Section 10(a) below, (A) none of Counterparty and its officers and directors is aware of any material nonpublic information regarding Counterparty or the Shares and (B) Counterparty’s most recent Annual Report on Form 10-K, together with all reports subsequently filed by it pursuant to the Exchange Act, taken together and as amended and supplemented to the date of this representation, do not, as of their respective filing dates, contain any untrue statement of a material fact or omit to state any material fact required to be stated therein or necessary to make the statements therein, in the light of the circumstances under which they were made, not misleading.

(ii)           Without limiting the generality of Section 13.1 of the Equity Definitions, Counterparty acknowledges that GS&Co. is not making any representations or taking any position or expressing any view with respect to the treatment of the Transaction under any accounting standards including ASC Topic 260, Earnings Per Share, ASC Topic 815, Derivatives and Hedging, or ASC Topic 480, Distinguishing Liabilities from Equity and ASC 815-40, Derivatives and Hedging – Contracts in Entity’s Own Equity (or any successor issue statements) or under FASB’s Liabilities & Equity Project.

(iii)          Without limiting the generality of Section 3(a)(iii) of the Agreement, the Transaction will not violate Rule 13e-1 or Rule 13e-4 under the Exchange Act.

(iv)          Prior to the Trade Date, Counterparty shall deliver to GS&Co. a resolution of Counterparty’s board of directors authorizing the Transaction and such other certificate or certificates as GS&Co. shall reasonably request.  Counterparty has publicly disclosed on October 21, 2010 its intention to institute a program for the acquisition of Shares.

(v)           Counterparty is not entering into this Confirmation to create actual or apparent trading activity in the Shares (or any security convertible into or exchangeable for Shares) or to raise or depress or otherwise manipulate the price of the Shares (or any security convertible into or exchangeable for Shares) or otherwise in violation of the Exchange Act, and will not engage in any other securities or derivative transaction to such ends.

(vi)          Counterparty is not, and after giving effect to the transactions contemplated hereby will not be, required to register as an “investment company,” as such term is defined in the Investment Company Act of 1940, as amended.

(vii)         On the Trade Date, the Prepayment Date, the Initial Share Delivery Date and the Settlement Date, Counterparty is not, or will not be, “insolvent,” as such term is defined under Section 101(32) of the U.S. Bankruptcy Code (Title 11 of the United States Code), as amended (the “Bankruptcy Code”), and Counterparty would be able to purchase the Shares hereunder in compliance with the corporate laws of the jurisdiction of its incorporation.

(viii)        No state or local (including non-U.S. jurisdictions) law, rule, regulation or regulatory order applicable to the Shares would give rise to any reporting, consent, registration or other requirement (including without limitation a requirement to obtain prior approval from any person or entity) as a result of GS&Co. or its affiliates owning or holding (however defined) Shares.

(ix)          Counterparty shall not declare or pay any Dividend (as defined above) to holders of record as of any date occurring prior to the Settlement Date or, if the provisions of Annex A apply, the Cash Settlement Payment Date, other than an ordinary cash dividend of USD 0.33 or less per Share to holders of record on each of July 31, 2012 and October 31, 2012 (or, in each case, any later date within the same quarterly fiscal period of Counterparty).

(x)           Counterparty understands no obligations of GS&Co. to it hereunder will be entitled to the benefit of deposit insurance and that such obligations will not be guaranteed by any affiliate of GS&Co. or any governmental agency.

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(b)           Each of GS&Co. and Counterparty agrees and represents that it is an “eligible contract participant” as defined in Section 1a(12) of the U.S. Commodity Exchange Act, as amended.

(c)           Each party acknowledges that the offer and sale of the Transaction to it is intended to be exempt from registration under the Securities Act by virtue of Section 4(2) thereof.  Accordingly, Counterparty represents to the other that (i) it has the financial ability to bear the economic risk of its investment in the Transaction and is able to bear a total loss of its investment, (ii) it is an “accredited investor” as that term is defined in Regulation D as promulgated under the Securities Act, (iii) it is entering into the Transaction for its own account and without a view to the distribution or resale thereof, and (iv) the assignment, transfer or other disposition of the Transaction has not been and will not be registered under the Securities Act and is restricted under this Confirmation, the Securities Act and state securities laws.

(d)           Counterparty agrees and acknowledges that GS&Co. is a “financial institution,”  “swap participant” and “financial participant” within the meaning of Sections 101(22), 101(53C) and 101(22A) of the Bankruptcy Code.  The parties hereto further agree and acknowledge that it is the intent of the parties that (A) this Confirmation is (i) a “securities contract,” as such term is defined in Section 741(7) of the Bankruptcy Code, with respect to which each payment and delivery hereunder or in connection herewith is a “termination value,” “payment amount” or “other transfer obligation” within the meaning of Section 362 of the Bankruptcy Code and a “settlement payment,” within the meaning of Section 546 of the Bankruptcy Code and (ii) a “swap agreement,” as such term is defined in Section 101(53B) of the Bankruptcy Code, with respect to which each payment and delivery hereunder or in connection herewith is a “termination value,” “payment amount” or “other transfer obligation” within the meaning of Section 362 of the Bankruptcy Code and a “transfer,” as such term is defined in Section 101(54) of the Bankruptcy Code and a “payment or other transfer of property” within the meaning of Sections 362 and 546 of the Bankruptcy Code, and (B) GS&Co. is entitled to the protections afforded by, among other sections, Sections 362(b)(6), 362(b)(17), 362(o), 546(e), 546(g), 548(d)(2), 555, 560 and 561 of the Bankruptcy Code.

(e)           In addition to the representations and agreements in the Agreement and those contained elsewhere herein, GS&Co. represents to and for the benefit of, and agrees with, Counterparty as follows:

(i)            GS&Co. has implemented and will at all relevant times maintain reasonable policies and procedures, taking into consideration the nature of its business, to ensure that individuals making investment decisions on behalf of the GS&Co. related to the Transaction do not have access to material nonpublic information regarding Counterparty that may be in possession of other individuals at GS&Co..

(ii)           GS&Co. is not entering into this Confirmation to create actual or apparent trading activity in the Shares (or any security convertible into or exchangeable for Shares) or to raise or depress or otherwise manipulate the price of the Shares (or any security convertible into or exchangeable for Shares) in violation of the Exchange Act, will not engage in any other securities or derivative transaction to such ends and will maintain such reasonable policies and procedures as are necessary to fulfill this clause during the period where such manipulation would constitute such a violation.

8.             Agreements and Acknowledgements Regarding Hedging.

Counterparty acknowledges and agrees that:

(a)           During the Relevant Period, GS&Co. and its Affiliates may buy or sell Shares or other securities or buy or sell options or futures contracts or enter into swaps or other derivative securities in order to adjust its hedge position with respect to the Transaction;

(b)           GS&Co. and its Affiliates also may be active in the market for Shares other than in connection with hedging activities in relation to the Transaction;

(c)           GS&Co. shall make its own determination as to whether, when or in what manner any hedging or market activities in Counterparty’s securities shall be conducted and shall do so in a manner that it deems appropriate to hedge its price and market risk with respect to the Settlement Price and/or the VWAP Price; and

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(d)           Any market activities of GS&Co. and its Affiliates with respect to Shares may affect the market price and volatility of Shares, as well as the Settlement Price and/or the VWAP Price, each in a manner that may be adverse to Counterparty.

9.             Special Provisions regarding Transaction Announcements.

(a)           If a Transaction Announcement occurs after the Trade Date but prior to the Scheduled Earliest Acceleration Date, the Scheduled Earliest Acceleration Date shall be adjusted to be the date of such Transaction Announcement.

(b)           “Transaction Announcement” means (i) the announcement of an Acquisition Transaction, (ii) an announcement that Counterparty or any of its subsidiaries has entered into an agreement, a letter of intent or an understanding to enter into an Acquisition Transaction, (iii) the announcement of an intention to solicit or enter into, or to explore strategic alternatives or other similar undertaking that may include, an Acquisition Transaction, or (iv) any other announcement that in the good faith reasonable judgment of the Calculation Agent may result in an Acquisition Transaction.  For the avoidance of doubt, announcements as used in this definition of Transaction Announcement refer to any public announcement whether made by the Issuer or a third party.

“Acquisition Transaction” means (i) any Merger Event (and for purposes of this definition the definition of Merger Event shall be read with the references therein to “100%” being replaced by “25%” and to “50%” by “75%” and  as if the clause beginning immediately following the definition of Reverse Merger therein to the end of such definition were deleted) or Tender Offer, or any other transaction, in each case, involving the merger of Counterparty with or into any third party, (ii) the sale or transfer of all or substantially all of the assets of Counterparty, (iii) a recapitalization, reclassification, binding share exchange or other similar transaction of Counterparty, (iv) any acquisition, lease, exchange, transfer, disposition (including by way of spin-off or distribution) of assets (including any capital stock or other ownership interests in subsidiaries) or other similar event by Counterparty or any of its subsidiaries where the aggregate consideration transferable or receivable by or to Counterparty or its subsidiaries exceeds 25% of the market capitalization of Counterparty and (v) any transaction in which Counterparty or its board of directors has a legal obligation to make a recommendation to its shareholders in respect of such transaction (whether pursuant to Rule 14e-2 under the Exchange Act or otherwise).

10.           Other Provisions.

(a)           Alternative Calculations and Payment on Early Termination and on Certain Extraordinary Events.  If either party would owe the other party any amount pursuant to Sections 12.2, 12.3, 12.6, 12.7 or 12.9 of the Equity Definitions or pursuant to Section 6(d)(ii) of the Agreement (a “Payment Obligation”), Counterparty shall have the right, in its sole discretion, to satisfy or to require GS&Co. to satisfy, as the case may be, any such Payment Obligation, in whole or in part, by the Share Termination Alternative (as defined below) by giving irrevocable telephonic notice to GS&Co., confirmed in writing within one Scheduled Trading Day, no later than 9:30 A.M., New York City time, on the Merger Date, Tender Offer Date, Announcement Date, Early Termination Date or date of cancellation or termination in respect of an Extraordinary Event, as applicable (“Notice of Share Termination”); provided that if GS&Co. would owe Counterparty the Payment Obligation and Counterparty does not elect to require GS&Co. to satisfy such Payment Obligation by the Share Termination Alternative in whole, GS&Co. shall have the right, in its sole discretion, to elect to satisfy any portion of such Payment Obligation that Counterparty has not so elected by the Share Termination Alternative, notwithstanding Counterparty’s failure to elect or election to the contrary; and provided further that Counterparty shall not have the right to so elect (but, for the avoidance of doubt, GS&Co. shall have the right to so elect) in the event of (i) an Insolvency, a Nationalization, a Merger Event or a Tender Offer, in each case, in which the consideration or proceeds to be paid to holders of Shares consists solely of cash or (ii) an Event of Default in which Counterparty is the Defaulting Party or a Termination Event in which Counterparty is the sole Affected Party, which Event of Default or Termination Event resulted from an event or events within Counterparty’s control.  Upon such Notice of Share Termination, the following provisions shall apply on the Scheduled Trading Day immediately following the Merger Date, Tender Offer Date, Announcement Date, Early Termination Date or date of cancellation or termination in respect of an Extraordinary Event, as applicable, with respect to the Payment Obligation or such portion of the Payment Obligation for which the Share Termination Alternative has been elected (the “Applicable Portion”):

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Share Termination Alternative: Applicable and means, if delivery pursuant to the Share Termination Alternative is owed by GS&Co., that GS&Co. shall deliver to Counterparty the Share Termination Delivery Property on the date on which the Payment Obligation would otherwise be due pursuant to Section 12.7 or 12.9 of the Equity Definitions or Section 6(d)(ii) of the Agreement, as applicable, or such later date as the Calculation Agent may determine (the “Share Termination Payment Date”), in satisfaction of the Payment Obligation or the Applicable Portion, as the case may be. If delivery pursuant to the Share Termination Alternative is owed by Counterparty, paragraphs 2 through 5 of Annex A shall apply as if such delivery were a settlement of the Transaction to which Net Share Settlement (as defined in Annex A) applied, the Cash Settlement Payment Date were the Early Termination Date, the Forward Cash Settlement Amount were zero (0) minus the Payment Obligation (or the Applicable Portion, as the case may be) owed by Counterparty, and “Shares” as used in Annex A were replaced by “Share Termination Delivery Units.”

Share Termination Delivery Property: A number of Share Termination Delivery Units, as calculated by the Calculation Agent, equal to the Payment Obligation (or the Applicable Portion, as the case may be) divided by the Share Termination Unit Price.  The Calculation Agent shall adjust the Share Termination Delivery Property by replacing any fractional portion of a security therein with an amount of cash equal to the value of such fractional security based on the values used to calculate the Share Termination Unit Price.

Share Termination Unit Price: The value of property contained in one Share Termination Delivery Unit on the date such Share Termination Delivery Units are to be delivered as Share Termination Delivery Property, as determined by the Calculation Agent in its good faith discretion by commercially reasonable means and notified by the Calculation Agent to the parties at the time of notification of the Payment Obligation.

Share Termination Delivery Unit: In the case of a Termination Event, Event of Default, Delisting or Additional Disruption Event, one Share or, in the case of an Insolvency, Nationalization, Merger Event or Tender Offer, one Share or a unit consisting of the number or amount of each type of property received by a holder of one Share (without consideration of any requirement to pay cash or other consideration in lieu of fractional amounts of any securities) in such Insolvency, Nationalization, Merger Event or Tender Offer.  If such Insolvency, Nationalization, Merger Event or Tender Offer involves a choice of consideration to be received by holders, such holder shall be deemed to have elected to receive the maximum possible amount of cash.

Failure to Deliver: Applicable

Other applicable provisions: If Share Termination Alternative is applicable, the provisions of Sections 9.8, 9.9, 9.10, 9.11 (except that the Representation and Agreement contained in Section 9.11 of the Equity Definitions shall be modified by excluding any representations therein relating to restrictions, obligations, limitations or requirements under applicable securities laws arising as a result of the fact that Counterparty is the issuer of the Shares or any portion of the Share Termination Delivery Units) and 9.12 of the Equity Definitions will be applicable as if “Physical Settlement” applied to the Transaction, except that all references to “Shares” shall be read as references to “Share Termination Delivery Units”.

(b)           Equity Rights.  GS&Co. acknowledges and agrees that this Confirmation is not intended to convey to it rights with respect to the Transaction that are senior to the claims of common stockholders in the event of Counterparty’s bankruptcy.  For the avoidance of doubt, the parties agree that the preceding sentence shall not apply at any time other than during Counterparty’s bankruptcy to any claim arising as a result of a breach by Counterparty of any of its obligations under this Confirmation or the Agreement.  For the avoidance of doubt, the parties acknowledge that this

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Confirmation is not secured by any collateral that would otherwise secure the obligations of Counterparty herein under or pursuant to any other agreement.

(c)           Indemnification.  In the event that GS&Co. or the Calculation Agent or any of their Affiliates becomes involved in any capacity in any action, proceeding or investigation brought by or against any person in connection with any matter referred to in this Confirmation, Counterparty shall reimburse GS&Co. or the Calculation Agent or such Affiliate for its reasonable legal and other out-of-pocket expenses (including the reasonable cost of any investigation and preparation) incurred in connection therewith within 30 days of receipt of notice of such expenses, and shall indemnify and hold GS&Co. or the Calculation Agent or such Affiliate harmless on an after-tax basis against any losses, claims, damages or liabilities to which GS&Co. or the Calculation Agent or such Affiliate may become subject in connection with any such action, proceeding or investigation.  If for any reason the foregoing indemnification is unavailable to GS&Co. or the Calculation Agent or such Affiliate or insufficient to hold it harmless, then Counterparty shall contribute to the amount paid or payable by GS&Co. or the Calculation Agent or such Affiliate as a result of such losses, claims, damages or liabilities (i) in such proportion as is appropriate to reflect the relative benefits received by Counterparty on the one hand and GS&Co. or the Calculation Agent or such Affiliate on the other hand in the matters contemplated by this Confirmation or (ii) if the allocation provided by clause (i) above is not permitted by applicable law, in such proportion as is appropriate to reflect not only the relative benefits received by Counterparty on the one hand and GS&Co. or the Calculation Agent or such Affiliate on the other hand in the matters contemplated by this Confirmation but also the relative fault of Counterparty and GS&Co. or the Calculation Agent or such Affiliate with respect to such losses, claims, damages or liabilities and any other relevant equitable considerations.  The relative benefits received by Counterparty, on the one hand, and GS&Co. or the Calculation Agent or such Affiliate, on the other hand, shall be in the same proportion as the Prepayment Amount bears to the customary brokerage commission for share repurchases multiplied by the Initial Shares.  The reimbursement, indemnity and contribution obligations of Counterparty under this Section 10(c) shall be in addition to any liability that Counterparty may otherwise have, shall extend upon the same terms and conditions to the partners, directors, officers, agents, employees and controlling persons (if any), as the case may be, of GS&Co. or the Calculation Agent and their Affiliates and shall be binding upon and inure to the benefit of any successors, assigns, heirs and personal representatives of Counterparty, GS&Co. or the Calculation Agent, any such Affiliate and any such person.  Counterparty also agrees that neither GS&Co., the Calculation Agent nor any of such Affiliates, partners, directors, officers, agents, employees or controlling persons shall have any liability to Counterparty for or in connection with any matter referred to in this Confirmation except to the extent that any losses, claims, damages, liabilities or expenses incurred by Counterparty result from the gross negligence or bad faith of GS&Co. or the Calculation Agent or a breach by GS&Co. or the Calculation Agent of any of its covenants, representations or obligations hereunder.  Notwithstanding the foregoing, in no event shall Counterparty have any obligation or liability hereunder to reimburse, indemnify or hold harmless, or so contribute to, GS&Co., the Calculation Agent (if GS&Co.) or any of their respective Affiliates (including any of their respective partners, directors, officers, agents, employees and controlling persons) for any such expenses, losses, claims, damages or liabilities to the extent arising from the gross negligence, bad faith or willful misconduct on the part of GS&Co., the Calculation Agent (if GS&Co.) or any of their respective Affiliates (including any of their respective partners, directors, officers, agents, employees and controlling persons) or from a breach by GS&Co. or the Calculation Agent (if GS&Co.) of any of its covenants, representations or obligations hereunder.  The foregoing provisions shall survive any termination or completion of the Transaction.

(d)           Staggered Settlement.  If GS&Co. would owe Counterparty any Shares pursuant to the “Settlement Terms” above, GS&Co. may, by notice to Counterparty on or prior to the Settlement Date (a “Nominal Settlement Date”), elect to deliver the Shares deliverable on such Nominal Settlement Date on two or more dates (each, a “Staggered Settlement Date”) or at two or more times on the Nominal Settlement Date as follows: (i) in such notice, GS&Co. will specify to Counterparty the related Staggered Settlement Dates (each of which will be on or prior to such Nominal Settlement Date) or delivery times and how it will allocate the Shares it is required to deliver under “Settlement Terms” above among the Staggered Settlement Dates or delivery times; and (ii) the aggregate number of Shares that GS&Co. will deliver to Counterparty hereunder on all such Staggered Settlement Dates and delivery times will equal the number of Shares that GS&Co. would otherwise be required to deliver on such Nominal Settlement Date.

(e)           Adjustments.  For the avoidance of doubt, whenever the Calculation Agent is called upon to make an adjustment pursuant to the terms of this Confirmation or the Definitions to take into account the effect of an event, the Calculation Agent shall make such adjustment by reference to the effect of such event on the Hedging Party, assuming that the Hedging Party maintains a commercially reasonable hedge position.

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(f)            Transfer and Assignment.  Neither party may transfer or assign any of its rights or obligations under the Transaction without the prior written consent of the other party, such consent not to be unreasonably withheld or delayed; provided, however, that GS&Co. may transfer or assign, without any consent of Counterparty, its rights and obligations hereunder and under the Agreement, in whole or in part, to any of its affiliated entities of reasonably equivalent credit quality as GS&Co., but only if (i) Counterparty will not be required to pay to the assignee an amount in respect of an Indemnifiable Tax under Section 2(d)(i)(4) of the Agreement (except in respect of interest under Section 6(d)(ii), 6(e) or 9(h)(i)(1) of the Agreement) greater than the amount in respect of which Counterparty would have been required to pay to GS&Co. in the absence of such assignment; (ii) Counterparty will not receive a payment from which an amount has been withheld or deducted, on account of a Tax under Section 2(d)(i) of the Agreement (except in respect of interest under Section 2(d), 6(d)(ii) or 6(e) of the Agreement), in excess of that which GS&Co. would have been required to so withhold or deduct in the absence of such assignment, unless the assignee will be required to make additional payments pursuant to Section 2(d)(i)(4) of the Agreement in respect of such excess; (iii) Counterparty will not otherwise suffer material adverse tax consequences from such transfer or assignment; (iv) immediately upon giving effect to such transfer, no Event of Default, no Potential Event of Default and no Termination Event will have occurred as a result thereof; and (v) GS&Co. shall have caused the transferee to make such Payee Tax Representations and to provide such tax documentation as may be reasonably requested by Counterparty to permit Counterparty to determine that results described in clauses (i) and (ii) will not occur upon or after such transfer and assignment.

(g)           Tax Form Deliverables.  GS&Co. will provide to Counterparty upon execution hereof a correct, complete and executed Internal Revenue Service (“IRS”) Form W-9 or applicable IRS Form W-8 as appropriate.

(h)           Additional Termination Event.  It shall constitute an Additional Termination Event with respect to which the Transaction is the sole Affected Transaction and Counterparty is the sole Affected Party and GS&Co. shall be the party entitled to designate an Early Termination Date pursuant to Section 6(b) of the Agreement if and so long as, at any time during the Relevant Period, the closing price per Share on the Exchange for any two consecutive Exchange Business Days is below the Threshold Price (as provided in Annex B to this Confirmation).  In such case, GS&Co. may, by not more than 10 Exchange Business Days notice to Counterparty and notwithstanding any subsequent closing price of the Shares on the Exchange, designate a day not earlier than the day such notice is effective as the “Early Termination Date” for purposes of the Agreement.

(i)            In respect of any Event of Default, Termination Event or Additional Disruption Event affording either party (the “Party with the Right”) the right to cancel or terminate the Transaction, notwithstanding anything in the Agreement or the Equity Definitions to the contrary, the Party with the Right shall have 20 Exchange Business Days following notice from the other party of such event to make its election to cancel or terminate the Transaction. If, with respect to any condition or event constituting such Event of Default, Termination Event or Additional Disruption Event, the Party with the Right has not made such election in such time, then the Party with the Right’s right to cancel or terminate in respect of such condition or event shall have been waived, and the condition under Section 2(a)(iii) of the Agreement shall not apply with respect to such condition or event (but only with respect to such condition or event).

(j)            Amendments to Equity Definitions.  The following amendments shall be made to the Equity Definitions:

(i)            Section 11.2(a) of the Equity Definitions is hereby amended by deleting the words “a diluting or concentrative effect on the theoretical value of the relevant Shares” and replacing them with the words “an effect on the volatility, expected dividends, stock loan rate or liquidity relative to the relevant Shares”;

(ii)           The first sentence of Section 11.2(c) of the Equity Definitions, prior to clause (A) thereof, is hereby amended to read as follows: ‘(c) If “Calculation Agent Adjustment” is specified as the Method of Adjustment in the related Confirmation of a Share Option Transaction or Share Forward Transaction, then following the announcement or occurrence of any Potential Adjustment Event, the Calculation Agent will determine whether such Potential Adjustment Event has an effect on the volatility, expected dividends, stock loan rate or liquidity relative to the relevant Shares and, if so, will (i) make appropriate adjustment(s), if any, to any one or more of:’ and the portion of such sentence immediately preceding clause (ii) thereof is hereby amended by deleting the words “diluting or concentrative” and the words “(provided that no adjustments will be made to account solely for changes in volatility, expected dividends, stock loan rate or liquidity relative to the relevant Shares)” and replacing such latter phrase with the words “(and, for the avoidance of doubt, adjustments may be made to account solely for changes in volatility, stock loan rate or liquidity relative to the relevant Shares, except

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that, in the case of the stock split declared or announced by Counterparty on February 15, 2012, no such adjustment may be made to account for changes in volatility, stock loan rate or liquidity relative to the relevant   Shares)”;

(iii)          Section 11.2(e)(vii) of the Equity Definitions is hereby amended by deleting the words “diluting or concentrative effect on the theoretical value of the relevant Shares” and replacing them with the words “effect on the volatility, expected dividends, stock loan rate or liquidity relative to the relevant Shares”;

(iv)          Section 12.6(a)(ii) of the Equity Definitions is hereby amended by (1) deleting from the fourth line thereof the word “or” after the word “official” and inserting a comma therefor, and (2) deleting the semi-colon at the end of subsection (B) thereof and inserting the following words therefor “or (C) the occurrence of any of the events specified in Section 5(a)(vii)(1) and (3) through (8) of the ISDA Master Agreement with respect to that issuer”; and

(v)           Section 12.9(b)(iv) of the Equity Definitions is hereby amended by (A) deleting (1) subsection (A) in its entirety, (2) the phrase “or (B)” following subsection (A) and (3) the phrase “in each case” in subsection (B); and (B) deleting the phrase “neither the Non-Hedging Party nor the Lending Party lends Shares in the amount of the Hedging Shares or” in the penultimate sentence.

(k)           No Netting and Set-off.  Each party waives any and all rights it may have to set off obligations arising under the Agreement and the Transaction against other obligations between the parties, whether arising under any other agreement, applicable law or otherwise.

(l)            Disclosure.  Effective from the date of commencement of discussions concerning the Transaction, Counterparty and each of its employees, representatives, or other agents may disclose to any and all persons, without limitation of any kind, the tax treatment and tax structure of the Transaction and all materials of any kind (including opinions or other tax analyses) that are provided to Counterparty relating to such tax treatment and tax structure.

(m)          Designation by GS&Co..  Notwithstanding any other provision in this Confirmation to the contrary requiring or allowing GS&Co. to purchase, sell, receive or deliver any Shares or other securities to or from Counterparty, GS&Co. (the “Designator”) may designate any of its Affiliates (the “Designee”) to deliver or take delivery, as the case may be, and otherwise perform its obligations to deliver, if any, or take delivery of, as the case may be, any such Shares or other securities in respect of the Transaction, and the Designee may assume such obligations, if any.  Such designation shall not relieve the Designator of any of its obligations, if any, hereunder. Notwithstanding the previous sentence, if the Designee shall have performed the obligations, if any, of the Designator hereunder, then the Designator shall be discharged of its obligations, if any, to Counterparty to the extent of such performance.

(n)           Termination Currency.  The Termination Currency shall be USD.

(o)           Waiver of Trial by Jury.  EACH OF COUNTERPARTY AND GS&CO. HEREBY IRREVOCABLY WAIVES (ON ITS OWN BEHALF AND, TO THE EXTENT PERMITTED BY APPLICABLE LAW, ON BEHALF OF ITS STOCKHOLDERS) ALL RIGHT TO TRIAL BY JURY IN ANY ACTION, PROCEEDING OR COUNTERCLAIM (WHETHER BASED ON CONTRACT, TORT OR OTHERWISE) ARISING OUT OF OR RELATING TO THE TRANSACTION OR THE ACTIONS OF GS&CO. OR ITS AFFILIATES IN THE NEGOTIATION, PERFORMANCE OR ENFORCEMENT HEREOF.

(p)           Governing Law; Jurisdiction.  THIS CONFIRMATION AND ANY CLAIM, CONTROVERSY OR DISPUTE ARISING UNDER OR RELATED TO THIS CONFIRMATION SHALL BE GOVERNED BY THE LAWS OF THE STATE OF NEW YORK.  THE PARTIES HERETO IRREVOCABLY SUBMIT TO THE EXCLUSIVE JURISDICTION OF THE COURTS OF THE STATE OF NEW YORK AND THE UNITED STATES DISTRICT COURT LOCATED IN THE BOROUGH OF MANHATTAN IN NEW YORK CITY IN CONNECTION WITH ALL MATTERS RELATING HERETO AND WAIVE ANY OBJECTION TO THE LAYING OF VENUE IN, THE JUSRIDICTION OF, AND ANY CLAIM OF INCONVENIENT FORUM WITH RESPECT TO THESE COURTS.

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(q)           No Condition of Confidentiality.  GS&Co. and Counterparty hereby acknowledge and agree that GS&Co. has authorized Counterparty to disclose this Agreement  and the transactions contemplated hereby to any and all persons, and there are no express or implied agreements, arrangements or understandings to the contrary, and GS&Co. hereby waives any and all claims to any proprietary rights with respect to this Agreement and the transactions contemplated hereby, and authorizes Counterparty to use any information that Counterparty receives or has received with respect to this Agreement and the transactions contemplated hereby in any manner.

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Please confirm your agreement to be bound by the terms stated herein by executing the copy of this Confirmation enclosed for that purpose and returning it to us by mail or facsimile transmission to the address for Notices indicated above.

Yours sincerely,
GOLDMAN, SACHS & CO.
By:	_______________________________
Name
Title

Confirmed as of the date first above written:

ONEOK, Inc.

By:      _______________________________

Name:

Title:

APPENDIX A

[Counterparty Letterhead]

Goldman, Sachs & Co.

200 West Street

New York, NY 10282-2198

Attn:

Re:           Issuer Forward Repurchase Transaction

Ladies and Gentlemen:

In connection with our entry into a confirmation between you and us dated as of June 11, 2012 (the “Confirmation”), we hereby represent that set forth below is the total number of shares of our common stock purchased by or for us or any of our affiliated purchasers in Rule 10b-18 purchases of blocks pursuant to the once-a-week block exception contained in Rule 10b-18(b)(4) (all defined in Rule 10b-18 under the Securities Exchange Act of 1934, as amended) during the four full calendar weeks immediately preceding the first day of the Relevant Period (as defined in the Confirmation) and the week during which the first day of the Relevant Period occurs:

	Monday’s Date	Friday’s Date	Share Number
Week 4:
Week 3:
Week 2:
Week 1:
Current Week:

We understand that you will use this information in calculating trading volume for purposes of Rule 10b-18.

Very truly yours,
ONEOK, Inc.
By:
	Name
	Title

ANNEX A

COUNTERPARTY SETTLEMENT PROVISIONS

1.             The following Counterparty Settlement Provisions shall apply to the extent indicated under the Confirmation:

Settlement Currency: USD

Settlement Method Election: Applicable; provided that (i) Section 7.1 of the Equity Definitions is hereby amended by deleting the word “Physical” in the sixth line thereof and replacing it with the words “Net Share” and (ii) the Electing Party may make a settlement method election only if the Electing Party represents to GS&Co. in writing on the date it notifies GS&Co. of its election that, as of such date, (A) none of Counterparty and its officers and directors is aware of any material nonpublic information regarding Counterparty or the Shares and (B) Counterparty is electing the settlement method in good faith and not as part of a plan or scheme to evade compliance with the federal securities laws.

Electing Party: Counterparty

Settlement Method

Election Date: The date 10 Exchange Business Days prior to the Valuation Date; provided that if GS&Co. accelerates the Final Averaging Date pursuant to the proviso to the definition of Final Averaging Date, the Settlement Method Election Date shall be the second Exchange Business Day immediately following the Valuation Date.

Default Settlement Method: Cash Settlement

Special Settlement: Either (i) a settlement to which this Annex A applies that follows the occurrence of a Transaction Announcement to which Section 9 of this Confirmation applies or (ii) any settlement to which paragraphs 2 through 5 of this Annex A apply that follows a termination or cancellation of the Transaction pursuant to Section 6 of the Agreement or Article 12 of the Equity Definitions to which Section 10(a) of this Confirmation applies.

Forward Cash Settlement

Amount: The Number of Shares to be Delivered multiplied by the Settlement Valuation Price.

Settlement Valuation Price: The arithmetic average of the VWAP Prices for all Settlement Valuation Dates, subject to Averaging Date Disruption, determined as if each Settlement Valuation Date were an Averaging Date (with Averaging Date Disruption applying as if the last Settlement Valuation Date were the Final Averaging Date and the Settlement Valuation Price were the Settlement Price).

Settlement Valuation Dates: A number of Scheduled Trading Days selected by GS&Co. in its good faith, commercially reasonable discretion, beginning on the Scheduled Trading Day immediately following the later of the Settlement Method Election Date and the Final Averaging Date.

Cash Settlement: If Cash Settlement is applicable, then Counterparty shall pay to GS&Co. the absolute value of the Forward Cash Settlement Amount on the Cash Settlement Payment Date.

Cash Settlement

Payment Date: The date one Settlement Cycle following the last Settlement Valuation Date.

Net Share Settlement 

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Procedures: If Net Share Settlement is applicable, Net Share Settlement shall be made in accordance with paragraphs 2 through 5 below.

2.             Net Share Settlement shall be made by delivery on the Settlement Date of a number of Shares equal to the product of 102% and the absolute value of the Number of Shares to be Delivered; provided that in the case of a Special Settlement, Net Share Settlement shall be made (i) by delivery on the Cash Settlement Payment Date (such date, the “Net Share Settlement Date”) of a number of Shares (the “Restricted Payment Shares”) with a value equal to the absolute value of the Forward Cash Settlement Amount, with such Shares’ value based on the realizable market value thereof to GS&Co. (which value shall take into account an illiquidity discount resulting from the fact that the Restricted Payment Shares will not be registered for resale), as determined by the Calculation Agent (the “Restricted Share Value”), and paragraph 3 of this Annex A shall apply to such Restricted Payment Shares, and (ii) by delivery of the Make-Whole Payment Shares as described in paragraph 4 below.

3.             (a)           All Restricted Payment Shares and Make-Whole Payment Shares shall be delivered to GS&Co. (or any affiliate of GS&Co. designated by GS&Co.) pursuant to the exemption from the registration requirements of the Securities Act provided by Section 4(2) thereof.

(b)           As of or prior to the date of delivery, GS&Co. and any potential purchaser of any such Shares from GS&Co. (or any affiliate of GS&Co. designated by GS&Co.) identified by GS&Co. shall be afforded a commercially reasonable opportunity to conduct a due diligence investigation with respect to Counterparty customary in scope for private placements, of similar size, of equity securities (including, without limitation, the right to have made available to them for inspection all financial and other records, pertinent corporate documents and other information reasonably requested by them); provided that, prior to receiving or being granted access to any such information, any such potential purchaser may be required by Counterparty to enter into a customary nondisclosure agreement with Counterparty in respect of any such due diligence investigation.

(c)           As of the date of delivery, Counterparty shall enter into an agreement (a “Private Placement Agreement”) with GS&Co. (or any affiliate of GS&Co. designated by GS&Co.) in connection with the private placement of such Shares by Counterparty to GS&Co. (or any such affiliate) and the private resale of such shares by GS&Co. (or any such affiliate), substantially similar to private placement purchase agreements customary for private placements of equity securities, in form and substance commercially reasonably satisfactory to GS&Co., which Private Placement Agreement shall include, without limitation, provisions substantially similar to those contained in such private placement purchase agreements relating to the indemnification of, and contribution in connection with the liability of, GS&Co. and its affiliates, and shall provide for the payment by Counterparty of all reasonable fees and actual, documented out-of-pocket expenses in connection with such resale, including all reasonable fees and actual, documented out-of-pocket expenses of counsel for GS&Co., and shall contain representations, warranties and agreements of Counterparty reasonably necessary or advisable to establish and maintain the availability of an exemption from the registration requirements of the Securities Act for such resales.

(d)           Neither GS&Co. nor Counterparty shall take or cause to be taken any action that would make unavailable either (i) the exemption set forth in Section 4(2) of the Securities Act for the sale of any Restricted Payment Shares or Make-Whole Payment Shares by Counterparty to GS&Co. or (ii) an exemption from the registration requirements of the Securities Act reasonably acceptable to GS&Co. for resales of Restricted Payment Shares and Make-Whole Payment Shares by GS&Co. (or an affiliate of GS&Co.).

(e)           Counterparty expressly agrees and acknowledges that the public disclosure of all material information relating to Counterparty is within Counterparty’s control.

4.             If Restricted Payment Shares are delivered in accordance with paragraph 3 above, on the last Settlement Valuation Date, a balance (the “Settlement Balance”) shall be established with an initial balance equal to the absolute value of the Forward Cash Settlement Amount.  Following the delivery of Restricted Payment Shares or any Make-Whole Payment Shares, GS&Co. shall sell all such Restricted Payment Shares or Make-Whole Payment Shares in a commercially reasonable manner.  At the end of each Exchange Business Day upon which sales have been made, the Settlement Balance shall be reduced by an amount equal to the aggregate proceeds received by GS&Co. or its affiliate upon the sale of such Restricted Payment Shares or Make-Whole Payment Shares, less a customary and commercially reasonable private placement fee for private placements of common stock by similar issuers.  If, on any Exchange

A- 2

Business Day, all Restricted Payment Shares and Make-Whole Payment Shares have been sold and the Settlement Balance has not been reduced to zero, Counterparty shall (i) deliver to GS&Co. or as directed by GS&Co. one Settlement Cycle following such Exchange Business Day an additional number of Shares (the “Make-Whole Payment Shares” and, together with the Restricted Payment Shares, the “Payment Shares”) equal to (x) the Settlement Balance as of such Exchange Business Day divided by (y) the Restricted Share Value of the Make-Whole Payment Shares as of such Exchange Business Day or (ii) promptly deliver to GS&Co. cash in an amount equal to the then remaining Settlement Balance.  This provision shall be applied successively until either the Settlement Balance is reduced to zero or the aggregate number of Restricted Payment Shares and Make-Whole Payment Shares equals the Maximum Deliverable Number. If on any Exchange Business Day, Restricted Payment Shares and Make-Whole Payment Shares remain unsold and the Settlement Balance has been reduced to zero, GS&Co. shall promptly return such unsold Restricted Payment Shares or Make-Whole Payment Shares.

5.             Notwithstanding the foregoing, in no event shall Counterparty be required to deliver more than the Maximum Deliverable Number of Shares hereunder.  “Maximum Deliverable Number” means the number of Shares set forth as such in Annex B to this Confirmation.  Counterparty represents to GS&Co. (which representation shall be deemed to be repeated on each day from the date hereof to the Settlement Date or, if Counterparty has elected to deliver any Payment Shares hereunder in connection with a Special Settlement, to the date on which resale of such Payment Shares is completed (the “Final Resale Date”)) that the Maximum Deliverable Number is equal to or less than the number of authorized but unissued Shares of Counterparty that are not reserved for future issuance in connection with transactions in such Shares (other than the transactions under this Confirmation) on the date of the determination of the Maximum Deliverable Number (such Shares, the “Available Shares”).  In the event Counterparty shall not have delivered the full number of Shares otherwise deliverable as a result of this paragraph 5 (the resulting deficit, the “Deficit Shares”), Counterparty shall be continually obligated to deliver, from time to time until the full number of Deficit Shares have been delivered pursuant to this paragraph, Shares when, and to the extent that, (i) Shares are repurchased, acquired or otherwise received by Counterparty or any of its subsidiaries after the date hereof (whether or not in exchange for cash, fair value or any other consideration), (ii) authorized and unissued Shares reserved for issuance in respect of other transactions prior to such date which prior to the relevant date become no longer so reserved or (iii) Counterparty additionally authorizes any unissued Shares that are not reserved for other transactions.  Counterparty shall immediately notify GS&Co. of the occurrence of any of the foregoing events (including the number of Shares subject to clause (i), (ii) or (iii) and the corresponding number of Shares to be delivered) and promptly deliver such Shares thereafter.

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EX-10.2

ONEOK, INC.

EMPLOYEE STOCK PURCHASE PLAN

Amended and Restated May 23, 2012

1. Purpose

The purpose of this Plan is to provide eligible employees the opportunity to purchase Common Stock at a discount on a basis that

qualifies for the tax treatment prescribed by Section 423 of the Code.

2. Definitions

The following terms, when used in the Plan, shall have the following meanings:

(a) Base Compensation means, with respect to any offering period: (i) in the case of an employee normally paid an hourly rate, the employee’s hourly rate at the inception of the offering period multiplied by 2,080, (ii) in the case of an employee normally paid at a weekly rate, the employee’s weekly rate at the inception of the offering period multiplied by 52, (iii) in the case of an employee normally paid at a bi-weekly rate, the employee’s bi-weekly rate at the inception of the offering period multiplied by 26, (iv) in the case of an employee normally paid at a monthly rate, the employee’s monthly rate at the inception of the offering period multiplied by 12; and (v) in the case of an employee normally paid at an annual rate, the employee’s annual rate at the inception of the offering period. Base compensation shall be determined by reference to the applicable rate before any deductions pursuant to a salary reduction agreement under any plan qualified under Section 401(k) of the Code or any cafeteria plan under Code Section 125 and shall exclude any bonuses, commissions, overtime pay, fringe benefits, stock options and other special compensation payable to an employee.

(b) Board or Board of Directors means the Board of Directors of the Company, as constituted from time to time.

(c) Code means the Internal Revenue Code of 1986, as amended from time to time. References to the Code or to a particular section of the Code shall include references to any related Treasury Regulations and rulings and to successor provisions.

(d) Committee means the committee appointed by the Board of Directors to administer the Plan pursuant to the provisions of Section 3(a) below.

(e) Common Stock means common stock, par value $0.01, of the Company.

(f) Company means ONEOK, Inc., an Oklahoma corporation, its successors and assigns.

(g) Exchange Act means the Securities Exchange Act of 1934, as amended from time to time.

(h) Fair Market Value on a particular date means the average of the high and low sale prices of the Common Stock in consolidated trading on the date in question as reported by The Wall Street Journal or another reputable source designated by the Committee; provided that if there were no sales on such date reported as provided above, the respective prices on the most recent prior day for which a sale was so reported. If the foregoing method of determining fair market value should be inconsistent with

Section 423 of the Code, “Fair Market Value” shall be determined by the Committee in a manner consistent with such section of the Code and shall mean the value as so determined.

(i) General Counsel means the General Counsel of the Company serving from time to time.

(j) Plan means the ONEOK, Inc. Employee Stock Purchase Plan set forth in these pages, as amended from time to time.

(k) SEC Rule 16b-3 means Rule 16b-3 of the Securities and Exchange Commission promulgated under the Exchange Act, as such rule or any successor rule may be in effect from time to time.

(l) Section 16 Person means a person subject to Section 16(b) of the Exchange Act with respect to transactions involving equity securities of the Company.

(m) Subsidiary means a subsidiary as defined in Section 424(f) of the Code, including a corporation which becomes such a subsidiary in the future.

3. Administration

(a) The Plan shall be administered by a committee of the Board consisting of two or more directors appointed from time to time by the Board. No person shall be appointed to or shall serve as a member of such committee unless at the time of such appointment and service he or she shall be a Non-Employee Director, as defined in SEC Rule 16b-3.

(b) Subject to the provisions of the Plan, the powers of the Committee shall include having the authority, in its discretion, to:

(i) define, prescribe, amend and rescind rules, regulations, procedures, terms and conditions relating to the Plan;

(ii) make all other determinations necessary or advisable for the administration of the Plan, including but not limited to interpreting the Plan, correcting defects, reconciling inconsistencies and resolving ambiguities; and

(iii) approve any transaction involving a grant, award or other transaction from the Company to a Section 16 Person (other than a Discretionary Transaction, as defined in SEC Rule 16b-3), so as to exempt such transaction under SEC Rule 16b-3; provided, that any transaction under the Plan involving a Section 16 Person also may be approved by the Board of Directors, or may be approved or ratified by the stockholders of the Company, in the manner that exempts such transaction under SEC Rule 16b-3.

(c) The interpretation by the Committee of the terms and provisions of the Plan, and its administration of the Plan, and all action taken by the Committee, shall be final, binding and conclusive on the Company, its stockholders, Subsidiaries, all participants and employees, and upon their respective successors and assigns, and upon all other persons claiming under or through any of them.

(d) Members of the Board and members of the Committee acting under this Plan shall be fully protected in relying in good faith upon the advice of counsel and shall incur no liability except for gross or willful misconduct in the performance of their duties.

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4. Stock Subject to the Plan

(a) Subject to paragraph (c) below, the aggregate number of shares of Common Stock which may be sold under the Plan is 5,800,000.

(b) If the number of shares of Common Stock that participating employees become entitled to purchase is greater than the number of shares of Common Stock that are offered in a particular offering or that remain available under the Plan, the available shares of Common Stock shall be allocated by the Committee among such participating employees in such manner as it deems fair and equitable.

(c) In the event of any change in the Common Stock, through recapitalization, merger, consolidation, stock dividend or split, combination or exchange of shares, spinoff or otherwise, the Committee may make such equitable adjustments in the Plan and the then outstanding offerings as it deems necessary and appropriate including, but not limited to, changing the number of shares of Common Stock reserved under the Plan, and the price of the current offering; provided that any such adjustments shall be consistent with Sections 423 and 424 of the Code.

(d) Shares of Common Stock which are to be delivered under the Plan may be obtained by the Company from its treasury, by purchases on the open market or from private sources, or by issuing authorized but unissued shares of its Common Stock. Shares of authorized but unissued Common Stock may not be delivered under the Plan if the purchase price thereof is less than the par value (if any) of the Common Stock at the time. The Committee may (but need not) provide at any time or from time to time (including without limitation upon or in contemplation of a change in control) for a number of shares of Common Stock equal in number to the number of shares then subject to options under this Plan, or expected to be subject to options under this Plan in the then pending offering(s), to be issued or transferred to, or acquired by, a trust (including but not limited to a grantor trust) for the purpose of satisfying the Company’s obligations under such options, and, unless prohibited by applicable law, such shares held in trust shall be considered authorized and issued shares with full dividend and voting rights, notwithstanding that the options to which such shares relate might not be exercisable at the time. No fractional shares of Common Stock shall be issued or sold under the Plan.

5. Eligibility

All employees of the Company and any Subsidiaries designated by the Committee from time to time will be eligible to participate in the Plan, in accordance with and subject to such rules and regulations as the Committee may prescribe; provided, however, that (a) such rules shall neither permit nor deny participation in the Plan contrary to the requirements of the Code (including but not limited to Section 423(b)(3), (4) and (8) thereof), (b) no employee shall be eligible to participate in the Plan if his or her customary employment is 20 hours or less per week or for not more than 5 months in any calendar year, unless the Committee determines otherwise on a uniform and non-discriminatory basis, (c) no employee may be granted an option under the Plan if such employee, immediately after the option is granted, owns stock possessing 5% or more of the total combined voting power or value of all classes of stock of his or her employer corporation or any parent or Subsidiary corporation (within the meaning of Section 423(b)(3) of the Code). For purposes of the preceding sentence, the rules of Section 424(d) of the Code shall

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apply in determining the stock ownership of an employee, and stock which the employee may purchase under outstanding options (whether or not such options qualify for the special tax treatment afforded by Code Section 421(a)) shall be treated as stock owned by the employee; and (d) all participating employees shall have the same rights and privileges except as otherwise permitted by Section 423(b)(5) of the Code.

6. Offerings; Participation.

The Company may make offerings of up to 27 months’ duration each, to eligible employees to purchase Common Stock under the Plan, until all shares authorized to be delivered under the Plan have been exhausted or until the Plan is sooner terminated by the Board. Subject to the preceding sentence, the duration and commencement date of any offerings shall be determined by the Committee in its sole discretion; provided that, unless the Committee determines otherwise, a new offering shall commence on the first day of the Company’s first payroll period coinciding with or next following each January 1 after the effective date of this Plan and shall extend through and include the payroll period immediately preceding the payroll period in which the next offering commences. Subject to such rules, procedures and forms as the Committee may prescribe, an eligible employee may participate in an offering at such time(s) as the Committee may permit by authorizing a payroll deduction for such purpose of up to a maximum of ten percent of his or her Base Compensation or such lesser amount as the Committee may prescribe. The Committee may (but need not) permit employee contributions to be made by means other than payroll deductions, provided that in no event shall an employee’s contributions from all sources in any offering exceed ten percent of his or her Base Compensation or such lesser amount as the Committee may prescribe. The Committee may at any time suspend or accelerate the completion of an offering if required by law or deemed by the Committee to be in the best interests of the Company, including in the event of a change in ownership or control of the Company or any Subsidiary. The Company’s obligation to sell and deliver Common Stock under this Plan shall be subject to the approval of any governmental authority whose approval the General Counsel determines is necessary or advisable to obtain in connection with the authorization, issuance or sale of such Common Stock.

7. Payroll Deductions

(a) The Company will maintain payroll deduction accounts on its books for all participating employees. All employee contributions shall be credited to such accounts. Employee contributions credited to the payroll deduction accounts of participating employees need not be segregated from other corporate funds and may be used for any corporate purpose.

(b) At such times as the Committee may permit and subject to such rules, procedures and forms as the Committee may prescribe, an employee may increase, decrease or suspend his or her payroll deduction during an offering, or may withdraw the balance of his or her payroll deduction account and thereby withdraw from participation in an offering. However, an employee may at any time waive in writing the right or privilege to decrease or suspend his or her payroll deductions or withdraw from participation in a particular offering for a period of at least six months. Any such waiver shall be irrevocable with respect to the period ending six months after the employee files a superseding written revocation of such waiver with the Company.

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(c) No employee shall make any elective contribution or employee contribution to the Plan (within the meaning of Treasury Regulation Section 1.401(k)-1(d)(2)(iv)(B)(4)) during the balance of the calendar year after the employee’s receipt of a hardship distribution from a plan of the Company or a related party within the provisions of Code Section 414(b), (c), (m) or (o) containing a cash or deferred arrangement under Section 401(k) of the Code, or during the following calendar year. The foregoing sentence shall not apply if and to the extent the General Counsel determines it is not necessary to qualify any such plan as a cash or deferred arrangement under Section 401(k) of the Code.

(d) Any balance remaining in any employee’s payroll deduction account at the end of an offering period will be carried forward into the employee’s payroll deduction account for the following offering period. In no event will the balance carried forward be equal to or greater than the purchase price of one share of Common Stock as determined under Section 8(c) below. Any excess shall be refunded to the participant. Upon termination of the Plan, all amounts in the accounts of participating employees shall be carried forward into their payroll deduction accounts under a successor plan, if any, or refunded to them, as the Committee may decide.

(e) In the event of the termination of a participating employee’s employment for any reason, his or her participation in any offering under the Plan shall cease, no further amounts shall be deducted pursuant to the Plan and the balance in the employee’s account shall be paid to the employee, or, in the event of the employee’s death, to the employee’s beneficiary under the Company’s basic group life insurance program.

8. Purchase; Limitations

(a) Within the limitations of Section 8(d) below, each employee participating in any offering under the Plan will be granted an option, upon the effective date of such offering, for as many full shares of Common Stock as the amount of his or her payroll deduction account (including any contributions made by means other than payroll deductions) at the end of the offering can purchase.

(b) As of the last day of the offering period, the payroll deduction account of each participating employee shall be totaled. Subject to the provisions of Section 7(b) above and 8(d) below, if such account contains sufficient funds as of that date to purchase one or more full shares of Common Stock at the price determined under Section 8(c) below, the employee shall be deemed to have exercised an option to purchase the largest number of full shares of Common Stock at the price determined under Section 8(c) below that his or her payroll deduction account will permit; such employee’s account will be charged for the amount of the purchase and for all purposes under the Plan the employee will be deemed to have acquired the shares on that date; and either a stock certificate representing such shares will be issued to him or her, or the Company’s registrar will make an entry on its books and records evidencing that such shares have been duly issued or transferred as of that date, as the Committee may direct. Notwithstanding any provision of the Plan to the contrary, the Committee may but need not permit fractional shares to be purchased under the Plan.

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(c) Unless the Committee determines before the effective date of an offering that a higher price that complies with Section 423 of the Code shall apply, the purchase price of the shares of Common Stock which are to be sold under the offering shall be the lesser of (i) an amount equal to 85 percent of the Fair Market Value of the Common Stock at the time such option is granted, or (ii) an amount equal to 85 percent of the Fair Market Value of the Common Stock at the time such option is exercised.

(d) In addition to any other limitations set forth in the Plan, (i) no employee may purchase in any offering period more than the number of shares of Common Stock determined by dividing the employee’s annual Base Compensation as of the first day of the offering period, or $25,000, whichever is less, by the Fair Market Value of a share of Common Stock at such day, and (ii) no employee may be granted an option under the Plan which permits his or her rights to purchase stock under the Plan, and any other stock purchase plan of his or her employer corporation and its parent and subsidiary corporations that is qualified under Section 423 of the Code, to accrue at a rate which exceeds $25,000 of the Fair Market Value of such stock (determined at the time such option is granted) for each calendar year in which the option is outstanding at any time. The Committee may further limit the amount of Common Stock which may be purchased by any employee during an offering period in accordance with Section 423(b)(5) of the Code.

9. No Transfer

(a) No option, right or benefit under the Plan (including any derivative security within the meaning of paragraph (a)(2) of SEC Rule 16b-3) may be transferred by a participating employee, whether by will, the laws of descent and distribution, or otherwise, and all options, rights and benefits under the Plan may be exercised during the participating employee’s lifetime only by such employee.

(b) Book entry accounts and certificates for shares of Common Stock purchased under the Plan may be maintained or registered, as the case may be, only in the name of the participating employee or, if such employee so indicates on his or her payroll deduction authorization form, in his or her name jointly with a member of his or her family, with right of survivorship. An employee who is a resident of a jurisdiction which does not recognize such a joint tenancy may have book entry accounts maintained and certificates registered in the employee’s name as tenant in common with a member of the employee’s family, without right of survivorship.

10. Effective Date and Duration of Plan

The Plan shall become effective when adopted by the Board, provided that the stockholders of the Company approve it within 12 months thereafter at a duly held stockholders’ meeting. If not so approved by shareholders, the Plan shall be null, void and of no force or effect. If so approved, the Plan shall remain in effect until all shares authorized to be issued or transferred hereunder have been exhausted or until the Plan is sooner terminated by the Board of Directors, and may continue in effect thereafter with respect to any options outstanding at the time of such termination if the Board of Directors so provides.

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11. Amendment and Termination of the Plan

The Plan may be amended by the Board of Directors, without shareholder approval, at any time and in any respect, unless shareholder approval of the amendment in question is required under Oklahoma law, the Code (including without limitation Code Section 423 and Treasury Regulation Section 1.423-2(c)(4) thereunder), any exemption from Section 16 of the Exchange Act (including without limitation SEC Rule 16b-3) for which the Company intends Section 16 Persons to qualify, any national securities exchange or system on which the Stock is then listed or reported, by any regulatory body having jurisdiction with respect to the Plan, or under any other applicable laws, rules or regulations. The Plan provisions that determine the amount, price and timing of option grants to Section 16 Persons may not be amended more than once every six months, other than to comport with changes in the Internal Revenue Code, the Employee Retirement Income Security Act of 1974, or the rules thereunder, unless the General Counsel determines that such restriction on amendments is not necessary to secure or maintain any exemption from Section 16 of the Exchange Act for which the Company intends Section 16 Persons to qualify. The Plan may also be terminated at any time by the Board of Directors.

12. General Provisions

(a) Nothing contained in this Plan shall be deemed to confer upon any person any right to continue as an employee of or to be associated in any other way with the Company for any period of time or at any particular rate of compensation.

(b) No person shall have any rights as a stockholder of the Company with respect to any shares optioned under the Plan until such shares are issued or transferred to him or her.

(c) All expenses of adopting and administering the Plan shall be borne by the Company, and none of such expenses shall be charged to any participant.

(d) The Plan shall be governed by and construed under the laws of the State of Oklahoma, without giving effect to the principles of conflicts of laws of that State.

(e) The Plan and each offering under the Plan is intended to qualify as an employee stock purchase plan within the meaning of Section 423 of the Code. Transactions under the Plan by or with respect to Section 16 Persons are also intended to qualify for exemption under SEC Rule 16b-3, unless the Committee specifically determines otherwise. Every provision of the Plan shall be administered, interpreted and construed to carry out those intentions, and any provision that cannot be so administered, interpreted and construed shall to that extent be disregarded.

7

EX-31.1

Exhibit 31.1

Certification

I, John W. Gibson, 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 1, 2012

/s/ John W. Gibson

John W. Gibson

Chief Executive Officer

EX-31.2

Exhibit 31.2

Certification

I, Robert F. Martinovich, 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 1, 2012

/s/ Robert F. Martinovich

Robert F. Martinovich

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, 2012, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, John W. Gibson, 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/ John W. Gibson

John W. Gibson

Chief Executive Officer

August 2, 2012

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, 2012, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Robert F. Martinovich, 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/ Robert F. Martinovich

Robert F. Martinovich

Chief Financial Officer

August 1, 2012

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

XML

FAIR VALUE MEASUREMENTS, Fair Value Measurements - Part 2 (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation Calculation [Roll Forward]
Balance, beginning	$ 14,178	$ 1,624	$ 17,821	$ 19,730
Total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets and liabilities still held as of June 30	253	7,606	(1,059)	5,890
Total realized/unrealized gains (losses):
Included in earnings	(1,597)	(4,550)	(4,840)	(12,009)
Included in other comprehensive income (loss)	20,942	1,297	26,727	(8,558)
Sale of discontinued operations			(3,636)
Transfers into Level 3	(28)	4,757		4,182
Transfers out of Level 3		(482)	(2,577)	(699)
Balance, ending	33,495	2,646	33,495	2,646
Derivative Financial Instruments, Assets Liabilities [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation Calculation [Roll Forward]
Balance, beginning	17,948	30,615	25,104	49,266
Total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets and liabilities still held as of June 30	1,571	11,278	(419)	12,524
Total realized/unrealized gains (losses):
Included in earnings	(1,117)	(12,329)	(7,873)	(20,333)
Included in other comprehensive income (loss)	20,942	1,297	26,727	(8,558)
Sale of discontinued operations			(3,636)
Transfers into Level 3	(28)	4,757		4,182
Transfers out of Level 3		(482)	(2,577)	(699)
Balance, ending	37,745	23,858	37,745	23,858
Firm Commitments [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation Calculation [Roll Forward]
Balance, beginning	(3,770)	(28,991)	(7,283)	(29,536)
Total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets and liabilities still held as of June 30	(1,318)	(3,672)	(640)	(6,634)
Total realized/unrealized gains (losses):
Included in earnings	(480)	7,779	3,033	8,324
Included in other comprehensive income (loss)	0	0	0	0
Sale of discontinued operations			0
Transfers into Level 3	0	0		0
Transfers out of Level 3		0	0	0
Balance, ending	$ (4,250)	$ (21,212)	$ (4,250)	$ (21,212)

XML

EMPLOYEE BENEFIT PLANS (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Pension Benefits [Member]
Components of net periodic benefit cost
Service cost	$ 5,325	$ 5,003	$ 10,650	$ 10,006
Interest cost	14,809	14,689	29,618	29,378
Expected return on assets	(20,689)	(18,875)	(41,378)	(37,750)
Amortization of unrecognized prior service cost	242	255	484	509
Amortization of net loss	12,111	8,927	24,222	17,855
Net periodic benefit cost	11,798	9,999	23,596	19,998
Postretirement Benefits [Member]
Components of net periodic benefit cost
Service cost	1,240	1,257	2,477	2,515
Interest cost	3,473	3,958	6,946	7,916
Expected return on assets	(2,671)	(2,568)	(5,342)	(5,136)
Amortization of unrecognized net asset at adoption	718	797	1,436	1,594
Amortization of unrecognized prior service cost	(2,063)	(501)	(4,126)	(1,002)
Amortization of net loss	3,296	2,031	6,592	4,062
Net periodic benefit cost	$ 3,993	$ 4,974	$ 7,983	$ 9,949

XML

ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011	Dec. 31, 2011
Balance of accumulated other comprehensive income (loss) [Abstract]
Unrealized Gains (Losses) on Energy Marketing and Risk Management Assets/Liabilities	$ (43,452)		$ (43,452)		$ (55,367)
Unrealized Holding Gains (Losses) on Investment Securities	1,107		1,107		987
Pension and Postretirement Benefit Plan Obligations	(163,295)		(163,295)		(151,741)
Accumulated Other Comprehensive Income (Loss)	(205,640)		(205,640)		(206,121)
Other comprehensive income (loss) attributable to ONEOK [Abstract]
Unrealized Gains (Losses) on Energy Marketing and Risk Management Assets/Liabilities			11,915
Unrealized Holding Gains (Losses) on Investment Securities	(104)	(49)	120	(148)
Pension and Postretirement Benefit Plan Obligations	(5,777)	(4,672)	(11,554)	(9,345)
Accumulated Other Comprehensive Income (Loss)			$ 481

XML

UNCONSOLIDATED AFFILIATES (Tables)

6 Months Ended

Jun. 30, 2012

UNCONSOLIDATED AFFILIATES [Abstract]

Equity Earnings from Investments

Equity Earnings from Investments -The following table sets forth our equity earnings from investments for the periods indicated.  All amounts in the table below are equity earnings from investments in our ONEOK Partners segment:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2012		2011		2012		2011
	(Thousands of dollars)
Northern Border Pipeline Company	$	16,077	$	16,395	$	36,308	$	37,247
Overland Pass Pipeline		5,979		5,360		11,296		9,736
Fort Union Gas Gathering		3,195		3,711		7,403		6,676
Bighorn Gas Gathering		796		1,845		1,961		3,338
Other		3,122		2,233		6,821		4,639
Equity earnings from investments	$	29,169	$	29,544	$	63,789	$	61,636

Unconsolidated Affiliates Financial Information

Unconsolidated Affiliates Financial Information - The following tables set forth summarized combined financial information of our unconsolidated affiliates for the periods indicated:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2012		2011		2012		2011
	(Thousands of dollars)
Income Statement
Operating revenues	$	119,286	$	121,002	$	247,210	$	244,303
Operating expenses	$	57,727	$	51,988	$	112,295	$	106,224
Net income	$	59,812	$	59,244	$	125,066	$	122,409
Distributions paid to ONEOK Partners	$	43,254	$	38,541	$	84,195	$	71,052

XML

ONEOK PARTNERS (Policies)

6 Months Ended

Jun. 30, 2012

ONEOK PARTNERS [Abstract]

Cash Distributions

Cash Distributions - We receive distributions from ONEOK Partners on our common and Class B units and our 2-percent general partner interest, which includes our incentive distribution rights.  Under ONEOK Partners’ partnership agreement, as amended, 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 ONEOK Partners’ partnership agreement, as amended.  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 ONEOK Partners’ partnership agreement, as amended, 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.

XML

ONEOK PARTNERS (Details) (USD $)

3 Months Ended

6 Months Ended

12 Months Ended

Jun. 30, 2012

Mar. 31, 2012

Jun. 30, 2011

Jun. 30, 2012

Jun. 30, 2011

Dec. 31, 2011

Related Party Transaction [Line Items]

Issuance of common units (in dollars per unit)

$ 59.27

Issuance of common units (in units)

8,000,000

Issuance of common units, in value

$ 459,680,000

$ 0

Issuance of Common Units Sold in Private Placement (in units)

8,000,000

Issuance of Common Units Sold in Private Placement (in value)

460,000,000

Face Value

350,000,000

350,000,000

Interest rate (in hundredths)

5.90%

5.90%

Repayment on line of credit facility

295,000,000

Maturity date

Apr. 01, 2012

Increase (decrease) in paid-in-capital

(51,100,000)

Ownership interest (in hundredths)

43.40%

42.80%

Total distributions paid

187,952,000

149,814,000

352,035,000

297,590,000

Total distributions declared

198,943,000

153,890,000

386,895,000

303,704,000

Revenues

81,050,000

98,699,000

156,755,000

195,492,000

Expenses

Cost of sales and fuel

5,769,000

12,440,000

15,044,000

23,171,000

Administrative and general expenses

62,636,000

57,214,000

118,997,000

113,509,000

Total expenses

68,405,000

69,654,000

134,041,000

136,680,000

Partnership agreement

Cash Distributions - We receive distributions from ONEOK Partners on our common and Class B units and our 2-percent general partner interest, which includes our incentive distribution rights.  Under ONEOK Partners’ partnership agreement, as amended, 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 ONEOK Partners’ partnership agreement, as amended.  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 ONEOK Partners’ partnership agreement, as amended, 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.

Maximum borrowing capacity

1,200,000,000

1,200,000,000

Dividend Paid [Member]

Related Party Transaction [Line Items]

Distribution per unit

$ 0.635

$ 0.575

$ 1.245

$ 1.145

Dividend Declared [Member]

Related Party Transaction [Line Items]

Distribution per unit

$ 0.660

$ 0.585

$ 1.295

$ 1.160

General Partner [Member]

Related Party Transaction [Line Items]

Contribution from general partner

19,100,000

Ownership interest (in hundredths)

2.00%

General Partner [Member] | Dividend Paid [Member]

Related Party Transaction [Line Items]

General partner distributions

3,759,000

2,996,000

7,040,000

5,952,000

Incentive distributions

44,610,000

29,624,000

81,082,000

58,269,000

Distributions to general partner

48,369,000

32,620,000

88,122,000

64,221,000

General Partner [Member] | Dividend Declared [Member]

Related Party Transaction [Line Items]

General partner distributions

3,979,000

3,078,000

7,738,000

6,074,000

Incentive distributions

49,886,000

31,580,000

94,496,000

61,204,000

Distributions to general partner

53,865,000

34,658,000

102,234,000

67,278,000

Limited Partner [Member]

Related Party Transaction [Line Items]

Ownership interest (in hundredths)

41.40%

Common units

19,800,000

19,800,000

Class B units

73,000,000

73,000,000

Limited Partner [Member] | Dividend Paid [Member]

Related Party Transaction [Line Items]

Limited partner distributions to ONEOK

58,921,000

48,753,000

110,642,000

97,083,000

Limited partner distributions to noncontrolling interest

80,662,000

68,441,000

153,271,000

136,286,000

Limited Partner [Member] | Dividend Declared [Member]

Related Party Transaction [Line Items]

Limited partner distributions to ONEOK

61,240,000

49,601,000

120,161,000

98,354,000

Limited partner distributions to noncontrolling interest

$ 83,838,000

$ 69,631,000

$ 164,500,000

$ 138,072,000

XML

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES, Part 2 (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011	Dec. 31, 2011
Derivative Instruments, Gain (Loss) [Line Items]
Premiums recorded in other current assets on natural gas contracts held	$ 6,300,000		$ 6,300,000		$ 10,000,000
Entity Information [Line Items]
Gains related to the change in fair value of derivatives	1,600,000	4,200,000	1,100,000	9,600,000
Change in fair value of the related hedged firm commitments for transportation contracts	2,200,000	4,400,000	300,000	9,400,000
Fair value of collateral	3,100,000		3,100,000
Aggregate fair value of additional collateral	3,100,000		3,100,000
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	99,493,000		99,493,000
Financial [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	72,676,000		72,676,000
Gas and Electric Utilities [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	18,019,000		18,019,000
Oil and Gas [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	8,397,000		8,397,000
Other companies [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	401,000		401,000
Investment Grade [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	98,517,000		98,517,000
Investment Grade [Member] | Financial [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	72,674,000		72,674,000
Investment Grade [Member] | Gas and Electric Utilities [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	17,911,000		17,911,000
Investment Grade [Member] | Oil and Gas [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	7,932,000		7,932,000
Investment Grade [Member] | Other companies [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	0		0
Non-Investment Grade [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	6,000		6,000
Non-Investment Grade [Member] | Financial [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	0		0
Non-Investment Grade [Member] | Gas and Electric Utilities [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	0		0
Non-Investment Grade [Member] | Oil and Gas [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	0		0
Non-Investment Grade [Member] | Other companies [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	6,000		6,000
Not Rated [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	970,000		970,000
Not Rated [Member] | Financial [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	2,000		2,000
Not Rated [Member] | Gas and Electric Utilities [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	108,000		108,000
Not Rated [Member] | Oil and Gas [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	465,000		465,000
Not Rated [Member] | Other companies [Member]
Derivative Credit Exposure [Line Items]
Derivative Credit Exposure	395,000		395,000
Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	(17,407,000)	21,847,000	49,168,000	3,545,000
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income on derivatives (effective portion)	31,005,000	(3,708,000)	30,571,000	28,643,000
Cash Flow Hedging [Member] | Commodity Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	35,349,000	21,847,000	80,914,000	3,545,000
Cash Flow Hedging [Member] | Interest Rate Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	(52,756,000)	0	(31,746,000)	0
Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total gain recognized in income on derivatives	1,852,000	7,670,000	5,130,000	10,624,000
Cost of Sales and Fuel [Member] | Cash Flow Hedging [Member] | Commodity Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income on derivatives (effective portion)	(1,460,000)	(108,000)	(63,437,000)	(936,000)
Cost of Sales and Fuel [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Non-trading [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total gain recognized in income on derivatives	1,361,000	7,959,000	4,324,000	10,507,000
Interest Expense [Member] | Cash Flow Hedging [Member] | Interest Rate Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income on derivatives (effective portion)	(1,195,000)	(90,000)	(2,022,000)	(298,000)
Revenues [Member] | Cash Flow Hedging [Member] | Commodity Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income on derivatives (effective portion)	33,660,000	(3,510,000)	96,030,000	29,877,000
Revenues [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Trading [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total gain recognized in income on derivatives	$ 491,000	$ (289,000)	$ 806,000	$ 117,000

XML

DISCONTINUED OPERATIONS (Details) (USD $)	1 Months Ended	3 Months Ended		6 Months Ended
	Jan. 31, 2012	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011	Jul. 31, 2012	Dec. 31, 2011
DISCONTINUED OPERATIONS [Abstract]
Description and timing of discontinued operations				On February 1, 2012, we sold ONEOK Energy Marketing Company, our retail natural gas marketing business, to Constellation Energy Group, Inc. for $22.5 million plus working capital.
Proceeds from sale of business				$ 32,900,000
Proceeds from divestiture of businesses after quarter close						900,000
Revenues	27,607,000		69,677,000		175,966,000
Cost of sales and fuel	25,961,000		66,862,000		169,479,000
Net margin	1,646,000		2,815,000		6,487,000
Operating costs	408,000		2,084,000		4,017,000
Depreciation and amortization	8,000		33,000		65,000
Operating income	1,230,000		698,000		2,405,000
Other income (expense), net	0		(1,000)		15,000
Income taxes	(468,000)		(260,000)		(922,000)
Income from discontinued operations, net	762,000		437,000		1,498,000
Gain on sale of discontinued operations		267,000	0	13,517,000	0
Gain on sale of business, tax impact				8,300,000
Assets
Cash and cash equivalents							8,859,000
Accounts recievable, net							47,967,000
Gas in storage							2,101,000
Energy marketing and risk management assets							15,016,000
Other assets							193,000
Assets of discontinued operations							74,136,000
Liabilities
Accounts payable							11,435,000
Energy marketing and risk management liabilities							629,000
Other liabilities							751,000
Liabilities of discontinued operations							12,815,000
Intercompany payables							$ 45,700,000

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SEGMENTS (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011	Dec. 31, 2011
Segment Reporting Information [Line Items]
Ownership interest (in hundredths)			43.40%		42.80%
Sales to unaffiliated customers	$ 2,529,260	$ 3,444,798	$ 5,943,860	$ 7,205,398
Intersegment revenues	0	0	0	0
Total revenues	2,529,260	3,444,798	5,943,860	7,205,398
Net margin	548,962	518,833	1,192,549	1,148,710
Operating costs	231,263	223,609	455,321	445,290
Depreciation and amortization	84,586	78,793	167,995	158,150
Goodwill impairment	0	0	10,255	0
Gain (loss) on sale of assets	966	(212)	1,023	(722)
Operating income	234,079	216,219	560,001	544,548
Equity earnings from investments	29,169	29,544	63,789	61,636
Investments in unconsolidated affiliates	1,210,268	1,177,219	1,210,268	1,177,219	1,223,398
Total assets	13,817,191	13,036,333	13,817,191	13,036,333	13,696,635
Noncontrolling interests in consolidated subsidiaries	2,116,448	1,480,615	2,116,448	1,480,615	1,561,159
Capital expenditures	432,260	329,093	780,697	523,772
Description of benchmark criteria			10 percent or more of our consolidated gross revenues
ONEOK Partners [Member]
Segment Reporting Information [Line Items]
Sales to unaffiliated customers	2,043,756	2,685,520	4,562,139	5,088,337
Intersegment revenues	81,050	98,699	156,755	195,492
Total revenues	2,124,806	2,784,219	4,718,894	5,283,829
Net margin	401,462	359,540	822,552	689,094
Operating costs	123,364	113,581	239,234	222,324
Depreciation and amortization	51,014	43,714	100,270	86,444
Goodwill impairment			0
Gain (loss) on sale of assets	966	(212)	1,023	(722)
Operating income	228,050	202,033	484,071	379,604
Equity earnings from investments	29,169	29,544	63,789	61,636
Investments in unconsolidated affiliates	1,210,268	1,177,219	1,210,268	1,177,219
Total assets	9,376,537	8,642,136	9,376,537	8,642,136
Noncontrolling interests in consolidated subsidiaries	5,028	5,185	5,028	5,185
Capital expenditures	355,443	265,333	636,236	410,159
ONEOK Partners [Member] | Regulated Segment [Member]
Segment Reporting Information [Line Items]
Total revenues	160,200	153,000	331,400	308,500
Net margin	100,600	113,200	223,500	229,100
Operating income	54,100	53,500	118,700	113,100
Natural Gas Distribution Regulated Segment [Member]
Segment Reporting Information [Line Items]
Sales to unaffiliated customers	221,181	253,917	738,104	933,324
Intersegment revenues	2	3,065	843	7,840
Total revenues	221,183	256,982	738,947	941,164
Net margin	157,488	159,141	394,836	402,875
Operating costs	103,774	104,516	208,760	209,213
Depreciation and amortization	31,999	34,436	65,519	70,383
Goodwill impairment			0
Gain (loss) on sale of assets	0	0	0	0
Operating income	21,715	20,189	120,557	123,279
Equity earnings from investments	0	0	0	0
Investments in unconsolidated affiliates	0	0	0	0
Total assets	3,153,679	3,134,134	3,153,679	3,134,134
Noncontrolling interests in consolidated subsidiaries	0	0	0	0
Capital expenditures	72,917	61,899	131,365	109,049
Energy Services [Member]
Segment Reporting Information [Line Items]
Sales to unaffiliated customers	263,897	504,756	642,595	1,182,556
Intersegment revenues	5,028	111,273	87,138	325,212
Total revenues	268,925	616,029	729,733	1,507,768
Net margin	(10,412)	(433)	(25,858)	55,516
Operating costs	4,626	5,298	9,465	13,302
Depreciation and amortization	77	111	206	259
Goodwill impairment			10,255
Gain (loss) on sale of assets	0	0	0	0
Operating income	(15,115)	(5,842)	(45,784)	41,955
Equity earnings from investments	0	0	0	0
Investments in unconsolidated affiliates	0	0	0	0
Total assets	549,623	559,976	549,623	559,976
Noncontrolling interests in consolidated subsidiaries	0	0	0	0
Capital expenditures	0	3	0	3
Corporate Elimination [Member]
Segment Reporting Information [Line Items]
Sales to unaffiliated customers	426	605	1,022	1,181
Intersegment revenues	(86,080)	(213,037)	(244,736)	(528,544)
Total revenues	(85,654)	(212,432)	(243,714)	(527,363)
Net margin	424	585	1,019	1,225
Operating costs	(501)	214	(2,138)	451
Depreciation and amortization	1,496	532	2,000	1,064
Goodwill impairment			0
Gain (loss) on sale of assets	0	0	0	0
Operating income	(571)	(161)	1,157	(290)
Equity earnings from investments	0	0	0	0
Investments in unconsolidated affiliates	0	0	0	0
Total assets	737,352	700,087	737,352	700,087
Noncontrolling interests in consolidated subsidiaries	2,111,420	1,475,430	2,111,420	1,475,430
Capital expenditures	$ 3,900	$ 1,858	$ 13,096	$ 4,561

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EARNINGS PER SHARE (Details) (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Basic EPS from continuing operations [Abstract]
Net income attributable to ONEOK available for common stock	$ 60,726	$ 54,705	$ 169,579	$ 183,774
Weighted Average number of share, basic (in shares)	207,292	210,674	207,454	212,358
Per share amount, basic (in dollars per shares)	$ 0.29	$ 0.26	$ 0.82	$ 0.87
Diluted EPS from continuing operations [Abstract]
Effect of options and other dilutive securities	0	0	0	0
Effect of options and other dilutive securities, number of shares (in shares)	4,492	5,386	4,364	4,852
Net income attributable to ONEOK available for common stock and common stock equivalents, diluted	$ 60,726	$ 54,705	$ 169,579	$ 183,774
Weighted Average number of share, diluted (in shares)	211,784	216,060	211,818	217,210
Per Share amount, diluted (in dollars per share)	$ 0.29	$ 0.25	$ 0.80	$ 0.85

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CONSOLIDATED STATEMENT OF CHANGES IN EQUITY Parenthetical (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY [Abstract]
Dividends declared per share of common stock	$ 0.330	$ 0.260	$ 0.635	$ 0.520

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CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE (Details) (USD $)	6 Months Ended
	Jun. 30, 2012
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 1,200,000,000
ONEOK 2011 Credit Agreement [Member]
Line of Credit Facility [Line Items]
Expiration date	April 2016
Maximum debt-to-capital ratio (in hundredths)	67.50%
Current debt-to-capital ratio (in hundredths)	50.50%
Commercial paper	571,900,000
Letters of credit issued	1,700,000
Remaining available borrowing capacity to meet liquidity needs	626,400,000
Maximum borrowing capacity	1,200,000,000
Option to increase borrowing capacity	1,700,000,000
Cash and Cash Equivalents on a standalone basis	22,800,000
ONEOK Partners 2011 Credit Agreement [Member]
Line of Credit Facility [Line Items]
Expiration date	August 2017
Original Expiration Date	August 2016
Partnership 2011 Credit Agreement sublimit for issuance of standby letters of credit	100,000,000
Commercial paper	24,000,000
Debt to EBITDA covenant ratio, before amendment	5.0 to 1
Acquisition price threshold for increase in permitted debt to EBITDA covenant ratio	25,000,000
Debt to EBITDA covenant ratio, amendment	5.5 to 1
Debt to EBITDA covenant, period end	2.3 to 1
Maximum borrowing capacity	1,200,000,000
Option to increase borrowing capacity	$ 1,700,000,000

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EQUITY (Tables)

6 Months Ended

Jun. 30, 2012

EQUITY [Abstract]

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

The following tables set 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, 2012										June 30, 2011
	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	$	2,256,152		$	2,123,303			$	4,379,455		$	2,499,084		$	1,457,934			$	3,957,018
Net income		60,993			88,212				149,205			55,142			79,624				134,766
Other comprehensive income (loss)		(26,795	)		(14,276	)			(41,071	)		3,871			11,572				15,443
Repurchase of common stock		(150,000	)		-				(150,000	)		(300,057	)		-				(300,057	)
Common stock issued		3,991			-				3,991			14,754			-				14,754
Common stock dividends		(63,397	)		-				(63,397	)		(55,705	)		-				(55,705	)
Issuance of common units of ONEOK Partners		-			(55	)			(55	)		-			-				-
Distributions to noncontrolling interests		-			(80,736	)			(80,736	)		-			(68,515	)			(68,515	)
Other		8,596			-				8,596			-			-				-
Ending balance	$	2,089,540		$	2,116,448			$	4,205,988		$	2,217,089		$	1,480,615			$	3,697,704

	Six Months Ended										Six Months Ended
	June 30, 2012										June 30, 2011
	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	$	2,238,573		$	1,561,159			$	3,799,732		$	2,448,623		$	1,472,218			$	3,920,841
Net income		183,858			198,809				382,667			185,272			148,840				334,112
Other comprehensive income (loss)		481			(712	)			(231	)		(22,464	)		(3,887	)			(26,351	)
Repurchase of common stock		(150,000	)		-				(150,000	)		(300,105	)		-				(300,105	)
Common stock issued		6,552			-				6,552			17,119			-				17,119
Common stock dividends		(126,772	)		-				(126,772	)		(111,356	)		-				(111,356	)
Issuance of common units of ONEOK Partners		(51,100	)		510,780				459,680			-			-				-
Distributions to noncontrolling interests		-			(153,588	)			(153,588	)		-			(136,556	)			(136,556	)
Other		(12,052	)		-				(12,052	)		-			-				-
Ending balance	$	2,089,540		$	2,116,448			$	4,205,988		$	2,217,089		$	1,480,615			$	3,697,704

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES (Tables)

6 Months Ended

Jun. 30, 2012

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES [Abstract]

Fair value of derivatives

Fair Values of Derivative Instruments - The following table sets forth the fair values of our derivative instruments for our continuing and discontinued operations for the periods indicated:

	June 30, 2012						December 31, 2011
	Fair Values of Derivatives (a)						Fair Values of Derivatives (a)
	Assets			(Liabilities)			Assets			(Liabilities)
	(Thousands of dollars)
Derivatives designated as hedging instruments
Commodity contracts
Financial contracts	$	136,655	(b)	$	(48,014	)(b)	$	184,184	(c)	$	(73,346	)(c)
Physical contracts		165			(71	)		62			(344	)
Interest-rate contracts		-			(116,166	)		-			(128,666	)
Total derivatives designated as hedging instruments		136,820			(164,251	)		184,246			(202,356	)
Derivatives not designated as hedging instruments
Commodity contracts
Nontrading instruments
Financial contracts		190,780			(197,993	)		295,948			(323,170	)
Physical contracts		15,087			(618	)		38,733			(1,665	)
Trading instruments
Financial contracts		76,807			(75,122	)		111,920			(110,050	)
Total derivatives not designated as hedging instruments		282,674			(273,733	)		446,601			(434,885	)
Total derivatives	$	419,494		$	(437,984	)	$	630,847		$	(637,241	)
(a) - Included on a net basis in energy marketing and risk management assets and liabilities, other assets and other deferred credits on our Consolidated Balance Sheets.
(b) - Includes $7.5 million of derivative assets associated with cash flow purchase hedges tied to injections of inventory into storage that were adjusted to reflect the lower of cost or market value in a prior period. The deferred gains associated with these assets have been reclassified from accumulated other comprehensive loss.
(c) - Includes $88.9 million of derivative assets associated with cash flow hedges of inventory that were adjusted to reflect the lower of cost or market value. The deferred gains associated with these assets have been reclassified from accumulated other comprehensive loss.

Notional amounts of derivative instruments

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

		June 30, 2012					December 31, 2011
	Contract Type	Purchased/ Payor		Sold/ Receiver			Purchased/ Payor		Sold/ Receiver
Derivatives designated as hedging instruments:
Cash flow hedges
Fixed price
- Natural gas (Bcf)	Exchange futures		8.1		(16.7	)		21.2		(23.4	)
	Swaps		8.5		(90.3	)		19.5		(111.9	)
- Crude oil and NGLs (MMBbl)	Swaps		-		(2.6	)		-		(2.9	)
Basis
- Natural gas (Bcf)	Forwards and swaps		13.7		(45.5	)		3.2		(82.8	)
Interest-rate contracts (Millions of dollars)	Forward-starting swaps	$	1,000.0		-		$	1,250.0		-
Fair value hedges
Basis
- Natural gas (Bcf)	Forwards and swaps		91.0		(91.0	)		76.5		(77.0	)
Derivatives not designated as hedging instruments:
Fixed price
- Natural gas (Bcf)	Exchange futures		56.1		(44.7	)		76.9		(59.6	)
	Forwards and swaps		136.0		(149.2	)		235.8		(253.4	)
	Options		205.0		(205.3	)		33.6		(14.3	)
Basis
- Natural gas (Bcf)	Forwards and swaps		159.3		(164.6	)		216.9		(219.3	)
Index
- Natural gas (Bcf)	Forwards and swaps		34.5		(15.3	)		29.3		(22.1	)

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 the periods indicated:

	Three Months Ended					Six Months Ended
Derivatives in Cash Flow	June 30,					June 30,
Hedging Relationships	2012			2011		2012			2011
	(Thousands of dollars)
Commodity contracts	$	35,349		$	21,847	$	80,914		$	3,545
Interest-rate contracts		(52,756	)		-		(31,746	)		-
Total gain (loss) recognized in other comprehensive income (loss) on    derivatives (effective portion)	$	(17,407	)	$	21,847	$	49,168		$	3,545

Schedule of cash flow hedging instruments effect on income

The following tables set forth the effect of cash flow hedges on our Consolidated Statements of Income for the periods indicated:

	Location of Gain (Loss) Reclassified from	Three Months Ended
Derivatives in Cash Flow	Accumulated Other Comprehensive Income	June 30,
Hedging Relationships	(Loss) into Net Income (Effective Portion)	2012			2011
		(Thousands of dollars)
Commodity contracts	Revenues	$	33,660		$	(3,510	)
Commodity contracts	Cost of sales and fuel		(1,460	)		(108	)
Interest-rate contracts	Interest expense		(1,195	)		(90	)
Total gain (loss) reclassified from accumulated other comprehensive income (loss)    into net income on derivatives (effective portion)		$	31,005		$	(3,708	)

	Location of Gain (Loss) Reclassified from	Six Months Ended
Derivatives in Cash Flow	Accumulated Other Comprehensive Income	June 30,
Hedging Relationships	(Loss) into Net Income (Effective Portion)	2012			2011
		(Thousands of dollars)
Commodity contracts	Revenues	$	96,030		$	29,877
Commodity contracts	Cost of sales and fuel		(63,437	)		(936	)
Interest-rate contracts	Interest expense		(2,022	)		(298	)
Total gain (loss) reclassified from accumulated other comprehensive income (loss)    into net income on derivatives (effective portion)		$	30,571		$	28,643

Schedule of derivatives not designated as hedging effect on income

Other Derivative Instruments - The following table sets forth the effect of our derivative instruments that are not part of a hedging relationship in our Consolidated Statements of Income for our continuing and discontinued operations for the periods indicated:

		Three Months Ended					Six Months Ended
Derivatives Not Designated as		June 30,					June 30,
Hedging Instruments	Location of Gain (Loss)	2012		2011			2012		2011
		(Thousands of dollars)
Commodity contracts - trading	Revenues	$	491	$	(289	)	$	806	$	117
Commodity contracts - nontrading (a)	Cost of sales and fuel		1,361		7,959			4,324		10,507
Total gain recognized in income on derivatives		$	1,852	$	7,670		$	5,130	$	10,624
(a) - Amounts are presented net of deferred losses associated with derivatives entered into by our Natural Gas Distribution segment.

Schedule of net credit exposure from derivative assets

The following table sets forth the net credit exposure from our derivative assets for the period indicated:

	June 30, 2012
	Investment		Noninvestment		Not
	Grade		Grade		Rated		Total
Counterparty sector	(Thousands of dollars)
Gas and electric utilities	$	17,911	$	-	$	108	$	18,019
Oil and gas		7,932		-		465		8,397
Financial		72,674		-		2		72,676
Other		-		6		395		401
Total	$	98,517	$	6	$	970	$	99,493

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LONG-TERM DEBT (Details) (USD $)

3 Months Ended

6 Months Ended

Jun. 30, 2012

Jun. 30, 2011

Jun. 30, 2012

Jun. 30, 2011

Debt Instrument [Line Items]

Face Amount

$ 350,000,000

$ 350,000,000

Interest rate (in hundredths)

5.90%

5.90%

Maximum borrowing capacity

1,200,000,000

1,200,000,000

Maturity date

Apr. 01, 2012

Interest costs, capitalized during period

9,700,000

4,200,000

18,700,000

7,400,000

Oneok [Member] | Notes Payables due 2022 [Member]

Debt Instrument [Line Items]

Interest rate (in hundredths)

4.25%

4.25%

Debt instrument call feature

ONEOK may redeem its senior notes due 2022 at a redemption price equal to the principal amount, plus accrued and unpaid interest, starting three months before the maturity date.  Prior to this date, ONEOK may redeem the senior notes due 2022, in whole or in part, at any time for a redemption price equal to the principal amount plus accrued and unpaid interest and a make-whole premium.  The redemption price will never be less than 100 percent of the principal amount of the respective note plus accrued and unpaid interest to the redemption date.  ONEOK’s senior notes due 2022 are senior unsecured obligations, ranking equally in right of payment with all of ONEOK’s existing and future unsecured senior indebtedness.

Debt instrument covenant description

The indenture governing ONEOK’s senior notes due 2022 includes an event of default upon the acceleration of other indebtedness of $100 million or more.  Such events of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of the outstanding senior notes due 2022 to declare those senior notes immediately due and payable in full.

Maximum borrowing capacity

1,200,000,000

1,200,000,000

Underwritten public offering

700,000,000

700,000,000

Net proceeds from public offering

$ 694,300,000

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Tables)

6 Months Ended

Jun. 30, 2012

ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) [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		Unrealized Holding Gains (Losses) on Investment Securities		Pension and Postretirement Benefit Plan Obligations		Accumulated Other Comprehensive Income (Loss)
		(Thousands of dollars)
December 31, 2011	$	(55,367)	$	987	$	(151,741)	$	(206,121)
Other comprehensive income (loss)    attributable to ONEOK		11,915		120		(11,554)		481
June 30, 2012	$	(43,452)	$	1,107	$	(163,295)	$	(205,640)

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EARNINGS PER SHARE (Tables)

6 Months Ended

Jun. 30, 2012

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, 2012
	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	$	60,726		207,292	$	0.29
Diluted EPS from continuing operations
Effect of options and other dilutive securities		-		4,492
Income from continuing operations attributable to ONEOK
available for common stock and common stock equivalents	$	60,726		211,784	$	0.29

	Three Months Ended June 30, 2011
	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	$	54,705		210,674	$	0.26
Diluted EPS from continuing operations
Effect of options and other dilutive securities		-		5,386
Income from continuing operations attributable to ONEOK
available for common stock and common stock equivalents	$	54,705		216,060	$	0.25

	Six Months Ended June 30, 2012
	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	$	169,579		207,454	$	0.82
Diluted EPS from continuing operations
Effect of options and other dilutive securities		-		4,364
Income from continuing operations attributable to ONEOK
available for common stock and common stock equivalents	$	169,579		211,818	$	0.80

	Six Months Ended June 30, 2011
	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	$	183,774		212,358	$	0.87
Diluted EPS from continuing operations
Effect of options and other dilutive securities		-		4,852
Income from continuing operations attributable to ONEOK
available for common stock and common stock equivalents	$	183,774		217,210	$	0.85

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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, 2010	$ 3,920,841						$ 1,472,218
Net income	334,112						148,840
Other comprehensive income (loss)	(26,351)						(3,887)
Repurchase of common stock	(300,105)						0
Common stock issued	17,119						0
Common stock dividends - $0.61 per share	(111,356)						0
Issuance of common units of ONEOK Partners	0						0
Distributions to noncontrolling interests	(136,556)						(136,556)
Other	0						0
Stockholders' equity, ending balance at Jun. 30, 2011	3,697,704						1,480,615
Stockholders' equity, beginning balance at Mar. 31, 2011	3,957,018						1,457,934
Net income	134,766						79,624
Other comprehensive income (loss)	15,443						11,572
Repurchase of common stock	(300,057)						0
Common stock issued	14,754						0
Common stock dividends - $0.61 per share	(55,705)						0
Issuance of common units of ONEOK Partners	0						0
Distributions to noncontrolling interests	(68,515)						(68,515)
Other	0						0
Stockholders' equity, ending balance at Jun. 30, 2011	3,697,704						1,480,615
Stockholders' equity, beginning balance at Dec. 31, 2011	3,799,732	2,458	1,417,185	(206,121)	1,960,374	(935,323)	1,561,159
Common stock issued, beginning balance (in shares) at Dec. 31, 2011		245,809,848
Net income	382,667	0	0	0	183,858	0	198,809
Other comprehensive income (loss)	(231)	0	0	481	0	0	(712)
Repurchase of common stock	(150,000)	0	0	0	0	(150,000)	0
Common stock issued	6,552		(27,829)	0	0	34,381	0
Common stock issued (in shares)		1,332
Common stock dividends - $0.61 per share	(126,772)	0	0	0	(126,772)	0	0
Issuance of common units of ONEOK Partners	459,680	0	(51,100)	0	0	0	510,780
Distributions to noncontrolling interests	(153,588)	0	0	0	0	0	(153,588)
Other	(12,052)	0	(12,052)	0	0	0	0
Stockholders' equity, ending balance at Jun. 30, 2012	4,205,988	2,458	1,326,204	(205,640)	2,017,460	(1,050,942)	2,116,448
Common stock issued, ending balance (in shares) at Jun. 30, 2012		245,811,180
Stockholders' equity, beginning balance at Mar. 31, 2012	4,379,455						2,123,303
Net income	149,205						88,212
Other comprehensive income (loss)	(41,071)						(14,276)
Repurchase of common stock	(150,000)						0
Common stock issued	3,991						0
Common stock dividends - $0.61 per share	(63,397)						0
Issuance of common units of ONEOK Partners	(55)						(55)
Distributions to noncontrolling interests	(80,736)						(80,736)
Other	8,596						0
Stockholders' equity, ending balance at Jun. 30, 2012	$ 4,205,988						$ 2,116,448

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EMPLOYEE BENEFIT PLANS (Tables)

6 Months Ended

Jun. 30, 2012

EMPLOYEE BENEFIT PLANS [Abstract]

The components of net periodic benefit cost

The following table sets forth the components of net periodic benefit cost for our pension and postretirement benefit plans for the periods indicated:

	Pension Benefits						Pension Benefits
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2012			2011			2012			2011
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	5,325		$	5,003		$	10,650		$	10,006
Interest cost		14,809			14,689			29,618			29,378
Expected return on assets		(20,689	)		(18,875	)		(41,378	)		(37,750	)
Amortization of unrecognized prior service cost		242			255			484			509
Amortization of net loss		12,111			8,927			24,222			17,855
Net periodic benefit cost	$	11,798		$	9,999		$	23,596		$	19,998

	Postretirement Benefits						Postretirement Benefits
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2012			2011			2012			2011
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	1,240		$	1,257		$	2,477		$	2,515
Interest cost		3,473			3,958			6,946			7,916
Expected return on assets		(2,671	)		(2,568	)		(5,342	)		(5,136	)
Amortization of unrecognized net asset at adoption		718			797			1,436			1,594
Amortization of unrecognized prior service cost		(2,063	)		(501	)		(4,126	)		(1,002	)
Amortization of net loss		3,296			2,031			6,592			4,062
Net periodic benefit cost	$	3,993		$	4,974		$	7,983		$	9,949

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FAIR VALUE MEASUREMENTS, Fair Value - Part 3 (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012 Energy Services [Member]	Dec. 31, 2011 Energy Services [Member]	Jun. 30, 2012 Carrying (Reported) Amount, Fair Value Disclosure [Member]	Dec. 31, 2011 Carrying (Reported) Amount, Fair Value Disclosure [Member]	Jun. 30, 2012 Estimate of Fair Value, Fair Value Disclosure [Member]	Dec. 31, 2011 Estimate of Fair Value, Fair Value Disclosure [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including current maturities							$ 5,200,000	$ 4,900,000	$ 5,900,000	$ 5,600,000
Goodwill impairment						10,255
Goodwill, Impairment Loss	$ 0	$ 0	$ 10,255	$ 0	$ 10,255

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CONSOLIDATED STATEMENTS OF INCOME (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
CONSOLIDATED STATEMENTS OF INCOME [Abstract]
Revenues	$ 2,529,260	$ 3,444,798	$ 5,943,860	$ 7,205,398
Cost of sales and fuel	1,980,298	2,925,965	4,751,311	6,056,688
Net margin	548,962	518,833	1,192,549	1,148,710
Operating expenses
Operations and maintenance	204,126	197,772	397,007	390,531
Depreciation and amortization	84,586	78,793	167,995	158,150
Goodwill impairment	0	0	10,255	0
General taxes	27,137	25,837	58,314	54,759
Total operating expenses	315,849	302,402	633,571	603,440
Gain (loss) on sale of assets	966	(212)	1,023	(722)
Operating income	234,079	216,219	560,001	544,548
Equity earnings from investments (Note K)	29,169	29,544	63,789	61,636
Allowance for equity funds used during construction	1,849	400	2,824	866
Other income	686	340	6,446	3,692
Other expense	(4,898)	(772)	(3,071)	(3,057)
Interest expense	(71,535)	(75,498)	(147,350)	(154,847)
Income before income taxes	189,350	170,233	482,639	452,838
Income taxes	(40,412)	(35,904)	(114,251)	(120,224)
Income from continuing operations	148,938	134,329	368,388	332,614
Income from discontinued operations, net of tax (Note B)	0	437	762	1,498
Gain on sale of discontinued operations, net of tax (Note B)	267	0	13,517	0
Net income	149,205	134,766	382,667	334,112
Less: Net income attributable to noncontrolling interests	88,212	79,624	198,809	148,840
Net income attributable to ONEOK	60,993	55,142	183,858	185,272
Amounts attributable to ONEOK:
Income from continuing operations	60,726	54,705	169,579	183,774
Income from discontinued operations	267	437	14,279	1,498
Net income	$ 60,993	$ 55,142	$ 183,858	$ 185,272
Basic earnings per share:
Income from continuing operations (Note I)	$ 0.29	$ 0.26	$ 0.82	$ 0.87
Income from discontinued operations	$ 0	$ 0	$ 0.07	$ 0
Net income	$ 0.29	$ 0.26	$ 0.89	$ 0.87
Diluted earnings per share:
Income from continuing operations (Note I)	$ 0.29	$ 0.25	$ 0.80	$ 0.85
Income from discontinued operations	$ 0	$ 0	$ 0.07	$ 0
Net income	$ 0.29	$ 0.25	$ 0.87	$ 0.85
Average shares (thousands)
Basic	207,292	210,674	207,454	212,358
Diluted	211,784	216,060	211,818	217,210
Dividends declared per share of common stock	$ 0.330	$ 0.260	$ 0.635	$ 0.520

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EQUITY (Details) (USD $) Share data in Millions, except Per Share data, unless otherwise specified	3 Months Ended				6 Months Ended		12 Months Ended
	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011	Dec. 31, 2010
Stockholders' equity, beginning balance	$ 4,379,455,000	$ 3,799,732,000		$ 3,957,018,000	$ 3,799,732,000	$ 3,920,841,000
Net income	149,205,000			134,766,000	382,667,000	334,112,000
Other comprehensive income (loss)	(41,071,000)			15,443,000	(231,000)	(26,351,000)
Repurchase of common stock	(150,000,000)			(300,057,000)	(150,000,000)	(300,105,000)
Common stock issued	3,991,000			14,754,000	6,552,000	17,119,000
Common stock dividends	(63,397,000)			(55,705,000)	(126,772,000)	(111,356,000)
Issuance of common units of ONEOK Partners	(55,000)			0	459,680,000	0
Stockholders' equity, ending balance	4,205,988,000	4,379,455,000	3,799,732,000	3,697,704,000	4,205,988,000	3,697,704,000	3,920,841,000
Distributions to noncontrolling interests	(80,736,000)			(68,515,000)	(153,588,000)	(136,556,000)
Other	8,596,000			0	(12,052,000)	0
Dividend paid (in dollars per share)	$ 0.33	$ 0.305	$ 0.305
Accelerated share repurchases price paid	150,000,000				150,000,000
Accelerated share repurchases shares	2.9				2.9
Accelerated share repurchases shares percentage of total	80.00%				80.00%
Accelerated share repurchases authorized amount							750,000,000
Accelerated share repurchases maximum amount of purchases allowed in any one calendar year							300,000,000
Accelerated share repurchases initial price paid			300,000,000
Accelerated share repurchases additional amount yet to be purchased	300,000,000				300,000,000
Accelerated share repurchases remaining maximum amount of purchases in current year					150,000,000
Accelerated share repurchases agreement date to be settled	Sep. 12, 2012				Sep. 12, 2012
ONEOK Shareholders' Equity [Member]
Stockholders' equity, beginning balance	2,256,152,000	2,238,573,000		2,499,084,000	2,238,573,000	2,448,623,000
Net income	60,993,000			55,142,000	183,858,000	185,272,000
Other comprehensive income (loss)	(26,795,000)			3,871,000	481,000	(22,464,000)
Repurchase of common stock	(150,000,000)			(300,057,000)	(150,000,000)	(300,105,000)
Common stock issued	3,991,000			14,754,000	6,552,000	17,119,000
Common stock dividends	(63,397,000)			(55,705,000)	(126,772,000)	(111,356,000)
Issuance of common units of ONEOK Partners	0			0	(51,100,000)	0
Stockholders' equity, ending balance	2,089,540,000			2,217,089,000	2,089,540,000	2,217,089,000
Distributions to noncontrolling interests	0			0	0	0
Other	8,596,000			0	(12,052,000)	0
Noncontrolling Interests in Consolidated Subsidiaries [Member]
Stockholders' equity, beginning balance	2,123,303,000	1,561,159,000		1,457,934,000	1,561,159,000	1,472,218,000
Net income	88,212,000			79,624,000	198,809,000	148,840,000
Other comprehensive income (loss)	(14,276,000)			11,572,000	(712,000)	(3,887,000)
Repurchase of common stock	0			0	0	0
Common stock issued	0			0	0	0
Common stock dividends	0			0	0	0
Issuance of common units of ONEOK Partners	(55,000)			0	510,780,000	0
Stockholders' equity, ending balance	2,116,448,000			1,480,615,000	2,116,448,000	1,480,615,000
Distributions to noncontrolling interests	(80,736,000)			(68,515,000)	(153,588,000)	(136,556,000)
Other	$ 0			$ 0	$ 0	$ 0

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CONSOLIDATED BALANCE SHEETS Parenthetical (USD $)	Jun. 30, 2012	Dec. 31, 2011
CONSOLIDATED BALANCE SHEETS Parenthetical [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	245,809,848
Common stock, shares, outstanding (in shares)	205,041,894	206,509,960
Treasury stock, shares (in shares)	40,769,286	39,299,888

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SEGMENTS (Tables)

6 Months Ended

Jun. 30, 2012

SEGMENTS [Abstract]

Segments

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

Three Months Ended June 30, 2012	ONEOK Partners (a)		Natural Gas Distribution		Energy Services			Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	2,043,756	$	221,181	$	263,897		$	426		$	2,529,260
Intersegment revenues		81,050		2		5,028			(86,080	)		-
Total revenues	$	2,124,806	$	221,183	$	268,925		$	(85,654	)	$	2,529,260
Net margin	$	401,462	$	157,488	$	(10,412	)	$	424			548,962
Operating costs		123,364		103,774		4,626			(501	)		231,263
Depreciation and amortization		51,014		31,999		77			1,496			84,586
Gain on sale of assets		966		-		-			-			966
Operating income	$	228,050	$	21,715	$	(15,115	)	$	(571	)	$	234,079
Equity earnings from investments	$	29,169	$	-	$	-		$	-		$	29,169
Capital expenditures	$	355,443	$	72,917	$	-		$	3,900		$	432,260
(a) - Our ONEOK Partners segment has regulated and nonregulated operations. Our ONEOK Partners segment’s regulated operations had revenues of $160.2 million, net margin of $100.6 million and operating income of $54.1 million.

Three Months Ended June 30, 2011	ONEOK Partners (a)			Natural Gas Distribution		Energy Services			Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	2,685,520		$	253,917	$	504,756		$	605		$	3,444,798
Intersegment revenues		98,699			3,065		111,273			(213,037	)		-
Total revenues	$	2,784,219		$	256,982	$	616,029		$	(212,432	)	$	3,444,798
Net margin	$	359,540		$	159,141	$	(433	)	$	585		$	518,833
Operating costs		113,581			104,516		5,298			214			223,609
Depreciation and amortization		43,714			34,436		111			532			78,793
Loss on sale of assets		(212	)		-		-			-			(212	)
Operating income	$	202,033		$	20,189	$	(5,842	)	$	(161	)	$	216,219
Equity earnings from investments	$	29,544		$	-	$	-		$	-		$	29,544
Capital expenditures	$	265,333		$	61,899	$	3		$	1,858		$	329,093
(a) - Our ONEOK Partners segment has regulated and nonregulated operations. Our ONEOK Partners segment’s regulated operations had revenues of $153.0 million, net margin of $113.2 million and operating income of $53.5 million.

Six Months Ended June 30, 2012	ONEOK Partners (a)		Natural Gas Distribution		Energy Services			Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	4,562,139	$	738,104	$	642,595		$	1,022		$	5,943,860
Intersegment revenues		156,755		843		87,138			(244,736	)		-
Total revenues	$	4,718,894	$	738,947	$	729,733		$	(243,714	)	$	5,943,860
Net margin	$	822,552	$	394,836	$	(25,858	)	$	1,019		$	1,192,549
Operating costs		239,234		208,760		9,465			(2,138	)		455,321
Depreciation and amortization		100,270		65,519		206			2,000			167,995
Goodwill impairment		-		-		10,255			-			10,255
Gain on sale of assets		1,023		-		-			-			1,023
Operating income	$	484,071	$	120,557	$	(45,784	)	$	1,157		$	560,001
Equity earnings from investments	$	63,789	$	-	$	-		$	-		$	63,789
Investments in unconsolidated    affiliates	$	1,210,268	$	-	$	-		$	-		$	1,210,268
Total assets	$	9,376,537	$	3,153,679	$	549,623		$	737,352		$	13,817,191
Noncontrolling interests in    consolidated subsidiaries	$	5,028	$	-	$	-		$	2,111,420		$	2,116,448
Capital expenditures	$	636,236	$	131,365	$	-		$	13,096		$	780,697
(a) - Our ONEOK Partners segment has regulated and nonregulated operations. Our ONEOK Partners segment’s regulated operations had revenues of $331.4 million, net margin of $223.5 million and operating income of $118.7 million.

Six Months Ended June 30, 2011	ONEOK Partners (a)			Natural Gas Distribution		Energy Services		Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	5,088,337		$	933,324	$	1,182,556	$	1,181		$	7,205,398
Intersegment revenues		195,492			7,840		325,212		(528,544	)		-
Total revenues	$	5,283,829		$	941,164	$	1,507,768	$	(527,363	)	$	7,205,398
Net margin	$	689,094		$	402,875	$	55,516	$	1,225		$	1,148,710
Operating costs		222,324			209,213		13,302		451			445,290
Depreciation and amortization		86,444			70,383		259		1,064			158,150
Loss on sale of assets		(722	)		-		-		-			(722	)
Operating income	$	379,604		$	123,279	$	41,955	$	(290	)	$	544,548
Equity earnings from investments	$	61,636		$	-	$	-	$	-		$	61,636
Investments in unconsolidated    affiliates	$	1,177,219		$	-	$	-	$	-		$	1,177,219
Total assets	$	8,642,136		$	3,134,134	$	559,976	$	700,087		$	13,036,333
Noncontrolling interests in    consolidated subsidiaries	$	5,185		$	-	$	-	$	1,475,430		$	1,480,615
Capital expenditures	$	410,159		$	109,049	$	3	$	4,561		$	523,772
(a) - Our ONEOK Partners segment has regulated and nonregulated operations. Our ONEOK Partners segment’s regulated operations had revenues of $308.5 million, net margin of $229.1 million and operating income of $113.1 million.

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COMMITMENTS AND CONTINGENCIES

6 Months Ended

Jun. 30, 2012

COMMITMENTS AND CONTINGENCIES [Abstract]

COMMITMENTS AND CONTINGENCIES

M.           COMMITMENTS AND CONTINGENCIES

Environmental Matters - We are subject to multiple historical and wildlife preservation laws and environmental regulations affecting many aspects of our present and future operations.  Regulated activities include those involving air emissions, storm water and wastewater discharges, handling and disposal of solid and hazardous wastes, hazardous materials transportation, and pipeline and facility construction.  These laws and regulations require us to obtain and 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 us to fines, penalties and/or interruptions in our operations that could be material to our results of operations.  If a leak or spill of hazardous substances or petroleum products occurs from pipelines or facilities that we own, operate or otherwise use, we could be held jointly and severally liable for all resulting liabilities, including response, investigation and cleanup costs, which could affect materially our results of operations and cash flows.  In addition, emission controls required under the Clean Air Act and other similar federal and state laws could require unexpected capital expenditures at our facilities.  We cannot assure that existing environmental regulations will not be revised or that new regulations will not be adopted or become applicable to us.  Revised or additional regulations that result in increased compliance costs or additional operating restrictions could have a material adverse effect on our business, financial condition, results of operations and cash flows.

We own or retain legal responsibility for the environmental conditions at 12 former manufactured natural gas sites in Kansas.  These sites contain potentially harmful materials that are subject to control or remediation under various environmental laws and regulations.  A consent agreement with the KDHE presently governs all work at these sites.  The terms of the consent agreement allow us to investigate these sites and set remediation activities based upon the results of the investigations and risk analysis.  Remediation typically involves the management of contaminated soils and may involve removal of structures and monitoring and/or remediation of groundwater.

Of the 12 sites, we have begun soil remediation on 11 sites.  Regulatory closure has been achieved at three locations, and we have completed or are near completion of soil remediation at eight sites.  We have begun site assessment at the remaining site where no active remediation has occurred.

Our expenditures for environmental evaluation, mitigation, remediation and compliance to date have not been material in relation to our financial position, results of operations or cash flows, and our expenditures related to environmental matters had no material effects on earnings or cash flows during the three and six months ended June 30, 2012 or 2011.

In May 2010, the EPA finalized the “Tailoring Rule” that will regulate greenhouse gas emissions at new or modified facilities that meet certain criteria.  Affected facilities will be required to review best available control technology, conduct air-quality analysis, impact analysis and public reviews with respect to such emissions.  The rule was phased in beginning January 2011, and at current emission threshold levels, we believe it will have a minimal impact on our existing facilities.  The EPA has stated it will consider lowering the threshold levels over the next five years, which could increase the impact on our existing facilities; however, potential costs, fees or expenses associated with the potential adjustments are unknown.

In addition, the EPA has issued a rule on air-quality standards, “National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines,” also known as RICE NESHAP, with a compliance date in 2013.  The rule will require capital expenditures over the next two years for the purchase and installation of new emissions-control equipment.  We do not expect these expenditures to have a material impact on our results of operations, financial position or cash flows.

In July 2011, the EPA issued a proposed rule that would change the air emission New Source Performance Standards, also known as NSPS, and Maximum Achievable Control Technology requirements applicable to the oil and gas industry, including natural gas production, processing, transmission and underground storage.  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 will become effective after it is published in the Federal Register.  It will require expenditures for updated emissions controls, monitoring and record keeping requirements at affected facilities.  We do not expect these expenditures to have a material impact on our results of operations, financial position or cash flows.

Pipeline Safety - We are subject to Pipeline and Hazardous Materials Safety Administration regulations, including 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 new law increased the 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 us.  These issues include but are not limited to:

·   an evaluation of whether hazardous natural gas liquid 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 liquid 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 pipelines previously untested in high-consequence areas operating above 30 percent yield strength.

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.  Various regulatory agencies, including the SEC and the CFTC, have proposed regulations for implementation of many of the provisions of the Dodd-Frank Act.  The CFTC has issued final regulations for certain provisions of the Dodd-Frank Act, but others remain outstanding.  In July 2012, the CFTC issued an order that further defers the effective date of the provisions of the Dodd-Frank Act that require a rulemaking, such as definitions of certain terms, until the earlier of the effective date of the final rule defining the referenced terms or December 31, 2012.  The CFTC issued the definitional rules in late May and early July 2012 that will become effective 60 days after publication in the Federal Register.  We are reviewing the rules to ascertain how we may be affected by them.  Based on our assessment of the regulations issued to date and those proposed, we expect to be able to continue to participate in financial markets for hedging certain risks inherent in our business, including commodity and interest-rate risks; however, the capital requirements and costs of hedging may increase as a result of the legislation.  We also may incur additional costs associated with our compliance with the new regulations and anticipated additional record keeping, reporting and disclosure obligations; however, we do not believe the costs will be material.  These requirements could affect adversely market liquidity and pricing of derivative contracts making it more difficult to execute our risk-management strategies in the future.  Also, the anticipated increased costs of compliance by dealers and counterparties likely will be passed on to customers, which could decrease the benefits of hedging to us and could reduce our profitability and liquidity.

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

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details)

6 Months Ended

Jun. 30, 2012

Summary of Significant Accounting Policies [Abstract]

Recently Issued Accounting Standards Update

Recently Issued Accounting Standards Update -In May 2011, the FASB issued ASU 2011-04, “Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and International Financial Reporting Standards (IFRS),” which provides a consistent definition of fair value and common requirements for measurement of and disclosure about fair value between GAAP and IFRS.  This new guidance changes some fair value measurement principles and disclosure requirements.  We adopted this guidance with our March 31, 2012, Quarterly Report, and the impact was not material.  See Note C for information on our fair value measurements.

In June 2011, the FASB issued ASU 2011-05, “Presentation of Comprehensive Income,” which provides two options for presenting items of net income, other comprehensive income and total comprehensive income either by creating one continuous statement of comprehensive income or two separate consecutive statements, and requires certain other disclosures.  In December 2011, the FASB issued ASU 2011-12, “Deferral of the Effective Date for Amendments to the Presentation of Reclassifications of Items Out of Accumulated Other Comprehensive Income in Accounting Standards Update No. 2011-05,” which deferred certain presentation requirements in ASU 2011-05 for items reclassified out of accumulated other comprehensive income.  We adopted this guidance, except for the portions deferred by ASU 2011-12, with our March 31, 2012, Quarterly Report, and the impact was not material.

In July 2012, the FASB issued ASU 2012-02, “Testing Indefinite-lived Intangible Assets for Impairment,” which allows companies to perform a “qualitative” assessment to determine whether further impairment testing of indefinite-lived intangible assets is necessary.  Under the revised standard, an entity is not required to calculate the fair value of an indefinite-lived intangible asset and perform the quantitative impairment test unless the entity determines that it is more likely than not that the asset is impaired.  An entity has the option to bypass the qualitative assessment and perform the quantitative impairment test for any indefinite-lived intangible assets in any period.  We are evaluating the impact of this recently issued guidance, which is required to be adopted for our annual assessments beginning in 2013.

Stock Split

Stock Split - In June 2012, we completed our previously announced two-for-one split of our common stock.  The two-for-one split was effected by a distribution on June 1, 2012, of one share of stock for each share outstanding and held by shareholders of record on May 24, 2012.  We have adjusted all share and per-share amounts contained herein, to be presented on a post-split basis.

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES (Policies)

6 Months Ended

Jun. 30, 2012

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES [Abstract]

Accounting treatment for derivative instruments

Accounting Treatment -We 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.

If certain conditions are met, we may elect to designate a derivative instrument as a hedge of exposure to changes in fair values, cash flows or foreign currency.  Certain nontrading derivative transactions, which are economic hedges of our accrual transactions such as our storage and transportation contracts, do not qualify for hedge accounting treatment.

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

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

Gains or losses associated with the fair value of derivative instruments entered into by our Natural Gas Distribution segment are included in, and recoverable through, the monthly purchased-gas cost mechanism.

We 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 specifically identify the asset, liability, firm commitment or forecasted transaction that has been designated as the hedged item.  We assess the effectiveness of hedging relationships quarterly by performing an effectiveness analysis on our cash flow and fair value hedging relationships to determine whether the hedge relationships are highly effective on a retrospective and prospective basis.  We also document our normal purchases and normal sales transactions that we expect to result in physical delivery and that we elect to exempt from derivative accounting treatment.

The presentation of settled derivative instruments on either a gross or net basis in our Consolidated Statements of Income is dependent on the relevant facts and circumstances of our different types of activities rather than based solely on the terms of the individual contracts.  All financially settled derivative instruments, as well as derivative instruments considered held for trading purposes that result in physical delivery, are reported on a net basis in revenues in our Consolidated Statements of Income.  The realized revenues and purchase costs of derivative instruments that are not considered held for trading purposes and nonderivative contracts are reported on a gross basis.  Derivatives that qualify as normal purchases or normal sales that are expected to result in physical delivery are also reported on a gross basis.

Revenues in our Consolidated Statements of Income include financial trading margins, as well as certain physical natural gas transactions with our trading counterparties.  Revenues and cost of sales and fuel from such physical transactions are reported on a net basis.

Cash flows from futures, forwards, options 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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CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011
Operating Activities
Net income	$ 382,667	$ 334,112
Depreciation and amortization	168,003	158,215
Impairment of goodwill	10,255	0
Gain on sale of discontinued operations	(13,517)	0
Reclassified loss on energy price risk management assets and liabilities	29,861	0
Equity earnings from investments	(63,789)	(61,636)
Distributions received from unconsolidated affiliates	69,490	55,302
Deferred income taxes	111,172	108,504
Share-based compensation expense	16,928	29,615
Allowance for equity funds used during construction	(2,824)	(866)
Loss (gain) on sale of assets	(1,023)	722
Other	(1,308)	(1,013)
Changes in assets and liabilities:
Accounts receivable	541,053	209,112
Gas and natural gas liquids in storage	(11,445)	134,760
Accounts payable	(404,006)	(20,199)
Commodity imbalances, net	25,045	(12,452)
Energy marketing and risk management assets and liabilities	(56,590)	(4,437)
Other assets and liabilities	(147,362)	(54,140)
Cash provided by operating activities	652,610	875,599
Investing Activities
Capital expenditures (less allowance for equity funds used during construction)	(780,697)	(523,772)
Proceeds from sale of discontinued operations, net of cash sold	32,008	0
Contributions to unconsolidated affiliates	(7,237)	(1,655)
Distributions received from unconsolidated affiliates	14,705	15,750
Proceeds from sale of assets	1,828	788
Other	942	0
Cash used in investing activities	(738,451)	(508,889)
Financing Activities
Borrowing (repayment) of notes payable, net	(246,051)	(30,222)
Issuance of debt, net of discounts	699,657	1,295,450
Long-term debt financing costs	(5,395)	(10,986)
Repayment of debt	(356,173)	(631,316)
Repurchase of common stock	(150,000)	(300,105)
Issuance of common stock	4,591	4,920
Issuance of common units, net of issuance costs	459,680	0
Dividends paid	(126,772)	(111,356)
Distributions to noncontrolling interests	(153,588)	(136,556)
Cash provided by financing activities	125,949	79,829
Change in cash and cash equivalents	40,108	446,539
Change in cash and cash equivalents included in discontinued operations	8,859	(4,701)
Change in cash and cash equivalents from continuing operations	48,967	441,838
Cash and cash equivalents at beginning of period	65,953	30,341
Cash and cash equivalents at end of period	$ 114,920	$ 472,179

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME [Abstract]
Net income	$ 149,205	$ 134,766	$ 382,667	$ 334,112
Other comprehensive income (loss), net of tax
Unrealized gains (losses) on energy marketing and risk-management assets/liabilities, net of tax of $4,773, $(5,028), $(14,229) and $(3,614), respectively	(12,634)	16,819	34,939	(69)
Realized (gains) losses in net income, net of tax of $8,449, $(301), $6,835 and $11,934, respectively	(22,556)	3,407	(23,736)	(16,709)
Unrealized holding gains (losses) on available-for-sale securities, net of tax of $65, $31, $(76) and $94, respectively	(104)	(49)	120	(148)
Change in pension and postretirement benefit plan liability, net of tax of $3,644, $2,947, $7,288 and $5,895, respectively	(5,777)	(4,672)	(11,554)	(9,345)
Other, net of tax of $0, $39, $0 and $50, respectively	0	(62)	0	(80)
Total other comprehensive income (loss), net of tax	(41,071)	15,443	(231)	(26,351)
Comprehensive income	108,134	150,209	382,436	307,761
Less: Comprehensive income attributable to noncontrolling interests	73,936	91,196	198,097	144,953
Comprehensive income attributable to ONEOK	$ 34,198	$ 59,013	$ 184,339	$ 162,808

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

6 Months Ended

Jun. 30, 2012

ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) [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		Unrealized Holding Gains (Losses) on Investment Securities		Pension and Postretirement Benefit Plan Obligations		Accumulated Other Comprehensive Income (Loss)
		(Thousands of dollars)
December 31, 2011	$	(55,367)	$	987	$	(151,741)	$	(206,121)
Other comprehensive income (loss)    attributable to ONEOK		11,915		120		(11,554)		481
June 30, 2012	$	(43,452)	$	1,107	$	(163,295)	$	(205,640)

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Document And Entity Information (USD $) In Billions, except Share data, unless otherwise specified	6 Months Ended
	Jun. 30, 2012	Jul. 27, 2012	Jun. 30, 2011
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 Public Float			$ 7.3
Entity Common Stock, Shares Outstanding		205,056,209
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q2
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2012

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EARNINGS PER SHARE

6 Months Ended

Jun. 30, 2012

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, 2012
	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	$	60,726		207,292	$	0.29
Diluted EPS from continuing operations
Effect of options and other dilutive securities		-		4,492
Income from continuing operations attributable to ONEOK
available for common stock and common stock equivalents	$	60,726		211,784	$	0.29

	Three Months Ended June 30, 2011
	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	$	54,705		210,674	$	0.26
Diluted EPS from continuing operations
Effect of options and other dilutive securities		-		5,386
Income from continuing operations attributable to ONEOK
available for common stock and common stock equivalents	$	54,705		216,060	$	0.25

	Six Months Ended June 30, 2012
	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	$	169,579		207,454	$	0.82
Diluted EPS from continuing operations
Effect of options and other dilutive securities		-		4,364
Income from continuing operations attributable to ONEOK
available for common stock and common stock equivalents	$	169,579		211,818	$	0.80

	Six Months Ended June 30, 2011
	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	$	183,774		212,358	$	0.87
Diluted EPS from continuing operations
Effect of options and other dilutive securities		-		4,852
Income from continuing operations attributable to ONEOK
available for common stock and common stock equivalents	$	183,774		217,210	$	0.85

There were no option shares excluded from the calculation of diluted EPS for the three and six months ended June 30, 2012 and 2011.

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME Parenthetical (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Other comprehensive income (loss), net of tax
Unrealized gains (losses) on energy marketing and risk-management assets/liabilities, tax	$ 4,773	$ (5,028)	$ (14,229)	$ (3,614)
Realized losses (gains) in net income, tax	8,449	(301)	6,835	11,934
Unrealized holding gains (losses) on available-for-sale securities, tax	65	31	(76)	94
Change in pension and postretirement benefit plan liability, tax	3,644	2,947	7,288	5,895
Other, tax	$ 0	$ 39	$ 0	$ 50

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FAIR VALUE MEASUREMENTS

6 Months Ended

Jun. 30, 2012

FAIR VALUE MEASUREMENTS [Abstract]

FAIR VALUE MEASUREMENTS

C.           FAIR VALUE MEASUREMENTS

Fair Value Measurements -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 the 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.

While many of the contracts in our portfolio are executed in liquid markets where price transparency exists, some contracts are executed in markets for which market prices may exist, but the market may be relatively inactive.  This results in limited price transparency that requires management’s judgment and assumptions to estimate fair values.  Inputs into our fair value estimates include commodity exchange prices, over-the-counter quotes, volatility, historical correlations of pricing data and LIBOR and other liquid money market instrument rates.  We also utilize internally developed basis curves that incorporate observable and unobservable market data.  We validate our valuation inputs with third-party information and settlement prices from other sources, where available.  In addition, as prescribed by the income approach, we compute the fair value of our derivative portfolio by discounting the projected future cash flows from our derivative assets and liabilities to present value using interest-rate yields to calculate present-value discount factors derived from LIBOR, Eurodollar futures and interest-rate swaps.  We also take into consideration the potential impact on market prices of liquidating positions in an orderly manner over a reasonable period of time under current market conditions.  We consider current market data in evaluating counterparties’, as well as our own, nonperformance risk, net of collateral, by using specific and sector bond yields and also monitor the credit default swap markets.  Although we use our best estimates to determine the fair value of the derivative contracts we have executed, the ultimate market prices realized could differ from our estimates, and the differences could be material.

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

	June 30, 2012
	Level 1			Level 2			Level 3			Netting			Total
	(Thousands of dollars)
Assets
Derivatives (a)
Commodity contracts
Financial contracts	$	330,358		$	27,248		$	46,636		$	-		$	404,242
Physical contracts		-			12,308			2,944			-			15,252
Netting		-			-			-			(320,001	)		(320,001	)
Total derivatives		330,358			39,556			49,580			(320,001	)		99,493
Trading securities (b)		6,326			-			-			-			6,326
Available-for-sale investment securities (c)		2,145			-			-			-			2,145
Total assets	$	338,829		$	39,556		$	49,580		$	(320,001	)	$	107,964
Liabilities
Derivatives (a)
Commodity contracts
Financial contracts	$	(304,810	)	$	(5,171	)	$	(11,148	)	$	-		$	(321,129	)
Physical contracts		-			(2	)		(687	)		-			(689	)
Netting		-			-			-			299,848			299,848
Interest-rate contracts		-			(116,166	)		-			-			(116,166	)
Total derivatives		(304,810	)		(121,339	)		(11,835	)		299,848			(138,136	)
Fair value of firm commitments (d)		-			-			(4,250	)		-			(4,250	)
Total liabilities	$	(304,810	)	$	(121,339	)	$	(16,085	)	$	299,848		$	(142,386	)
(a) - Our derivative assets and liabilities are presented in our Consolidated Balance Sheets as energy marketing and risk management assets and liabilities and other assets on a net basis. We net derivative assets and liabilities, including cash collateral, when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and us. At June 30, 2012, we held $21.7 million of cash collateral and had posted $8.4 million of cash collateral with various counterparties.
(b) - Included in our Consolidated Balance Sheets as other current assets.
(c) - Included in our Consolidated Balance Sheets as other assets.
(d) - Included in our Consolidated Balance Sheets as other current liabilities and other deferred credits.

	December 31, 2011
	Level 1			Level 2			Level 3			Netting			Total
	(Thousands of dollars)
Assets
Derivatives (a)
Commodity contracts
Financial contracts	$	545,247		$	13,874		$	32,931		$	-		$	592,052
Physical contracts		-			23,879			14,916			-			38,795
Netting		-			-			-			(569,243	)		(569,243	)
Total derivatives		545,247			37,753			47,847			(569,243	)		61,604
Trading securities (b)		5,749			-			-			-			5,749
Available-for-sale investment securities (c)		1,949			-			-			-			1,949
Total assets	$	552,945		$	37,753		$	47,847		$	(569,243	)	$	69,302
Liabilities
Derivatives (a)
Commodity contracts
Financial contracts	$	(479,073	)	$	(6,498	)	$	(20,995	)	$	-		$	(506,566	)
Physical contracts		-			(261	)		(1,748	)		-			(2,009	)
Netting		-			-			-			497,608			497,608
Interest-rate contracts		-			(128,666	)		-			-			(128,666	)
Total derivatives		(479,073	)		(135,425	)		(22,743	)		497,608			(139,633	)
Fair value of firm commitments (d)		-			-			(7,283	)		-			(7,283	)
Total liabilities	$	(479,073	)	$	(135,425	)	$	(30,026	)	$	497,608		$	(146,916	)
(a) - Our derivative assets and liabilities are presented in our Consolidated Balance Sheets as energy marketing and risk management assets and liabilities, other assets and other deferred credits on a net basis. We net derivative assets and liabilities, including cash collateral, when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and us. At December 31, 2011, we held $73.3 million of cash collateral and had posted $1.7 million of cash collateral with various counterparties.
(b) - Included in our Consolidated Balance Sheets as other current assets.
(c) - Included in our Consolidated Balance Sheets as other assets.
(d) - Included in our Consolidated Balance Sheets as other current liabilities and other deferred credits.

The December 31, 2011, table above includes balances for ONEOK Energy Marketing Company that have been reflected as discontinued operations in our Consolidated Balance Sheet.  At December 31, 2011, we had $15.0 million in derivative assets and $0.6 million in derivative liabilities related to this discontinued operation.

Our Level 1 fair value measurements are based on NYMEX-settled prices and actively quoted prices for equity securities.  These balances are comprised predominantly of exchange-traded derivative contracts, including futures and certain options for natural gas and crude oil, which are valued based on unadjusted quoted prices in active markets.  Also included in Level 1 are equity securities.

Our Level 2 fair value inputs are based on NYMEX-settled prices for natural gas and crude oil that are utilized to determine the fair value of certain nonexchange-traded financial instruments, including natural gas and crude oil swaps, as well as physical forwards.  Also, included in Level 2 are interest-rate swaps that are valued using financial models that incorporate the implied forward LIBOR yield curve for the same period as the future interest swap settlements.

Our Level 3 inputs include internally developed basis curves incorporating observable and unobservable market data, NGL price curves from independent broker quotes, market volatilities derived from the most recent NYMEX close spot prices and forward LIBOR curves, and adjustments for the credit risk of our counterparties.  We corroborate the data on which our fair value estimates are based using our market knowledge of recent transactions, analysis of historical correlations and validation with independent broker quotes.  The derivatives categorized as Level 3 include natural gas basis swaps, swing swaps, options, other commodity swaps and physical forward contracts.  Also included in Level 3 are the fair values of firm commitments.  We do not believe that our Level 3 fair value estimates have a material impact on our results of operations, as the majority of our derivatives are accounted for as hedges for which ineffectiveness is not material.  The significant unobservable inputs used in the fair value measurement of our swaps, forwards and firm commitments are the unpublished forward basis and index curves.  Significant increases or decreases in either of those inputs in isolation would not have a material impact on our fair value measurements.

The following tables set forth the reconciliation of our Level 3 fair value measurements for the periods indicated:

	Derivative Assets (Liabilities)			Fair Value of Firm Commitments			Total
	(Thousands of dollars)
April 1, 2012	$	17,948		$	(3,770	)	$	14,178
Total realized/unrealized gains (losses):
Included in earnings (a)		(1,117	)		(480	)		(1,597	)
Included in other comprehensive income (loss)		20,942			-			20,942
Transfers into Level 3		(28	)		-			(28	)
June 30, 2012	$	37,745		$	(4,250	)	$	33,495
Total gains (losses) for the period included in    earnings attributable to the change in unrealized    gains (losses) relating to assets and liabilities    still held as of June 30, 2012 (a)	$	1,571		$	(1,318	)	$	253
(a) - Reported in revenues and cost of sales and fuel in our Consolidated Statements of Income.

	Derivative Assets (Liabilities)			Fair Value of Firm Commitments			Total
	(Thousands of dollars)
April 1, 2011	$	30,615		$	(28,991	)	$	1,624
Total realized/unrealized gains (losses):
Included in earnings (a)		(12,329	)		7,779			(4,550	)
Included in other comprehensive income (loss)		1,297			-			1,297
Transfers into Level 3		4,757			-			4,757
Transfers out of Level 3		(482	)		-			(482	)
June 30, 2011	$	23,858		$	(21,212	)	$	2,646
Total gains (losses) for the period included in    earnings attributable to the change in unrealized    gains (losses) relating to assets and liabilities    still held as of June 30, 2011 (a)	$	11,278		$	(3,672	)	$	7,606
(a) - Reported in revenues and cost of sales and fuel in our Consolidated Statements of Income.

	Derivative Assets (Liabilities)			Fair Value of Firm Commitments			Total
	(Thousands of dollars)
January 1, 2012	$	25,104		$	(7,283	)	$	17,821
Total realized/unrealized gains (losses):
Included in earnings (a)		(7,873	)		3,033			(4,840	)
Included in other comprehensive income (loss)		26,727			-			26,727
Sale of discontinued operations		(3,636	)		-			(3,636	)
Transfers out of Level 3		(2,577	)		-			(2,577	)
June 30, 2012	$	37,745		$	(4,250	)	$	33,495
Total gains (losses) for the period included in    earnings attributable to the change in unrealized    gains (losses) relating to assets and liabilities    still held as of June 30, 2012 (a)	$	(419	)	$	(640	)	$	(1,059	)
(a) - Reported in revenues and cost of sales and fuel in our Consolidated Statements of Income.

	Derivative Assets (Liabilities)			Fair Value of Firm Commitments			Total
	(Thousands of dollars)
January 1, 2011	$	49,266		$	(29,536	)	$	19,730
Total realized/unrealized gains (losses):
Included in earnings (a)		(20,333	)		8,324			(12,009	)
Included in other comprehensive income (loss)		(8,558	)		-			(8,558	)
Transfers into Level 3		4,182			-			4,182
Transfers out of Level 3		(699	)		-			(699	)
June 30, 2011	$	23,858		$	(21,212	)	$	2,646
Total gains (losses) for the period included in    earnings attributable to the change in unrealized    gains (losses) relating to assets and liabilities    still held as of June 30, 2011 (a)	$	12,524		$	(6,634	)	$	5,890
(a) - Reported in revenues and cost of sales and fuel in our Consolidated Statements of Income.

Realized/unrealized gains (losses) include the realization of our derivative contracts through maturity and changes in fair value of our hedged firm commitments.  We recognize transfers into and out of the levels in the fair value hierarchy as of the end of each reporting period.  We had no transfers into or out of Level 1 during the periods presented.  Transfers into Level 3 represent existing assets or liabilities that were previously categorized at a higher level for which the unobservable inputs became a more significant portion of the fair value estimates.  Transfers out of Level 3 represent existing assets and liabilities that were classified previously as Level 3 for which the observable inputs became a more significant portion of the fair value estimates.

Our Level 3 fair value measurements based on unobservable inputs, excluding the portion of our fair value measurements based on third-party pricing information without adjustment, are not material at June 30, 2012.

Goodwill Impairment - As a result of the continued decline in natural gas prices and its effect on location and seasonal price differentials, we performed an interim impairment assessment of our Energy Services segment’s goodwill balance as of March 31, 2012. As a result of this assessment, goodwill with a carrying amount of $10.3 million was written down to its implied fair value of zero, with a resulting impairment charge of $10.3 million recorded in earnings for the three months ended March 31, 2012.  The fair value of our Energy Services reporting unit and the implied fair value of its goodwill were calculated using Level 3, significant unobservable inputs.

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 $5.9 billion at June 30, 2012, and $5.6 billion at December 31, 2011.  The book value of long-term debt, including current maturities, was $5.2 billion and $4.9 billion at June 30, 2012, and December 31, 2011, 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.  Our consolidated long-term debt is classified as Level 2.

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DISCONTINUED OPERATIONS

6 Months Ended

Jun. 30, 2012

DISCONTINUED OPERATIONS [Abstract]

DISCONTINUED OPERATIONS

B.           DISCONTINUED OPERATIONS

On February 1, 2012, we sold ONEOK Energy Marketing Company, our retail natural gas marketing business, to Constellation Energy Group, Inc. for $22.5 million plus working capital.  We received net proceeds of approximately $32.9 million, $0.9 million of which was received in July 2012, and recognized a gain on the sale of approximately $13.5 million, net of taxes of $8.3 million.  The proceeds from the sale were used to reduce short-term borrowings.  The financial information of ONEOK Energy Marketing Company is reflected as discontinued operations in this Quarterly Report.  All prior periods presented have been recast to reflect the discontinued operations.

The amounts of revenue, costs and income taxes reported in discontinued operations are set forth in the table below for the periods indicated:

	One Month Ended		Three Months Ended				Six Months Ended
	January 31,			June 30,			June 30,
	2012			2011			2011
	(Thousands of dollars)
Revenues	$	27,607		$	69,677		$	175,966
Cost of sales and fuel		25,961			66,862			169,479
Net margin		1,646			2,815			6,487
Operating costs		408			2,084			4,017
Depreciation and amortization		8			33			65
Operating income		1,230			698			2,405
Other income (expense), net		-			(1	)		15
Income taxes		(468	)		(260	)		(922	)
Income from discontinued operations, net	$	762		$	437		$	1,498

The following table discloses the major classes of discontinued assets and liabilities included on our Consolidated Balance Sheet for the period indicated:

		December 31,
		2011
Assets	(Thousands of dollars)
Cash and cash equivalents		$	8,859
Accounts receivable, net			47,967
Gas in storage			2,101
Energy marketing and risk management assets			15,016
Other assets			193
Assets of discontinued operations		$	74,136
Liabilities
Accounts payable		$	11,435
Energy marketing and risk management liabilities			629
Other liabilities			751
Liabilities of discontinued operations		$	12,815

At December 31, 2011, the liabilities of our discontinued operations exclude $45.7 million of intercompany payables due to its parent or other affiliates.

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SEGMENTS

6 Months Ended

Jun. 30, 2012

SEGMENTS [Abstract]

SEGMENTS

N.           SEGMENTS

Segment Descriptions - Our operations are divided into three reportable business segments as follows:

·   our ONEOK Partners segment reflects the consolidated operations of ONEOK Partners.  We own a 43.4-percent ownership interest and control ONEOK Partners through our ownership of its general partner interest.  ONEOK Partners gathers, processes, treats, transports, stores and sells natural gas and gathers, treats, fractionates, stores, distributes and markets NGLs.  We and ONEOK Partners maintain significant financial and corporate governance separations.  We seek to receive increasing cash distributions as a result of our investment in ONEOK Partners, and our investment decisions are made based on the anticipated returns from ONEOK Partners in total, not specific to any of its businesses individually;

·   our Natural Gas Distribution segment is comprised of our regulated public utilities that deliver natural gas to residential, commercial and industrial customers, and transport natural gas; and

·   our Energy Services segment markets natural gas to wholesale customers.

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

Accounting Policies - The accounting policies of the segments are the same as those described in Note A of the Notes to Consolidated Financial Statements in our Annual Report.  Intersegment sales are recorded on the same basis as sales to unaffiliated customers and are discussed in further detail in Note L.  Net margin is comprised of total revenues less cost of sales and fuel.  Cost of sales and fuel includes commodity purchases, fuel, and storage and transportation costs.

Customers - For the three and six months ended June 30, 2012, and the six months ended June 30, 2011, we had no single external customer from which we received 10 percent or more of our consolidated gross revenues.  For the three months ended June 30, 2011, our ONEOK Partners segment had one single customer from which it received 10 percent of our consolidated gross revenues.

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

Three Months Ended June 30, 2012	ONEOK Partners (a)		Natural Gas Distribution		Energy Services			Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	2,043,756	$	221,181	$	263,897		$	426		$	2,529,260
Intersegment revenues		81,050		2		5,028			(86,080	)		-
Total revenues	$	2,124,806	$	221,183	$	268,925		$	(85,654	)	$	2,529,260
Net margin	$	401,462	$	157,488	$	(10,412	)	$	424			548,962
Operating costs		123,364		103,774		4,626			(501	)		231,263
Depreciation and amortization		51,014		31,999		77			1,496			84,586
Gain on sale of assets		966		-		-			-			966
Operating income	$	228,050	$	21,715	$	(15,115	)	$	(571	)	$	234,079
Equity earnings from investments	$	29,169	$	-	$	-		$	-		$	29,169
Capital expenditures	$	355,443	$	72,917	$	-		$	3,900		$	432,260
(a) - Our ONEOK Partners segment has regulated and nonregulated operations. Our ONEOK Partners segment’s regulated operations had revenues of $160.2 million, net margin of $100.6 million and operating income of $54.1 million.

Three Months Ended June 30, 2011	ONEOK Partners (a)			Natural Gas Distribution		Energy Services			Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	2,685,520		$	253,917	$	504,756		$	605		$	3,444,798
Intersegment revenues		98,699			3,065		111,273			(213,037	)		-
Total revenues	$	2,784,219		$	256,982	$	616,029		$	(212,432	)	$	3,444,798
Net margin	$	359,540		$	159,141	$	(433	)	$	585		$	518,833
Operating costs		113,581			104,516		5,298			214			223,609
Depreciation and amortization		43,714			34,436		111			532			78,793
Loss on sale of assets		(212	)		-		-			-			(212	)
Operating income	$	202,033		$	20,189	$	(5,842	)	$	(161	)	$	216,219
Equity earnings from investments	$	29,544		$	-	$	-		$	-		$	29,544
Capital expenditures	$	265,333		$	61,899	$	3		$	1,858		$	329,093
(a) - Our ONEOK Partners segment has regulated and nonregulated operations. Our ONEOK Partners segment’s regulated operations had revenues of $153.0 million, net margin of $113.2 million and operating income of $53.5 million.

Six Months Ended June 30, 2012	ONEOK Partners (a)		Natural Gas Distribution		Energy Services			Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	4,562,139	$	738,104	$	642,595		$	1,022		$	5,943,860
Intersegment revenues		156,755		843		87,138			(244,736	)		-
Total revenues	$	4,718,894	$	738,947	$	729,733		$	(243,714	)	$	5,943,860
Net margin	$	822,552	$	394,836	$	(25,858	)	$	1,019		$	1,192,549
Operating costs		239,234		208,760		9,465			(2,138	)		455,321
Depreciation and amortization		100,270		65,519		206			2,000			167,995
Goodwill impairment		-		-		10,255			-			10,255
Gain on sale of assets		1,023		-		-			-			1,023
Operating income	$	484,071	$	120,557	$	(45,784	)	$	1,157		$	560,001
Equity earnings from investments	$	63,789	$	-	$	-		$	-		$	63,789
Investments in unconsolidated    affiliates	$	1,210,268	$	-	$	-		$	-		$	1,210,268
Total assets	$	9,376,537	$	3,153,679	$	549,623		$	737,352		$	13,817,191
Noncontrolling interests in    consolidated subsidiaries	$	5,028	$	-	$	-		$	2,111,420		$	2,116,448
Capital expenditures	$	636,236	$	131,365	$	-		$	13,096		$	780,697
(a) - Our ONEOK Partners segment has regulated and nonregulated operations. Our ONEOK Partners segment’s regulated operations had revenues of $331.4 million, net margin of $223.5 million and operating income of $118.7 million.

Six Months Ended June 30, 2011	ONEOK Partners (a)			Natural Gas Distribution		Energy Services		Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	5,088,337		$	933,324	$	1,182,556	$	1,181		$	7,205,398
Intersegment revenues		195,492			7,840		325,212		(528,544	)		-
Total revenues	$	5,283,829		$	941,164	$	1,507,768	$	(527,363	)	$	7,205,398
Net margin	$	689,094		$	402,875	$	55,516	$	1,225		$	1,148,710
Operating costs		222,324			209,213		13,302		451			445,290
Depreciation and amortization		86,444			70,383		259		1,064			158,150
Loss on sale of assets		(722	)		-		-		-			(722	)
Operating income	$	379,604		$	123,279	$	41,955	$	(290	)	$	544,548
Equity earnings from investments	$	61,636		$	-	$	-	$	-		$	61,636
Investments in unconsolidated    affiliates	$	1,177,219		$	-	$	-	$	-		$	1,177,219
Total assets	$	8,642,136		$	3,134,134	$	559,976	$	700,087		$	13,036,333
Noncontrolling interests in    consolidated subsidiaries	$	5,185		$	-	$	-	$	1,475,430		$	1,480,615
Capital expenditures	$	410,159		$	109,049	$	3	$	4,561		$	523,772
(a) - Our ONEOK Partners segment has regulated and nonregulated operations. Our ONEOK Partners segment’s regulated operations had revenues of $308.5 million, net margin of $229.1 million and operating income of $113.1 million.

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EMPLOYEE BENEFIT PLANS

6 Months Ended

Jun. 30, 2012

EMPLOYEE BENEFIT PLANS [Abstract]

EMPLOYEE BENEFIT PLANS

J.           EMPLOYEE BENEFIT PLANS

The following table sets forth the components of net periodic benefit cost for our pension and postretirement benefit plans for the periods indicated:

	Pension Benefits						Pension Benefits
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2012			2011			2012			2011
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	5,325		$	5,003		$	10,650		$	10,006
Interest cost		14,809			14,689			29,618			29,378
Expected return on assets		(20,689	)		(18,875	)		(41,378	)		(37,750	)
Amortization of unrecognized prior service cost		242			255			484			509
Amortization of net loss		12,111			8,927			24,222			17,855
Net periodic benefit cost	$	11,798		$	9,999		$	23,596		$	19,998

	Postretirement Benefits						Postretirement Benefits
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2012			2011			2012			2011
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	1,240		$	1,257		$	2,477		$	2,515
Interest cost		3,473			3,958			6,946			7,916
Expected return on assets		(2,671	)		(2,568	)		(5,342	)		(5,136	)
Amortization of unrecognized net asset at adoption		718			797			1,436			1,594
Amortization of unrecognized prior service cost		(2,063	)		(501	)		(4,126	)		(1,002	)
Amortization of net loss		3,296			2,031			6,592			4,062
Net periodic benefit cost	$	3,993		$	4,974		$	7,983		$	9,949

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LONG-TERM DEBT

6 Months Ended

Jun. 30, 2012

LONG-TERM DEBT [Abstract]

LONG-TERM DEBT

F.           LONG-TERM DEBT

In January 2012, we completed an underwritten public offering of $700 million, 4.25-percent senior notes due 2022.  The net proceeds from the offering, after deducting underwriting discounts and offering expenses, of approximately $694.3 million were used to repay amounts outstanding under our $1.2 billion commercial paper program and for general corporate purposes.

The indenture governing ONEOK’s senior notes due 2022 includes an event of default upon the acceleration of other indebtedness of $100 million or more.  Such events of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of the outstanding senior notes due 2022 to declare those senior notes immediately due and payable in full.

ONEOK may redeem its senior notes due 2022 at a redemption price equal to the principal amount, plus accrued and unpaid interest, starting three months before the maturity date.  Prior to this date, ONEOK may redeem the senior notes due 2022, in whole or in part, at any time for a redemption price equal to the principal amount plus accrued and unpaid interest and a make-whole premium.  The redemption price will never be less than 100 percent of the principal amount of the respective note plus accrued and unpaid interest to the redemption date.  ONEOK’s senior notes due 2022 are senior unsecured obligations, ranking equally in right of payment with all of ONEOK’s existing and future unsecured senior indebtedness.

ONEOK Partners repaid its $350 million, 5.9-percent senior notes at maturity in April 2012 with a portion of the proceeds from its March 2012 equity issuance.

For the three-month periods ended June 30, 2012 and 2011, interest expense was net of capitalized interest of $9.7 million and $4.2 million, respectively.  For the six-month periods ended June 30, 2012 and 2011, interest expense was net of capitalized interest of $18.7 million and $7.4 million, respectively.

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

6 Months Ended

Jun. 30, 2012

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES [Abstract]

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

D.           RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

Our Energy Services and ONEOK Partners segments are exposed to various risks that we manage by periodically entering into derivative instruments.  These risks include the following:

·   Commodity price risk - We are exposed to the risk of loss in cash flows and future earnings arising from adverse changes in the price of natural gas, NGLs and crude oil.  We use commodity derivative instruments such as futures, physical forward contracts, swaps and options to reduce the commodity price risk associated with a portion of the

forecasted purchases and sales of commodities and natural gas and natural gas liquids in storage.  Commodity price volatility may have a significant impact on the fair value of our derivative instruments as of a given date;

·   Basis risk - We are exposed to the risk of loss in cash flows and future earnings arising from adverse changes in the price differentials between pipeline receipt and delivery locations.  Our firm transportation capacity allows us to purchase natural gas at a pipeline receipt point and sell natural gas at a pipeline delivery point.  As market conditions permit, our Energy Services segment periodically enters into basis swaps between the transportation receipt and delivery points in order to protect the fair value of these location price differentials related to our firm commitments;

·   Currency exchange rate risk - As a result of our Energy Services segment’s activities in Canada, we are exposed to the risk of loss in cash flows and future earnings from adverse changes in currency exchange rates on our commodity purchases and sales, primarily related to our firm transportation and storage contracts that are transacted in a currency other than our functional currency, the United States dollar.  To reduce our exposure to exchange-rate fluctuations, we use physical forward transactions, which result in an actual two-way flow of currency on the settlement date in which we exchange United States dollars for Canadian dollars with another party; and

·   Interest-rate risk -We are also subject to fluctuations in interest rates.  We manage interest-rate risk through the use of fixed-rate debt, floating-rate debt and interest-rate swaps.

The following derivative instruments are used to manage our exposure to these risks:

·   Futures contracts - Standardized exchange-traded contracts to purchase or sell natural gas and crude oil at a specified price, requiring delivery on or settlement through the sale or purchase of an offsetting contract by a specified future date under the provisions of exchange regulations;

·   Forward contracts - Commitments to purchase or sell natural gas, crude oil or NGLs for physical delivery at some specified time in the future.  We also may use currency forward contracts to manage our currency exchange-rate risk.  Forward contracts are different from futures in that forwards are customized and nonexchange traded;

·   Swaps - Financial trades involving the exchange of payments based on two different pricing structures for a commodity or other instrument.  In a typical commodity swap, parties exchange payments based on changes in the price of a commodity or a market index, while fixing the price they effectively pay or receive for the physical commodity.  As a result, one party assumes the risks and benefits of movements in market prices, while the other party assumes the risks and benefits of a fixed price for the commodity.  Interest-rate swaps are agreements to exchange interest payments at some future point based on specified notional amounts; and

·   Options - Contractual agreements that give the holder the right, but not the obligation, to buy or sell a fixed quantity of a commodity, at a fixed price, within a specified period of time.  Options may either be standardized and exchange traded or customized and nonexchange traded.

Our objectives for entering into such contracts include but are not limited to:

·   reducing the variability of cash flows by locking in the price for all or a portion of anticipated index-based physical purchases and sales, transportation fuel requirements, asset management transactions and customer-related business activities;

·   locking in a price differential to protect the fair value between transportation receipt and delivery points and to protect the fair value of natural gas or NGLs that are purchased in one month and sold in a later month;

·   reducing our exposure to fluctuations in interest and foreign currency exchange rates; and

·   reducing variability in cash flows from changes in interest rates associated with forecasted debt issuances.

Our Energy Services segment also enters into derivative contracts for financial trading purposes primarily to capitalize on opportunities created by market volatility, weather-related events, supply-demand imbalances and market liquidity inefficiencies, which allow us to capture additional margin.  Financial trading activities are executed generally using financially settled derivatives and are normally short term in nature.

With respect to the net open positions that exist within our marketing and financial trading operations, fluctuating commodity prices can impact our financial position and results of operations.  The net open positions are actively managed, and the impact of the changing prices on our financial condition at a point in time is not necessarily indicative of the impact of price movements throughout the year.

Our Natural Gas Distribution segment also uses derivative instruments to hedge the cost of a portion of anticipated natural gas purchases during the winter heating months to protect our customers from upward volatility in the market price of natural gas.  The use of these derivative instruments and the associated recovery of these costs have been approved by the OCC, KCC and regulatory authorities in certain Texas jurisdictions.

ONEOK and ONEOK Partners each entered into 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.  ONEOK had interest-rate swaps with notional values totaling $500 million at December 31, 2011.  In January 2012, ONEOK entered into additional interest-rate swaps with notional amounts totaling $200 million.  Upon issuance in January 2012 of our $700 million, 4.25-percent senior notes due 2022, ONEOK settled all $700 million of its interest-rate swaps and realized a loss of $44.1 million in accumulated other comprehensive income that will be amortized to interest expense over the term of the hedged debt.  At June 30, 2012, and December 31, 2011, ONEOK Partners had forward-starting interest-rate swaps with notional amounts totaling $1 billion and $750 million, respectively.  In July 2012, ONEOK Partners entered into additional forward-starting interest-rate swaps with settlement dates greater than 12 months that were also designated as cash flow hedges with notional amounts totaling $400 million.

Accounting Treatment -We 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.

If certain conditions are met, we may elect to designate a derivative instrument as a hedge of exposure to changes in fair values, cash flows or foreign currency.  Certain nontrading derivative transactions, which are economic hedges of our accrual transactions such as our storage and transportation contracts, do not qualify for hedge accounting treatment.

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

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

Gains or losses associated with the fair value of derivative instruments entered into by our Natural Gas Distribution segment are included in, and recoverable through, the monthly purchased-gas cost mechanism.

We 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 specifically identify the asset, liability, firm commitment or forecasted transaction that has been designated as the hedged item.  We assess the effectiveness of hedging relationships quarterly by performing an effectiveness analysis on our cash flow and fair value hedging relationships to determine whether the hedge relationships are highly effective on a retrospective and prospective basis.  We also document our normal purchases and normal sales transactions that we expect to result in physical delivery and that we elect to exempt from derivative accounting treatment.

The presentation of settled derivative instruments on either a gross or net basis in our Consolidated Statements of Income is dependent on the relevant facts and circumstances of our different types of activities rather than based solely on the terms of the individual contracts.  All financially settled derivative instruments, as well as derivative instruments considered held for trading purposes that result in physical delivery, are reported on a net basis in revenues in our Consolidated Statements of Income.  The realized revenues and purchase costs of derivative instruments that are not considered held for trading purposes and nonderivative contracts are reported on a gross basis.  Derivatives that qualify as normal purchases or normal sales that are expected to result in physical delivery are also reported on a gross basis.

Revenues in our Consolidated Statements of Income include financial trading margins, as well as certain physical natural gas transactions with our trading counterparties.  Revenues and cost of sales and fuel from such physical transactions are reported on a net basis.

Cash flows from futures, forwards, options 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 - The following table sets forth the fair values of our derivative instruments for our continuing and discontinued operations for the periods indicated:

	June 30, 2012						December 31, 2011
	Fair Values of Derivatives (a)						Fair Values of Derivatives (a)
	Assets			(Liabilities)			Assets			(Liabilities)
	(Thousands of dollars)
Derivatives designated as hedging instruments
Commodity contracts
Financial contracts	$	136,655	(b)	$	(48,014	)(b)	$	184,184	(c)	$	(73,346	)(c)
Physical contracts		165			(71	)		62			(344	)
Interest-rate contracts		-			(116,166	)		-			(128,666	)
Total derivatives designated as hedging instruments		136,820			(164,251	)		184,246			(202,356	)
Derivatives not designated as hedging instruments
Commodity contracts
Nontrading instruments
Financial contracts		190,780			(197,993	)		295,948			(323,170	)
Physical contracts		15,087			(618	)		38,733			(1,665	)
Trading instruments
Financial contracts		76,807			(75,122	)		111,920			(110,050	)
Total derivatives not designated as hedging instruments		282,674			(273,733	)		446,601			(434,885	)
Total derivatives	$	419,494		$	(437,984	)	$	630,847		$	(637,241	)
(a) - Included on a net basis in energy marketing and risk management assets and liabilities, other assets and other deferred credits on our Consolidated Balance Sheets.
(b) - Includes $7.5 million of derivative assets associated with cash flow purchase hedges tied to injections of inventory into storage that were adjusted to reflect the lower of cost or market value in a prior period. The deferred gains associated with these assets have been reclassified from accumulated other comprehensive loss.
(c) - Includes $88.9 million of derivative assets associated with cash flow hedges of inventory that were adjusted to reflect the lower of cost or market value. The deferred gains associated with these assets have been reclassified from accumulated other comprehensive loss.

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

		June 30, 2012					December 31, 2011
	Contract Type	Purchased/ Payor		Sold/ Receiver			Purchased/ Payor		Sold/ Receiver
Derivatives designated as hedging instruments:
Cash flow hedges
Fixed price
- Natural gas (Bcf)	Exchange futures		8.1		(16.7	)		21.2		(23.4	)
	Swaps		8.5		(90.3	)		19.5		(111.9	)
- Crude oil and NGLs (MMBbl)	Swaps		-		(2.6	)		-		(2.9	)
Basis
- Natural gas (Bcf)	Forwards and swaps		13.7		(45.5	)		3.2		(82.8	)
Interest-rate contracts (Millions of dollars)	Forward-starting swaps	$	1,000.0		-		$	1,250.0		-
Fair value hedges
Basis
- Natural gas (Bcf)	Forwards and swaps		91.0		(91.0	)		76.5		(77.0	)
Derivatives not designated as hedging instruments:
Fixed price
- Natural gas (Bcf)	Exchange futures		56.1		(44.7	)		76.9		(59.6	)
	Forwards and swaps		136.0		(149.2	)		235.8		(253.4	)
	Options		205.0		(205.3	)		33.6		(14.3	)
Basis
- Natural gas (Bcf)	Forwards and swaps		159.3		(164.6	)		216.9		(219.3	)
Index
- Natural gas (Bcf)	Forwards and swaps		34.5		(15.3	)		29.3		(22.1	)

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

Cash Flow Hedges -Our Energy Services and ONEOK Partners segments use derivative instruments to hedge the cash flows associated with anticipated purchases and sales of natural gas, NGLs and condensate and cost of fuel used in the transportation of natural gas.  Accumulated other comprehensive income (loss) at June 30, 2012, includes gains of approximately $15.2 million, net of tax, related to these hedges that will be recognized within the next 18 months as the forecasted transactions affect earnings.  If prices remain at current levels, we will recognize $8.9 million in net gains over the next 12 months, and we will recognize net gains of $6.3 million thereafter.  The remaining amounts deferred in accumulated other comprehensive income (loss) are primarily attributable to our interest-rate swaps, which will be amortized to interest expense over the life of long-term, fixed-rate debt upon issuance of the debt.

For the six months ended June 30, 2012, net margin in our Consolidated Statement of Income includes losses of $29.9 million related to certain financial contracts that were used to hedge forecasted purchases of natural gas.  As a result of the continued decline in natural gas prices, the combination of the cost basis of the forecasted purchases of inventory and the financial contracts exceed the amount expected to be recovered through sales of that inventory after considering related sales hedges, which requires reclassification of the loss from accumulated other comprehensive loss to current period earnings.

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

	Three Months Ended					Six Months Ended
Derivatives in Cash Flow	June 30,					June 30,
Hedging Relationships	2012			2011		2012			2011
	(Thousands of dollars)
Commodity contracts	$	35,349		$	21,847	$	80,914		$	3,545
Interest-rate contracts		(52,756	)		-		(31,746	)		-
Total gain (loss) recognized in other comprehensive income (loss) on    derivatives (effective portion)	$	(17,407	)	$	21,847	$	49,168		$	3,545

The following tables set forth the effect of cash flow hedges on our Consolidated Statements of Income for the periods indicated:

	Location of Gain (Loss) Reclassified from	Three Months Ended
Derivatives in Cash Flow	Accumulated Other Comprehensive Income	June 30,
Hedging Relationships	(Loss) into Net Income (Effective Portion)	2012			2011
		(Thousands of dollars)
Commodity contracts	Revenues	$	33,660		$	(3,510	)
Commodity contracts	Cost of sales and fuel		(1,460	)		(108	)
Interest-rate contracts	Interest expense		(1,195	)		(90	)
Total gain (loss) reclassified from accumulated other comprehensive income (loss)    into net income on derivatives (effective portion)		$	31,005		$	(3,708	)

	Location of Gain (Loss) Reclassified from	Six Months Ended
Derivatives in Cash Flow	Accumulated Other Comprehensive Income	June 30,
Hedging Relationships	(Loss) into Net Income (Effective Portion)	2012			2011
		(Thousands of dollars)
Commodity contracts	Revenues	$	96,030		$	29,877
Commodity contracts	Cost of sales and fuel		(63,437	)		(936	)
Interest-rate contracts	Interest expense		(2,022	)		(298	)
Total gain (loss) reclassified from accumulated other comprehensive income (loss)    into net income on derivatives (effective portion)		$	30,571		$	28,643

Ineffectiveness related to our cash flow hedges was not material for the three months and six months ended June 30, 2012 and 2011.  In the event that it becomes probable that a forecasted transaction will not occur, we will discontinue cash flow hedge treatment, which will affect earnings.  For the three and six months ended June 30, 2012 and 2011, there were no gains or losses due to the discontinuance of cash flow hedge treatment as a result of the underlying transactions being no longer probable.

Other Derivative Instruments - The following table sets forth the effect of our derivative instruments that are not part of a hedging relationship in our Consolidated Statements of Income for our continuing and discontinued operations for the periods indicated:

		Three Months Ended					Six Months Ended
Derivatives Not Designated as		June 30,					June 30,
Hedging Instruments	Location of Gain (Loss)	2012		2011			2012		2011
		(Thousands of dollars)
Commodity contracts - trading	Revenues	$	491	$	(289	)	$	806	$	117
Commodity contracts - nontrading (a)	Cost of sales and fuel		1,361		7,959			4,324		10,507
Total gain recognized in income on derivatives		$	1,852	$	7,670		$	5,130	$	10,624
(a) - Amounts are presented net of deferred losses associated with derivatives entered into by our Natural Gas Distribution segment.

Our Natural Gas Distribution segment held natural gas call options with premiums totaling $6.3 million and $10.0 million at June 30, 2012, and December 31, 2011, respectively.  The premiums are recorded in other current assets as these contracts are included in, and recoverable through, the monthly purchased-gas cost mechanism.  Gains and losses associated with the change in value and expiration of these option contracts are deferred as part of our unrecovered purchase-gas costs and are not material for the three- and six-month periods ended June 30, 2012 and 2011.

Fair Value Hedges - Our Energy Services segment uses basis swaps to hedge the fair value of location price differentials related to certain firm transportation commitments.  Cost of sales and fuel in our Consolidated Statements of Income includes gains of $1.6 million and $1.1 million for the three and six months ended June 30, 2012, respectively, related to the change in fair value of derivatives designated as fair value hedges.  Revenues include losses of $2.2 million and $0.3 million for the three and six months ended June 30, 2012, respectively, to recognize the change in fair value of the related hedged firm commitments.  The ineffectiveness related to these hedges was not material for the three and six months ended June 30, 2012.

Cost of sales and fuel in our Consolidated Statements of Income includes gains of $4.2 million and $9.6 million for the three and six months ended June 30, 2011, respectively, related to the change in fair value of derivatives designated as fair value hedges.  Revenues include losses of $4.4 million and $9.4 million for the three and six months ended June 30, 2011, respectively, to recognize the change in fair value of the related hedged firm commitments.  The ineffectiveness related to these hedges was immaterial for the three and six months ended June 30, 2011.

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

Some of our derivative instruments contain provisions that require us to maintain an investment-grade credit rating from S&P and/or Moody’s.  If our credit ratings on senior unsecured long-term debt were to decline below investment grade, we would be in violation of these provisions, and the counterparties to the derivative instruments could request collateralization on derivative instruments in net liability positions.  The aggregate fair value of all financial derivative instruments with contingent features related to credit risk that were in a net liability position as of June 30, 2012, was $3.1 million.  If the contingent features underlying these agreements were triggered on June 30, 2012, we would have been required to post an additional $3.1 million of collateral to our counterparties.

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

The following table sets forth the net credit exposure from our derivative assets for the period indicated:

	June 30, 2012
	Investment		Noninvestment		Not
	Grade		Grade		Rated		Total
Counterparty sector	(Thousands of dollars)
Gas and electric utilities	$	17,911	$	-	$	108	$	18,019
Oil and gas		7,932		-		465		8,397
Financial		72,674		-		2		72,676
Other		-		6		395		401
Total	$	98,517	$	6	$	970	$	99,493

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CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE

6 Months Ended

Jun. 30, 2012

CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE [Abstract]

CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE

E.           CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE

ONEOK 2011 Credit Agreement -The ONEOK 2011 Credit Agreement, which is scheduled to expire in April 2016, contains certain financial, operational and legal covenants.  Among other things, these covenants include maintaining ONEOK’s stand-alone debt-to-capital ratio of no more than 67.5 percent at the end of any calendar quarter, limitations on the ratio of indebtedness secured by liens and indebtedness of subsidiaries to consolidated net tangible assets, a requirement that ONEOK maintains the power to control the management and policies of ONEOK Partners, and a limit on new investments in master limited partnerships.  The ONEOK 2011 Credit Agreement also contains customary affirmative and negative covenants, including covenants relating to liens, investments, fundamental changes in the nature of ONEOK’s businesses, transactions with affiliates, the use of proceeds and a covenant that limits ONEOK’s ability to restrict its subsidiaries’ ability to pay dividends. The debt covenant calculations in the ONEOK 2011 Credit Agreement exclude the debt of ONEOK Partners.  Upon breach of certain covenants by ONEOK, amounts outstanding under the ONEOK 2011 Credit Agreement may become due and payable immediately.  At June 30, 2012, ONEOK’s stand-alone debt-to-capital ratio, as defined by the ONEOK 2011 Credit Agreement, was 50.5 percent, and ONEOK was in compliance with all covenants under the ONEOK 2011 Credit Agreement.

Under the terms of the ONEOK 2011 Credit Agreement, ONEOK may request an increase in the size of the facility to an aggregate of $1.7 billion from $1.2 billion by either commitments from new lenders or increased commitments from existing lenders.  The ONEOK 2011 Credit Agreement is available to repay our commercial paper notes, if necessary.  Amounts outstanding under the commercial paper program reduce the borrowing capacity under the ONEOK 2011 Credit Agreement.

At June 30, 2012, ONEOK had $571.9 million of commercial paper outstanding, $1.7 million in letters of credit issued under the ONEOK 2011 Credit Agreement and approximately $22.8 million of cash and cash equivalents.  ONEOK had approximately $626.4 million of credit available at June 30, 2012, under the ONEOK 2011 Credit Agreement.

ONEOK Partners 2011 Credit Agreement - The ONEOK Partners 2011 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 2011 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 of the acquisition and the two following quarters.  Upon breach of certain covenants by ONEOK Partners in the ONEOK Partners 2011 Credit Agreement, amounts outstanding under the ONEOK Partners 2011 Credit Agreement, if any, may become due and payable immediately.  At June 30, 2012, ONEOK Partners’ ratio of indebtedness to adjusted EBITDA was 2.3 to 1, and ONEOK Partners was in compliance with all covenants under the ONEOK Partners 2011 Credit Agreement.

The ONEOK Partners 2011 Credit Agreement includes a $100-million sublimit for the issuance of standby letters of credit and also features an option to request an increase in the size of the facility to an aggregate of $1.7 billion from $1.2 billion by either commitments from new lenders or increased commitments from existing lenders.  The ONEOK Partners 2011 Credit Agreement is available to repay ONEOK Partners’ commercial paper notes, if necessary.  Amounts outstanding under the commercial paper program reduce the borrowing capacity under the ONEOK Partners 2011 Credit Agreement.  At June 30, 2012, ONEOK Partners had $24 million of commercial paper outstanding, no letters of credit issued and no borrowings under the ONEOK Partners 2011 Credit Agreement.

Effective August 1, 2012, ONEOK Partners extended the maturity date of its ONEOK Partners 2011 Credit Agreement from August 1, 2016, to August 1, 2017, pursuant to an extension agreement between ONEOK Partners and its lenders.

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.

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EQUITY

6 Months Ended

Jun. 30, 2012

EQUITY [Abstract]

EQUITY

G.           EQUITY

The following tables set 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, 2012										June 30, 2011
	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	$	2,256,152		$	2,123,303			$	4,379,455		$	2,499,084		$	1,457,934			$	3,957,018
Net income		60,993			88,212				149,205			55,142			79,624				134,766
Other comprehensive income (loss)		(26,795	)		(14,276	)			(41,071	)		3,871			11,572				15,443
Repurchase of common stock		(150,000	)		-				(150,000	)		(300,057	)		-				(300,057	)
Common stock issued		3,991			-				3,991			14,754			-				14,754
Common stock dividends		(63,397	)		-				(63,397	)		(55,705	)		-				(55,705	)
Issuance of common units of ONEOK Partners		-			(55	)			(55	)		-			-				-
Distributions to noncontrolling interests		-			(80,736	)			(80,736	)		-			(68,515	)			(68,515	)
Other		8,596			-				8,596			-			-				-
Ending balance	$	2,089,540		$	2,116,448			$	4,205,988		$	2,217,089		$	1,480,615			$	3,697,704

	Six Months Ended										Six Months Ended
	June 30, 2012										June 30, 2011
	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	$	2,238,573		$	1,561,159			$	3,799,732		$	2,448,623		$	1,472,218			$	3,920,841
Net income		183,858			198,809				382,667			185,272			148,840				334,112
Other comprehensive income (loss)		481			(712	)			(231	)		(22,464	)		(3,887	)			(26,351	)
Repurchase of common stock		(150,000	)		-				(150,000	)		(300,105	)		-				(300,105	)
Common stock issued		6,552			-				6,552			17,119			-				17,119
Common stock dividends		(126,772	)		-				(126,772	)		(111,356	)		-				(111,356	)
Issuance of common units of ONEOK Partners		(51,100	)		510,780				459,680			-			-				-
Distributions to noncontrolling interests		-			(153,588	)			(153,588	)		-			(136,556	)			(136,556	)
Other		(12,052	)		-				(12,052	)		-			-				-
Ending balance	$	2,089,540		$	2,116,448			$	4,205,988		$	2,217,089		$	1,480,615			$	3,697,704

Dividends - Dividends paid on our common stock to shareholders of record at the close of business on January 31, 2012, and April 30, 2012, each were $0.305 per share.  A dividend of $0.33 per share was declared for shareholders of record on August 6, 2012, payable August 15, 2012. Stock Repurchase Program - In June 2012, we entered into an accelerated share repurchase agreement (the ASR Agreement) with Goldman, Sachs & Co. (Goldman), pursuant to which we paid $150 million to Goldman and received from Goldman approximately 2.9 million shares of our common stock, representing approximately 80 percent of the estimated total number of shares to be repurchased.  The ASR Agreement is scheduled to end in September 2012, although the termination date may be accelerated.  We expect to receive the balance of the shares at the conclusion of the ASR Agreement.  The specific number of shares that we ultimately will repurchase will be based on the volume-weighted-average price per share of our common stock during the repurchase period, subject to other adjustments pursuant to the terms and conditions of the ASR Agreement.  At settlement, under certain circumstances, Goldman may be required to deliver additional shares of our common stock to us, or, under certain circumstances, we may be required to deliver shares of our common stock or we may elect to make a cash payment to Goldman.  We accounted for the repurchase as two separate transactions:  (i) as shares of common stock acquired in a treasury stock transaction recorded on the acquisition date; and (ii) as a forward contract indexed to ONEOK common stock that is classified as equity.

The ASR Agreement is part of our three-year stock repurchase program that was authorized by our Board of Directors in October 2010 to buy up to $750 million of our common stock, subject to the limitation that purchases will not exceed $300 million in any one calendar year.  Following this transaction and our repurchase of $300 million in 2011, an additional $300 million may yet be purchased pursuant to our three-year repurchase program, of which a maximum of $150 million of additional shares of our common stock may be purchased in 2012.

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

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ONEOK PARTNERS (Tables)

6 Months Ended

Jun. 30, 2012

ONEOK PARTNERS [Abstract]

Ownership interest in ONEOK Partners

Ownership Interest in ONEOK Partners - Our ownership interest in ONEOK Partners is shown in the table below as of June 30, 2012:

General partner interest	2.0%
Limited partner interest (a)	41.4%
Total ownership interest	43.4%
(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,
	2012		2011		2012		2011
	(Thousands, except per unit amounts)
Distribution per unit	$	0.635	$	0.575	$	1.245	$	1.145
General partner distributions	$	3,759	$	2,996	$	7,040	$	5,952
Incentive distributions		44,610		29,624		81,082		58,269
Distributions to general partner		48,369		32,620		88,122		64,221
Limited partner distributions to ONEOK		58,921		48,753		110,642		97,083
Limited partner distributions to noncontrolling interest		80,662		68,441		153,271		136,286
Total distributions paid	$	187,952	$	149,814	$	352,035	$	297,590

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,
	2012		2011		2012		2011
	(Thousands, except per unit amounts)
Distribution per unit	$	0.660	$	0.585	$	1.295	$	1.160
General partner distributions	$	3,979	$	3,078	$	7,738	$	6,074
Incentive distributions		49,886		31,580		94,496		61,204
Distributions to general partner		53,865		34,658		102,234		67,278
Limited partner distributions to ONEOK		61,240		49,601		120,161		98,354
Limited partner distributions to noncontrolling interest		83,838		69,631		164,500		138,072
Total distributions declared	$	198,943	$	153,890	$	386,895	$	303,704

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,
	2012		2011		2012		2011
	(Thousands of dollars)
Revenues	$	81,050	$	98,699	$	156,755	$	195,492
Expenses
Cost of sales and fuel	$	5,769	$	12,440	$	15,044	$	23,171
Administrative and general expenses		62,636		57,214		118,997		113,509
Total expenses	$	68,405	$	69,654	$	134,041	$	136,680

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COMMITMENTS AND CONTINGENCIES (Details)	Jun. 30, 2012
COMMITMENTS AND CONTINGENCIES [Abstract]
Number of former manufactured gas sites in Kansas where we own or retain legal responsibility for environmental conditions	12
Number of sites where soil remediation has begun	11
Number of sites where regulatory closure has been achieved	3
Number of sites soil remediation is completed or near completion	8
Number of years of consideration for EPA lowering threshold levels for greenhouse gas emissions	5
Number of years over which capital expenditures are expected to be required to meet administrative standards	2
Minimum percentage yield of high consequence pipeline areas	30.00%
Number of days after publication in Federal Register the Dodd-Frank Act definitional rules become effective	60

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ONEOK PARTNERS

6 Months Ended

Jun. 30, 2012

ONEOK PARTNERS [Abstract]

ONEOK PARTNERS

L.           ONEOK PARTNERS

Equity Issuance -In March 2012, ONEOK Partners completed an underwritten public offering of 8,000,000 common units at a public offering price of $59.27 per common unit, generating net proceeds of approximately $460 million.  ONEOK Partners also sold 8,000,000 common units to us in a private placement, generating net proceeds of approximately $460 million.  In conjunction with the issuances, we contributed $19.1 million in order to maintain our 2-percent general partner interest in ONEOK Partners.  ONEOK Partners used the net proceeds from the offering to repay approximately $295 million under its $1.2 billion commercial paper program, to repay amounts on the maturity of its $350 million, 5.9-percent senior notes due April 2012 and for other general partnership purposes, including capital expenditures.  As a result of these transactions, our aggregate ownership interest in ONEOK Partners increased to 43.4 percent from 42.8 percent.

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.  As a result of ONEOK Partners’ issuance of common units, we recognized a decrease in paid-in capital of approximately $51.1 million in the first quarter of 2012.

Ownership Interest in ONEOK Partners - Our ownership interest in ONEOK Partners is shown in the table below as of June 30, 2012:

General partner interest	2.0%
Limited partner interest (a)	41.4%
Total ownership interest	43.4%
(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 our common and Class B units and our 2-percent general partner interest, which includes our incentive distribution rights.  Under ONEOK Partners’ partnership agreement, as amended, 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 ONEOK Partners’ partnership agreement, as amended.  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 ONEOK Partners’ partnership agreement, as amended, 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.

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2012		2011		2012		2011
	(Thousands, except per unit amounts)
Distribution per unit	$	0.635	$	0.575	$	1.245	$	1.145
General partner distributions	$	3,759	$	2,996	$	7,040	$	5,952
Incentive distributions		44,610		29,624		81,082		58,269
Distributions to general partner		48,369		32,620		88,122		64,221
Limited partner distributions to ONEOK		58,921		48,753		110,642		97,083
Limited partner distributions to noncontrolling interest		80,662		68,441		153,271		136,286
Total distributions paid	$	187,952	$	149,814	$	352,035	$	297,590

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,
	2012		2011		2012		2011
	(Thousands, except per unit amounts)
Distribution per unit	$	0.660	$	0.585	$	1.295	$	1.160
General partner distributions	$	3,979	$	3,078	$	7,738	$	6,074
Incentive distributions		49,886		31,580		94,496		61,204
Distributions to general partner		53,865		34,658		102,234		67,278
Limited partner distributions to ONEOK		61,240		49,601		120,161		98,354
Limited partner distributions to noncontrolling interest		83,838		69,631		164,500		138,072
Total distributions declared	$	198,943	$	153,890	$	386,895	$	303,704

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 ONEOK Partners partnership agreement.  See Note N for more information on ONEOK Partners’ results.

Affiliate Transactions - We have certain transactions with ONEOK Partners and its subsidiaries, which comprise our ONEOK Partners segment.

ONEOK Partners sells natural gas from its natural gas gathering and processing operations to our Energy Services segment.  In addition, a portion of ONEOK Partners’ revenues from its natural gas pipelines business is from our Energy Services and Natural Gas Distribution segments, which contract with ONEOK Partners for natural gas transportation and storage services.  ONEOK Partners also purchases natural gas from our Energy Services segment for its natural gas liquids and its natural gas gathering and processing operations.

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.  For example, a service that applies equally to all employees is allocated based upon the number of employees in each affiliate.  However, an expense benefiting the consolidated company but having no direct basis for allocation is allocated by the modified Distrigas method, a method using a combination of ratios that include gross plant and investment, operating income and payroll expense.  It is not practicable to determine what these general overhead costs would be 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,
	2012		2011		2012		2011
	(Thousands of dollars)
Revenues	$	81,050	$	98,699	$	156,755	$	195,492
Expenses
Cost of sales and fuel	$	5,769	$	12,440	$	15,044	$	23,171
Administrative and general expenses		62,636		57,214		118,997		113,509
Total expenses	$	68,405	$	69,654	$	134,041	$	136,680

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DISCONTINUED OPERATIONS (Tables)

6 Months Ended

Jun. 30, 2012

DISCONTINUED OPERATIONS [Abstract]

Discontinued Operations

The amounts of revenue, costs and income taxes reported in discontinued operations are set forth in the table below for the periods indicated:

	One Month Ended		Three Months Ended				Six Months Ended
	January 31,			June 30,			June 30,
	2012			2011			2011
	(Thousands of dollars)
Revenues	$	27,607		$	69,677		$	175,966
Cost of sales and fuel		25,961			66,862			169,479
Net margin		1,646			2,815			6,487
Operating costs		408			2,084			4,017
Depreciation and amortization		8			33			65
Operating income		1,230			698			2,405
Other income (expense), net		-			(1	)		15
Income taxes		(468	)		(260	)		(922	)
Income from discontinued operations, net	$	762		$	437		$	1,498

The following table discloses the major classes of discontinued assets and liabilities included on our Consolidated Balance Sheet for the period indicated:

		December 31,
		2011
Assets	(Thousands of dollars)
Cash and cash equivalents		$	8,859
Accounts receivable, net			47,967
Gas in storage			2,101
Energy marketing and risk management assets			15,016
Other assets			193
Assets of discontinued operations		$	74,136
Liabilities
Accounts payable		$	11,435
Energy marketing and risk management liabilities			629
Other liabilities			751
Liabilities of discontinued operations		$	12,815

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UNCONSOLIDATED AFFILIATES (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Schedule of Equity Method Investments [Line Items]
Equity earnings from investments	$ 29,169	$ 29,544	$ 63,789	$ 61,636
Income Statement
Operating revenues	119,286	121,002	247,210	244,303
Operating expenses	57,727	51,988	112,295	106,224
Net income	59,812	59,244	125,066	122,409
Distributions paid to ONEOK Partners	43,254	38,541	84,195	71,052
Northern Border Pipeline [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings from investments	16,077	16,395	36,308	37,247
Overland Pass Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings from investments	5,979	5,360	11,296	9,736
Fort Union Gas Gathering, L.L.C. [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings from investments	3,195	3,711	7,403	6,676
Bighorn Gas Gathering L.L.C. [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings from investments	796	1,845	1,961	3,338
Other Unconsolidated Affiliate [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings from investments	$ 3,122	$ 2,233	$ 6,821	$ 4,639

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES Part 1 (Details) (USD $)	6 Months Ended																												1 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Dec. 31, 2011	Jun. 30, 2012 Cash Flow Hedging [Member] Fixed Price [Member] Natural Gas [Member] Swaps [Member] Purchased [Member]	Dec. 31, 2011 Cash Flow Hedging [Member] Fixed Price [Member] Natural Gas [Member] Swaps [Member] Purchased [Member]	Jun. 30, 2012 Cash Flow Hedging [Member] Fixed Price [Member] Natural Gas [Member] Swaps [Member] Sold [Member]	Dec. 31, 2011 Cash Flow Hedging [Member] Fixed Price [Member] Natural Gas [Member] Swaps [Member] Sold [Member]	Jun. 30, 2012 Cash Flow Hedging [Member] Fixed Price [Member] Natural Gas [Member] Exchange Futures [Member] Purchased [Member]	Dec. 31, 2011 Cash Flow Hedging [Member] Fixed Price [Member] Natural Gas [Member] Exchange Futures [Member] Purchased [Member]	Jun. 30, 2012 Cash Flow Hedging [Member] Fixed Price [Member] Natural Gas [Member] Exchange Futures [Member] Sold [Member]	Dec. 31, 2011 Cash Flow Hedging [Member] Fixed Price [Member] Natural Gas [Member] Exchange Futures [Member] Sold [Member]	Jun. 30, 2012 Cash Flow Hedging [Member] Fixed Price [Member] Crude oil and NGLs [Member] Swaps [Member] Purchased [Member]	Dec. 31, 2011 Cash Flow Hedging [Member] Fixed Price [Member] Crude oil and NGLs [Member] Swaps [Member] Purchased [Member]	Jun. 30, 2012 Cash Flow Hedging [Member] Fixed Price [Member] Crude oil and NGLs [Member] Swaps [Member] Sold [Member]	Dec. 31, 2011 Cash Flow Hedging [Member] Fixed Price [Member] Crude oil and NGLs [Member] Swaps [Member] Sold [Member]	Jun. 30, 2012 Cash Flow Hedging [Member] Basis [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Purchased [Member]	Dec. 31, 2011 Cash Flow Hedging [Member] Basis [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Purchased [Member]	Jun. 30, 2012 Cash Flow Hedging [Member] Basis [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Sold [Member]	Dec. 31, 2011 Cash Flow Hedging [Member] Basis [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Sold [Member]	Jun. 30, 2012 Cash Flow Hedging [Member] Interest Rate Contract [Member] Forward Starting Swaps [Member] Purchased [Member]	Dec. 31, 2011 Cash Flow Hedging [Member] Interest Rate Contract [Member] Forward Starting Swaps [Member] Purchased [Member]	Jun. 30, 2012 Cash Flow Hedging [Member] Interest Rate Contract [Member] Forward Starting Swaps [Member] Sold [Member]	Dec. 31, 2011 Cash Flow Hedging [Member] Interest Rate Contract [Member] Forward Starting Swaps [Member] Sold [Member]	Jan. 31, 2012 Cash Flow Hedging [Member] Oneok Inc [Member] Forward Starting Interest Rate Swap [Member]	Dec. 31, 2011 Cash Flow Hedging [Member] Oneok Inc [Member] Forward Starting Interest Rate Swap [Member]	Jul. 31, 2012 Cash Flow Hedging [Member] Oneok Partners [Member] Forward Starting Interest Rate Swap [Member]	Jun. 30, 2012 Cash Flow Hedging [Member] Oneok Partners [Member] Forward Starting Interest Rate Swap [Member]	Dec. 31, 2011 Cash Flow Hedging [Member] Oneok Partners [Member] Forward Starting Interest Rate Swap [Member]	Jan. 31, 2012 Cash Flow Hedging [Member] Notes Payables Due 2022 [Member] Forward Starting Interest Rate Swap [Member]	Jun. 30, 2012 Fair Value Hedging [Member] Basis [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Purchased [Member]	Dec. 31, 2011 Fair Value Hedging [Member] Basis [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Purchased [Member]	Jun. 30, 2012 Fair Value Hedging [Member] Basis [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Sold [Member]	Dec. 31, 2011 Fair Value Hedging [Member] Basis [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Sold [Member]	Jun. 30, 2012 Not Designated as Hedging Instrument [Member] Fixed Price [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Purchased [Member]	Dec. 31, 2011 Not Designated as Hedging Instrument [Member] Fixed Price [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Purchased [Member]	Jun. 30, 2012 Not Designated as Hedging Instrument [Member] Fixed Price [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Sold [Member]	Dec. 31, 2011 Not Designated as Hedging Instrument [Member] Fixed Price [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Sold [Member]	Jun. 30, 2012 Not Designated as Hedging Instrument [Member] Fixed Price [Member] Natural Gas [Member] Options [Member] Purchased [Member]	Dec. 31, 2011 Not Designated as Hedging Instrument [Member] Fixed Price [Member] Natural Gas [Member] Options [Member] Purchased [Member]	Jun. 30, 2012 Not Designated as Hedging Instrument [Member] Fixed Price [Member] Natural Gas [Member] Options [Member] Sold [Member]	Dec. 31, 2011 Not Designated as Hedging Instrument [Member] Fixed Price [Member] Natural Gas [Member] Options [Member] Sold [Member]	Jun. 30, 2012 Not Designated as Hedging Instrument [Member] Fixed Price [Member] Natural Gas [Member] Exchange Futures [Member] Purchased [Member]	Dec. 31, 2011 Not Designated as Hedging Instrument [Member] Fixed Price [Member] Natural Gas [Member] Exchange Futures [Member] Purchased [Member]	Jun. 30, 2012 Not Designated as Hedging Instrument [Member] Fixed Price [Member] Natural Gas [Member] Exchange Futures [Member] Sold [Member]	Dec. 31, 2011 Not Designated as Hedging Instrument [Member] Fixed Price [Member] Natural Gas [Member] Exchange Futures [Member] Sold [Member]	Jun. 30, 2012 Not Designated as Hedging Instrument [Member] Basis [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Purchased [Member]	Dec. 31, 2011 Not Designated as Hedging Instrument [Member] Basis [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Purchased [Member]	Jun. 30, 2012 Not Designated as Hedging Instrument [Member] Basis [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Sold [Member]	Dec. 31, 2011 Not Designated as Hedging Instrument [Member] Basis [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Sold [Member]	Jun. 30, 2012 Not Designated as Hedging Instrument [Member] Index [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Purchased [Member]	Dec. 31, 2011 Not Designated as Hedging Instrument [Member] Index [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Purchased [Member]	Jun. 30, 2012 Not Designated as Hedging Instrument [Member] Index [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Sold [Member]	Dec. 31, 2011 Not Designated as Hedging Instrument [Member] Index [Member] Natural Gas [Member] Forward and Swaps Contracts [Member] Sold [Member]	Jun. 30, 2012 Designated as Hedging Instrument [Member]	Dec. 31, 2011 Designated as Hedging Instrument [Member]	Jun. 30, 2012 Not Designated as Hedging Instrument [Member]	Dec. 31, 2011 Not Designated as Hedging Instrument [Member]	Jun. 30, 2012 Commodity Contract [Member] Designated as Hedging Instrument [Member] Financial Derivative Instrument [Member]	Dec. 31, 2011 Commodity Contract [Member] Designated as Hedging Instrument [Member] Financial Derivative Instrument [Member]	Jun. 30, 2012 Commodity Contract [Member] Designated as Hedging Instrument [Member] Physical Derivative Instrument [Member]	Dec. 31, 2011 Commodity Contract [Member] Designated as Hedging Instrument [Member] Physical Derivative Instrument [Member]	Jun. 30, 2012 Commodity Contract [Member] Not Designated as Hedging Instrument [Member] Financial Derivative Instrument [Member] Trading [Member]	Dec. 31, 2011 Commodity Contract [Member] Not Designated as Hedging Instrument [Member] Financial Derivative Instrument [Member] Trading [Member]	Jun. 30, 2012 Commodity Contract [Member] Not Designated as Hedging Instrument [Member] Financial Derivative Instrument [Member] Non-trading [Member]	Dec. 31, 2011 Commodity Contract [Member] Not Designated as Hedging Instrument [Member] Financial Derivative Instrument [Member] Non-trading [Member]	Jun. 30, 2012 Commodity Contract [Member] Not Designated as Hedging Instrument [Member] Physical Derivative Instrument [Member] Non-trading [Member]	Dec. 31, 2011 Commodity Contract [Member] Not Designated as Hedging Instrument [Member] Physical Derivative Instrument [Member] Non-trading [Member]	Jun. 30, 2012 Interest Rate Contracts [Member] Designated as Hedging Instrument [Member]	Dec. 31, 2011 Interest Rate Contracts [Member] Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	$ 419,494,000		$ 630,847,000																																																			$ 136,820,000	$ 184,246,000	$ 282,674,000	$ 446,601,000	$ 136,655,000	$ 184,184,000	$ 165,000	$ 62,000	$ 76,807,000	$ 111,920,000	$ 190,780,000	$ 295,948,000	$ 15,087,000	$ 38,733,000	$ 0	$ 0
(Liabilities)	(437,984,000)		(637,241,000)																																																			(164,251,000)	(202,356,000)	(273,733,000)	(434,885,000)	(48,014,000)	(73,346,000)	(71,000)	(344,000)	(75,122,000)	(110,050,000)	(197,993,000)	(323,170,000)	(618,000)	(1,665,000)	(116,166,000)	(128,666,000)
Inventory cash flow hedges derivative assets	7,500,000		88,900,000
Derivative [Line Items]
Derivative nonmonetary notional amount				8.5	19.5	(90.3)	(111.9)	8.1	21.2	(16.7)	(23.4)	0	0	(2.6)	(2.9)	13.7	3.2	(45.5)	(82.8)											91.0	76.5	(91.0)	(77.0)	136.0	235.8	(149.2)	(253.4)	205.0	33.6	(205.3)	(14.3)	56.1	76.9	(44.7)	(59.6)	159.3	216.9	(164.6)	(219.3)	34.5	29.3	(15.3)	(22.1)
Notional amount of cash flow hedge instruments																				1,000,000,000	1,250,000,000	0	0	200,000,000	500,000,000		1,000,000,000	750,000,000
Notional amount of cash flow hedge instruments with settlement dates greater than 12 months																										400,000,000
Net unrealized gain in accumulated other comprehensive income (loss)	15,200,000
Amount recognized in the next 12 months	8,900,000
Amount recognized after the next 12 months	6,300,000
Face Amount	350,000,000																												700,000,000
Interest rates (in hundredths)																													4.25%
Amount of loss amortized to interest expense																													44,100,000
Natural gas cash flow hedge losses	$ 29,861,000	$ 0

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CONSOLIDATED BALANCE SHEETS (USD $) In Thousands, unless otherwise specified	Jun. 30, 2012	Dec. 31, 2011
Current assets
Cash and cash equivalents	$ 114,920	$ 65,953
Accounts receivable, net	793,842	1,339,933
Gas and natural gas liquids in storage	561,802	549,915
Commodity imbalances	37,716	63,452
Energy marketing and risk management assets (Notes C and D)	90,335	40,280
Other current assets	208,704	185,143
Assets of discontinued operations (Note B)	0	74,136
Total current assets	1,807,319	2,318,812
Property, plant and equipment	11,953,916	11,177,934
Accumulated depreciation and amortization	2,855,863	2,733,601
Net property, plant and equipment	9,098,053	8,444,333
Investments and other assets
Investments in unconsolidated affiliates (Note K)	1,210,268	1,223,398
Goodwill and intangible assets	1,000,039	1,014,127
Other assets	701,512	695,965
Total investments and other assets	2,911,819	2,933,490
Total assets	13,817,191	13,696,635
Current liabilities
Current maturities of long-term debt	12,262	364,391
Notes payable (Note E)	595,931	841,982
Accounts payable	911,977	1,341,718
Commodity imbalances	201,515	202,206
Energy marketing and risk management liabilities (Notes C and D)	138,028	137,680
Other current liabilities	396,964	345,383
Liabilities of discontinued operations (Note B)	0	12,815
Total current liabilities	2,256,677	3,246,175
Long-term debt, excluding current maturities (Note F)	5,224,623	4,529,551
Deferred credits and other liabilities
Deferred income taxes	1,457,896	1,446,591
Other deferred credits	672,007	674,586
Total deferred credits and other liabilities	2,129,903	2,121,177
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 205,041,894 shares at June 30, 2012; issued 245,809,848 shares and outstanding 206,509,960 shares at December 31, 2011	2,458	2,458
Paid-in capital	1,326,204	1,417,185
Accumulated other comprehensive loss (Note H)	(205,640)	(206,121)
Retained earnings	2,017,460	1,960,374
Treasury stock, at cost: 40,769,286 shares at June 30, 2012, and 39,299,888 shares at December 31, 2011	(1,050,942)	(935,323)
Total ONEOK shareholders' equity	2,089,540	2,238,573
Noncontrolling interests in consolidated subsidiaries	2,116,448	1,561,159
Total equity	4,205,988	3,799,732
Total liabilities and equity	$ 13,817,191	$ 13,696,635

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

6 Months Ended

Jun. 30, 2012

Summary of Significant 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 2011 year-end consolidated balance sheet data was derived from 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.  Due to the seasonal nature of our business, the results of operations for the three and six months ended June 30, 2012, are not necessarily indicative of the results that may be expected for a 12-month period.

Stock Split - In June 2012, we completed our previously announced two-for-one split of our common stock.  The two-for-one split was effected by a distribution on June 1, 2012, of one share of stock for each share outstanding and held by shareholders of record on May 24, 2012.  We have adjusted all share and per-share amounts contained herein, to be presented on a post-split basis.

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

Recently Issued Accounting Standards Update -In May 2011, the FASB issued ASU 2011-04, “Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and International Financial Reporting Standards (IFRS),” which provides a consistent definition of fair value and common requirements for measurement of and disclosure about fair value between GAAP and IFRS.  This new guidance changes some fair value measurement principles and disclosure requirements.  We adopted this guidance with our March 31, 2012, Quarterly Report, and the impact was not material.  See Note C for information on our fair value measurements.

In June 2011, the FASB issued ASU 2011-05, “Presentation of Comprehensive Income,” which provides two options for presenting items of net income, other comprehensive income and total comprehensive income either by creating one continuous statement of comprehensive income or two separate consecutive statements, and requires certain other disclosures.  In December 2011, the FASB issued ASU 2011-12, “Deferral of the Effective Date for Amendments to the Presentation of Reclassifications of Items Out of Accumulated Other Comprehensive Income in Accounting Standards Update No. 2011-05,” which deferred certain presentation requirements in ASU 2011-05 for items reclassified out of accumulated other comprehensive income.  We adopted this guidance, except for the portions deferred by ASU 2011-12, with our March 31, 2012, Quarterly Report, and the impact was not material.

In July 2012, the FASB issued ASU 2012-02, “Testing Indefinite-lived Intangible Assets for Impairment,” which allows companies to perform a “qualitative” assessment to determine whether further impairment testing of indefinite-lived intangible assets is necessary. Under the revised standard, an entity is not required to calculate the fair value of an indefinite-lived intangible asset and perform the quantitative impairment test unless the entity determines that it is more likely than not that the asset is impaired.  An entity has the option to bypass the qualitative assessment and perform the quantitative impairment test for any indefinite-lived intangible assets in any period.  We are evaluating the impact of this recently issued guidance, which is required to be adopted for our annual assessments beginning in 2013.

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FAIR VALUE MEASUREMENTS (Tables)

6 Months Ended

Jun. 30, 2012

FAIR VALUE MEASUREMENTS [Abstract]

Recurring Fair Value Measurments

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

	June 30, 2012
	Level 1			Level 2			Level 3			Netting			Total
	(Thousands of dollars)
Assets
Derivatives (a)
Commodity contracts
Financial contracts	$	330,358		$	27,248		$	46,636		$	-		$	404,242
Physical contracts		-			12,308			2,944			-			15,252
Netting		-			-			-			(320,001	)		(320,001	)
Total derivatives		330,358			39,556			49,580			(320,001	)		99,493
Trading securities (b)		6,326			-			-			-			6,326
Available-for-sale investment securities (c)		2,145			-			-			-			2,145
Total assets	$	338,829		$	39,556		$	49,580		$	(320,001	)	$	107,964
Liabilities
Derivatives (a)
Commodity contracts
Financial contracts	$	(304,810	)	$	(5,171	)	$	(11,148	)	$	-		$	(321,129	)
Physical contracts		-			(2	)		(687	)		-			(689	)
Netting		-			-			-			299,848			299,848
Interest-rate contracts		-			(116,166	)		-			-			(116,166	)
Total derivatives		(304,810	)		(121,339	)		(11,835	)		299,848			(138,136	)
Fair value of firm commitments (d)		-			-			(4,250	)		-			(4,250	)
Total liabilities	$	(304,810	)	$	(121,339	)	$	(16,085	)	$	299,848		$	(142,386	)
(a) - Our derivative assets and liabilities are presented in our Consolidated Balance Sheets as energy marketing and risk- management assets and liabilities and other assets on a net basis. We net derivative assets and liabilities, including cash collateral, when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and us. At June 30, 2012, we held $21.7 million of cash collateral and had posted $8.4 million of cash collateral with various counterparties.
(b) - Included in our Consolidated Balance Sheets as other current assets.
(c) - Included in our Consolidated Balance Sheets as other assets.
(d) - Included in our Consolidated Balance Sheets as other current liabilities and other deferred credits.

	December 31, 2011
	Level 1			Level 2			Level 3			Netting			Total
	(Thousands of dollars)
Assets
Derivatives (a)
Commodity contracts
Financial contracts	$	545,247		$	13,874		$	32,931		$	-		$	592,052
Physical contracts		-			23,879			14,916			-			38,795
Netting		-			-			-			(569,243	)		(569,243	)
Total derivatives		545,247			37,753			47,847			(569,243	)		61,604
Trading securities (b)		5,749			-			-			-			5,749
Available-for-sale investment securities (c)		1,949			-			-			-			1,949
Total assets	$	552,945		$	37,753		$	47,847		$	(569,243	)	$	69,302
Liabilities
Derivatives (a)
Commodity contracts
Financial contracts	$	(479,073	)	$	(6,498	)	$	(20,995	)	$	-		$	(506,566	)
Physical contracts		-			(261	)		(1,748	)		-			(2,009	)
Netting		-			-			-			497,608			497,608
Interest-rate contracts		-			(128,666	)		-			-			(128,666	)
Total derivatives		(479,073	)		(135,425	)		(22,743	)		497,608			(139,633	)
Fair value of firm commitments (d)		-			-			(7,283	)		-			(7,283	)
Total liabilities	$	(479,073	)	$	(135,425	)	$	(30,026	)	$	497,608		$	(146,916	)
(a) - Our derivative assets and liabilities are presented in our Consolidated Balance Sheets as energy marketing and risk- management assets and liabilities, other assets and other deferred credits on a net basis. We net derivative assets and liabilities, including cash collateral, when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and us. At December 31, 2011, we held $73.3 million of cash collateral and had posted $1.7 million of cash collateral with various counterparties.
(b) - Included in our Consolidated Balance Sheets as other current assets.
(c) - Included in our Consolidated Balance Sheets as other assets.
(d) - Included in our Consolidated Balance Sheets as other current liabilities and other deferred credits.

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

The following tables set forth the reconciliation of our Level 3 fair value measurements for the periods indicated:

	Derivative Assets (Liabilities)			Fair Value of Firm Commitments			Total
	(Thousands of dollars)
April 1, 2012	$	17,948		$	(3,770	)	$	14,178
Total realized/unrealized gains (losses):
Included in earnings (a)		(1,117	)		(480	)		(1,597	)
Included in other comprehensive income (loss)		20,942			-			20,942
Transfers into Level 3		(28	)		-			(28	)
June 30, 2012	$	37,745		$	(4,250	)	$	33,495
Total gains (losses) for the period included in    earnings attributable to the change in unrealized    gains (losses) relating to assets and liabilities    still held as of June 30, 2012 (a)	$	1,571		$	(1,318	)	$	253
(a) - Reported in revenues and cost of sales and fuel in our Consolidated Statements of Income.

	Derivative Assets (Liabilities)			Fair Value of Firm Commitments			Total
	(Thousands of dollars)
April 1, 2011	$	30,615		$	(28,991	)	$	1,624
Total realized/unrealized gains (losses):
Included in earnings (a)		(12,329	)		7,779			(4,550	)
Included in other comprehensive income (loss)		1,297			-			1,297
Transfers into Level 3		4,757			-			4,757
Transfers out of Level 3		(482	)		-			(482	)
June 30, 2011	$	23,858		$	(21,212	)	$	2,646
Total gains (losses) for the period included in    earnings attributable to the change in unrealized    gains (losses) relating to assets and liabilities    still held as of June 30, 2011 (a)	$	11,278		$	(3,672	)	$	7,606
(a) - Reported in revenues and cost of sales and fuel in our Consolidated Statements of Income.

	Derivative Assets (Liabilities)			Fair Value of Firm Commitments			Total
	(Thousands of dollars)
January 1, 2012	$	25,104		$	(7,283	)	$	17,821
Total realized/unrealized gains (losses):
Included in earnings (a)		(7,873	)		3,033			(4,840	)
Included in other comprehensive income (loss)		26,727			-			26,727
Sale of discontinued operations		(3,636	)		-			(3,636	)
Transfers out of Level 3		(2,577	)		-			(2,577	)
June 30, 2012	$	37,745		$	(4,250	)	$	33,495
Total gains (losses) for the period included in    earnings attributable to the change in unrealized    gains (losses) relating to assets and liabilities    still held as of June 30, 2012 (a)	$	(419	)	$	(640	)	$	(1,059	)
(a) - Reported in revenues and cost of sales and fuel in our Consolidated Statements of Income.

	Derivative Assets (Liabilities)			Fair Value of Firm Commitments			Total
	(Thousands of dollars)
January 1, 2011	$	49,266		$	(29,536	)	$	19,730
Total realized/unrealized gains (losses):
Included in earnings (a)		(20,333	)		8,324			(12,009	)
Included in other comprehensive income (loss)		(8,558	)		-			(8,558	)
Transfers into Level 3		4,182			-			4,182
Transfers out of Level 3		(699	)		-			(699	)
June 30, 2011	$	23,858		$	(21,212	)	$	2,646
Total gains (losses) for the period included in    earnings attributable to the change in unrealized    gains (losses) relating to assets and liabilities    still held as of June 30, 2011 (a)	$	12,524		$	(6,634	)	$	5,890
(a) - Reported in revenues and cost of sales and fuel in our Consolidated Statements of Income.

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FAIR VALUE MEASUREMENTS (Details) (USD $)	Jun. 30, 2012	Dec. 31, 2011
Commodity contracts
Energy marketing and risk management assets		$ 15,016,000
Commodity contracts
Energy marketing and risk management liabilities		629,000
Cash collateral held	21,700,000	73,300,000
Cash collateral posted	8,400,000	1,700,000
Fair Value, Measurements, Recurring [Member]
Commodity contracts
Energy marketing and risk management assets		15,000,000
Commodity contracts
Energy marketing and risk management liabilities		600,000
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Commodity contracts
Financial contracts	330,358,000	545,247,000
Physical contracts	0	0
Netting	0	0
Total derivatives	330,358,000	545,247,000
Trading securities	6,326,000	5,749,000
Available-for-sale investment securities	2,145,000	1,949,000
Total assets	338,829,000	552,945,000
Commodity contracts
Financial contracts	(304,810,000)	(479,073,000)
Physical contracts	0	0
Netting	0	0
Interest-rate contracts	0	0
Total derivatives	(304,810,000)	(479,073,000)
Fair value of firm commitments	0	0
Total liabilities	(304,810,000)	(479,073,000)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Commodity contracts
Financial contracts	27,248,000	13,874,000
Physical contracts	12,308,000	23,879,000
Netting	0	0
Total derivatives	39,556,000	37,753,000
Trading securities	0	0
Available-for-sale investment securities	0	0
Total assets	39,556,000	37,753,000
Commodity contracts
Financial contracts	(5,171,000)	(6,498,000)
Physical contracts	(2,000)	(261,000)
Netting	0	0
Interest-rate contracts	(116,166,000)	(128,666,000)
Total derivatives	(121,339,000)	(135,425,000)
Fair value of firm commitments	0	0
Total liabilities	(121,339,000)	(135,425,000)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Commodity contracts
Financial contracts	46,636,000	32,931,000
Physical contracts	2,944,000	14,916,000
Netting	0	0
Total derivatives	49,580,000	47,847,000
Trading securities	0	0
Available-for-sale investment securities	0	0
Total assets	49,580,000	47,847,000
Commodity contracts
Financial contracts	(11,148,000)	(20,995,000)
Physical contracts	(687,000)	(1,748,000)
Netting	0	0
Interest-rate contracts	0	0
Total derivatives	(11,835,000)	(22,743,000)
Fair value of firm commitments	(4,250,000)	(7,283,000)
Total liabilities	(16,085,000)	(30,026,000)
Fair Value, Measurements, Recurring [Member] | Netting and Collateral [Member]
Commodity contracts
Financial contracts	0	0
Physical contracts	0	0
Netting	(320,001,000)	(569,243,000)
Total derivatives	(320,001,000)	(569,243,000)
Trading securities	0	0
Available-for-sale investment securities	0	0
Total assets	(320,001,000)	(569,243,000)
Commodity contracts
Financial contracts	0	0
Physical contracts	0	0
Netting	299,848,000	497,608,000
Interest-rate contracts	0	0
Total derivatives	299,848,000	497,608,000
Fair value of firm commitments	0	0
Total liabilities	299,848,000	497,608,000
Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]
Commodity contracts
Financial contracts	404,242,000	592,052,000
Physical contracts	15,252,000	38,795,000
Netting	(320,001,000)	(569,243,000)
Total derivatives	99,493,000	61,604,000
Trading securities	6,326,000	5,749,000
Available-for-sale investment securities	2,145,000	1,949,000
Total assets	107,964,000	69,302,000
Commodity contracts
Financial contracts	(321,129,000)	(506,566,000)
Physical contracts	(689,000)	(2,009,000)
Netting	299,848,000	497,608,000
Interest-rate contracts	(116,166,000)	(128,666,000)
Total derivatives	(138,136,000)	(139,633,000)
Fair value of firm commitments	(4,250,000)	(7,283,000)
Total liabilities	$ (142,386,000)	$ (146,916,000)

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UNCONSOLIDATED AFFILIATES

6 Months Ended

Jun. 30, 2012

UNCONSOLIDATED AFFILIATES [Abstract]

UNCONSOLIDATED AFFILIATES

K.           UNCONSOLIDATED AFFILIATES

Equity Earnings from Investments -The following table sets forth our equity earnings from investments for the periods indicated.  All amounts in the table below are equity earnings from investments in our ONEOK Partners segment:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2012		2011		2012		2011
	(Thousands of dollars)
Northern Border Pipeline Company	$	16,077	$	16,395	$	36,308	$	37,247
Overland Pass Pipeline		5,979		5,360		11,296		9,736
Fort Union Gas Gathering		3,195		3,711		7,403		6,676
Bighorn Gas Gathering		796		1,845		1,961		3,338
Other		3,122		2,233		6,821		4,639
Equity earnings from investments	$	29,169	$	29,544	$	63,789	$	61,636

Unconsolidated Affiliates Financial Information - The following tables set forth summarized combined financial information of our unconsolidated affiliates for the periods indicated:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2012		2011		2012		2011
	(Thousands of dollars)
Income Statement
Operating revenues	$	119,286	$	121,002	$	247,210	$	244,303
Operating expenses	$	57,727	$	51,988	$	112,295	$	106,224
Net income	$	59,812	$	59,244	$	125,066	$	122,409
Distributions paid to ONEOK Partners	$	43,254	$	38,541	$	84,195	$	71,052