Edgar Filing: ONEOK INC /NEW/

OKE-2014.9.30-10Q

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended September 30, 2014.

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

For the transition period from __________ to __________.

Commission file number 001-13643

ONEOK, Inc.

(Exact name of registrant as specified in its charter)



Oklahoma	73-1520922
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

100 West Fifth Street, Tulsa, OK	74103
(Address of principal executive offices)	(Zip Code)

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

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes X No __

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

Yes X No __

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

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

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

Yes __ No X

On October 28, 2014, the Company had 208,198,062 shares of common stock outstanding.

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ONEOK, Inc.

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Part I.	Financial Information	Page No.
Item 1.	Financial Statements (Unaudited)	6
	Consolidated Statements of Income - Three and Nine Months Ended September 30, 2014 and 2013	6
	Consolidated Statements of Comprehensive Income - Three and Nine Months Ended September 30, 2014 and 2013	7
	Consolidated Balance Sheets - September 30, 2014, and December 31, 2013	8
	Consolidated Statements of Cash Flows - Nine Months Ended September 30, 2014 and 2013	11
	Consolidated Statement of Changes in Equity - Nine Months Ended September 30, 2014	12
	Notes to Consolidated Financial Statements	14
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	39
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	66
Item 4.	Controls and Procedures	67
Part II.	Other Information
Item 1.	Legal Proceedings	67
Item 1A.	Risk Factors	67
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	67
Item 3.	Defaults Upon Senior Securities	67
Item 4.	Mine Safety Disclosures	67
Item 5.	Other Information	67
Item 6.	Exhibits	67
Signature		69

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

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

INFORMATION AVAILABLE ON OUR WEBSITE

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

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

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GLOSSARY

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



AFUDC	Allowance for funds used during construction
Annual Report	Annual Report on Form 10-K for the year ended December 31, 2013
ASU	Accounting Standards Update
Bbl	Barrels, 1 barrel is equivalent to 42 United States gallons
Bbl/d	Barrels per day
BBtu/d	Billion British thermal units per day
Bcf	Billion cubic feet
Btu	British thermal units, a measure of the amount of heat required to raise the temperature of one pound of water one degree Fahrenheit
CFTC	U.S. Commodity Futures Trading Commission
Clean Air Act	Federal Clean Air Act, as amended
Clean Water Act	Federal Water Pollution Control Act Amendments of 1972, as amended
DOT	United States Department of Transportation
EBITDA	Earnings before interest expense, income taxes, depreciation and amortization
EPA	United States Environmental Protection Agency
Exchange Act	Securities Exchange Act of 1934, as amended
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
GAAP	Accounting principles generally accepted in the United States of America
Intermediate Partnership	ONEOK Partners Intermediate Limited Partnership, a wholly owned subsidiary of ONEOK Partners, L.P.
LIBOR	London Interbank Offered Rate
MBbl/d	Thousand barrels per day
MDth/d	Thousand dekatherms per day
MMBbl	Million barrels
MMBtu	Million British thermal units
MMBtu/d	Million British thermal units per day
MMcf/d	Million cubic feet per day
Moody’s	Moody’s Investors Service, Inc.
Natural Gas Policy Act	Natural Gas Policy Act of 1978, as amended
NGL(s)	Natural gas liquid(s)
NGL products	Marketable natural gas liquids purity products, such as ethane, ethane/propane mix, propane, iso-butane, normal butane and natural gasoline
NYMEX	New York Mercantile Exchange
NYSE	New York Stock Exchange
ONE Gas	ONE Gas, Inc.
ONEOK	ONEOK, Inc.
ONEOK Credit Agreement	ONEOK’s $300 million Amended and Restated Revolving Credit Agreement dated January 31, 2014
ONEOK Partners	ONEOK Partners, L.P.
ONEOK Partners Credit Agreement	ONEOK Partners’ $1.7 billion Amended and Restated Revolving Credit Agreement dated January 31, 2014
ONEOK Partners GP	ONEOK Partners GP, L.L.C., a wholly owned subsidiary of ONEOK and the sole general partner of ONEOK Partners
OPIS	Oil Price Information Service
Partnership Agreement	Third Amended and Restated Agreement of Limited Partnership of ONEOK Partners, L.P., as amended
PHMSA	United States Department of Transportation Pipeline and Hazardous Materials Safety Administration
POP	Percent of Proceeds
Quarterly Report(s)	Quarterly Report(s) on Form 10-Q

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S&P	Standard & Poor’s Ratings Services
SCOOP	South Central Oklahoma Oil Province
SEC	Securities and Exchange Commission
Securities Act	Securities Act of 1933, as amended
XBRL	eXtensible Business Reporting Language

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PART I - FINANCIAL INFORMATION



ITEM 1. FINANCIAL STATEMENTS



ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF INCOME
	Three Months Ended						Nine Months Ended
	September 30,						September 30,
(Unaudited)	2014			2013			2014			2013
	(Thousands of dollars, except per share amounts)
Revenues
Commodity sales	$	2,754,495		$	2,807,329		$	8,276,333		$	7,453,534
Services	365,650			328,052			1,073,990			968,786
Total revenues	3,120,145			3,135,381			9,350,323			8,422,320
Cost of sales and fuel	2,583,204			2,711,159			7,807,275			7,214,233
Net margin	536,941			424,222			1,543,048			1,208,087
Operating expenses
Operations and maintenance	153,408			116,678			433,457			346,989
Depreciation and amortization	74,588			61,850			214,129			176,016
General taxes	19,087			14,323			60,171			50,912
Total operating expenses	247,083			192,851			707,757			573,917
Gain (loss) on sale of assets	1,534			21			1,533			341
Operating income	291,392			231,392			836,824			634,511
Equity earnings (loss) from investments (Note K)	(52,347		)	27,468			6,747			79,744
Allowance for equity funds used during construction	1,723			6,429			13,947			21,172
Other income	100			4,278			3,117			12,634
Other expense	(2,506		)	(595		)	(27,827		)	(2,476		)
Interest expense (net of capitalized interest of $14,303, $14,320, $41,446 and $38,284, respectively)	(86,052		)	(66,187		)	(269,704		)	(196,793		)
Income before income taxes	152,310			202,785			563,104			548,792
Income taxes	(37,858		)	(44,961		)	(95,155		)	(126,688		)
Income from continuing operations	114,452			157,824			467,949			422,104
Income (loss) from discontinued operations, net of tax (Note B)	(171		)	(10,126		)	(6,406		)	(29,206		)
Net income	114,281			147,698			461,543			392,898
Less: Net income attributable to noncontrolling interests	49,823			85,342			241,980			217,102
Net income attributable to ONEOK	$	64,458		$	62,356		$	219,563		$	175,796
Amounts attributable to ONEOK:
Income from continuing operations	$	64,629		$	72,482		$	225,969		$	205,002
Income (loss) from discontinued operations	(171		)	(10,126		)	(6,406		)	(29,206		)
Net income	$	64,458		$	62,356		$	219,563		$	175,796
Basic earnings per share:
Income from continuing operations (Note I)	$	0.31		$	0.35		$	1.08		$	1.00
Income (loss) from discontinued operations	—			(0.05		)	(0.03		)	(0.15		)
Net income	$	0.31		$	0.30		$	1.05		$	0.85
Diluted earnings per share:
Income from continuing operations (Note I)	$	0.31		$	0.35		$	1.07		$	0.98
Income (loss) from discontinued operations	—			(0.05		)	(0.03		)	(0.14		)
Net income	$	0.31		$	0.30		$	1.04		$	0.84
Average shares (thousands)
Basic	209,489			206,235			209,341			205,952
Diluted	210,759			209,893			210,482			209,408
Dividends declared per share of common stock	$	0.575		$	0.38		$	1.535		$	1.10

See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

	Three Months Ended					Nine Months Ended
	September 30,					September 30,
(Unaudited)	2014		2013			2014			2013
	(Thousands of dollars)
Net income	$	114,281	$	147,698		$	461,543		$	392,898
Other comprehensive income (loss), net of tax
Unrealized gains (losses) on energy marketing and risk-management assets/liabilities, net of tax of $(1,160), $(467), $12,664 and $(10,349), respectively	6,219		(2,542		)	(72,627		)	37,095
Realized (gains) losses in net income, net of tax of $(748), $333, $(14,966) and $(1,748), respectively	3,132		789			48,170			4,694
Unrealized holding gains (losses) on available-for-sale securities, net of tax of $(73), $277, $(36) and $147, respectively	107		(440		)	(6		)	(234		)
Change in pension and postretirement benefit plan liability, net of tax of $(1,456), $4,603, $(5,379) and $13,651, respectively	2,185		(7,293		)	8,069			(21,637		)
Total other comprehensive income (loss), net of tax	11,643		(9,486		)	(16,394		)	19,918
Comprehensive income	125,924		138,212			445,149			412,816
Less: Comprehensive income attributable to noncontrolling interests	55,995		83,378			214,644			239,714
Comprehensive income attributable to ONEOK	$	69,929	$	54,834		$	230,505		$	173,102

See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS

	September 30,		December 31,
(Unaudited)	2014		2013
Assets	(Thousands of dollars)
Current assets
Cash and cash equivalents	$	151,403	$	145,565
Accounts receivable, net	971,285		1,109,510
Natural gas and natural gas liquids in storage	338,345		188,286
Commodity imbalances	74,247		80,481
Other current assets	119,427		133,010
Assets of discontinued operations (Note B)	58,080		747,872
Total current assets	1,712,787		2,404,724
Property, plant and equipment
Property, plant and equipment	12,173,835		10,970,256
Accumulated depreciation and amortization	1,931,713		1,738,302
Net property, plant and equipment	10,242,122		9,231,954
Investments and other assets
Investments in unconsolidated affiliates (Note K)	1,128,509		1,229,838
Goodwill and intangible assets	1,017,715		1,024,562
Other assets	184,935		224,353
Assets of discontinued operations (Note B)	26,128		3,626,050
Total investments and other assets	2,357,287		6,104,803
Total assets	$	14,312,196	$	17,741,481

See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS
(Continued)
	September 30,			December 31,
(Unaudited)	2014			2013
Liabilities and equity	(Thousands of dollars)
Current liabilities
Current maturities of long-term debt	$	10,650		$	10,650
Notes payable (Note E)	—			564,462
Accounts payable	1,221,934			1,273,102
Commodity imbalances	171,249			213,577
Accrued interest	102,838			109,099
Accrued taxes other than income	90,681			37,359
Other current liabilities	120,162			66,393
Liabilities of discontinued operations (Note B)	64,387			455,688
Total current liabilities	1,781,901			2,730,330
Long-term debt, excluding current maturities (Note F)	7,194,957			7,753,657
Deferred credits and other liabilities
Deferred income taxes	1,303,548			1,146,562
Other deferred credits	229,280			217,522
Liabilities of discontinued operations (Note B)	43,115			1,048,230
Total deferred credits and other liabilities	1,575,943			2,412,314
Commitments and contingencies (Note M)
Equity (Note G)
ONEOK shareholders’ equity:
Common stock, $0.01 par value: authorized 600,000,000 shares; issued 245,811,180 shares and outstanding 208,193,467 shares at September 30, 2014; issued 245,811,180 shares and outstanding 206,618,877 shares at December 31, 2013	2,458			2,458
Paid-in capital	1,515,158			1,433,600
Accumulated other comprehensive loss (Note H)	(107,656		)	(121,987		)
Retained earnings	170,249			2,020,815
Treasury stock, at cost: 37,617,713 shares at September 30, 2014, and 39,192,303 shares at December 31, 2013	(956,977		)	(997,035		)
Total ONEOK shareholders’ equity	623,232			2,337,851
Noncontrolling interests in consolidated subsidiaries	3,136,163			2,507,329
Total equity	3,759,395			4,845,180
Total liabilities and equity	$	14,312,196		$	17,741,481

See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF CASH FLOWS
	Nine Months Ended
	September 30,
(Unaudited)	2014			2013
	(Thousands of dollars)
Operating activities
Net income	$	461,543		$	392,898
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	225,483			276,343
Charges attributable to exit activities	1,739			130,753
Equity earnings from investments	(6,747		)	(79,744		)
Distributions received from unconsolidated affiliates	84,298			79,022
Deferred income taxes	96,044			107,575
Share-based compensation expense	23,359			27,634
Pension and postretirement benefit expense, net of contributions	14,282			7,638
Allowance for equity funds used during construction	(13,947		)	(21,172		)
Loss (gain) on sale of assets	(1,533		)	(342		)
Other	—			(4,047		)
Changes in assets and liabilities:
Accounts receivable	156,555			182,377
Natural gas and natural gas liquids in storage	(43,351		)	(147,199		)
Accounts payable	(111,186		)	82,743
Commodity imbalances, net	(33,214		)	(49,274		)
Settlement of exit activities liabilities	(38,627		)	(6,143		)
Accrued interest	(6,390		)	17,462
Accrued taxes other than income	66,083			27,417
Other assets and liabilities, net	(3,852		)	(2,395		)
Cash provided by operating activities	870,539			1,021,546
Investing activities
Capital expenditures (less allowance for equity funds used during construction)	(1,204,386		)	(1,597,820		)
Acquisitions	(14,000		)	(304,889		)
Contributions to unconsolidated affiliates	(1,063		)	(4,558		)
Distributions received from unconsolidated affiliates	24,925			24,891
Proceeds from sale of assets	2,388			1,685
Cash used in investing activities	(1,192,136		)	(1,880,691		)
Financing activities
Borrowing (repayment) of notes payable, net	(564,462		)	(254,841		)
Issuance of ONE Gas, Inc. debt, net of discounts	1,199,994			—
Issuance of long-term debt, net of discounts	—			1,247,822
ONE Gas, Inc. long-term debt financing costs	(9,663		)	—
Long-term debt financing costs	—			(10,217		)
Repayment of long-term debt	(555,768		)	(5,802		)
Issuance of common stock	12,908			8,538
Issuance of common units, net of issuance costs	947,472			569,246
Dividends paid	(321,051		)	(226,349		)
Cash of ONE Gas, Inc. at separation	(60,000		)	—
Distributions to noncontrolling interests	(325,158		)	(273,346		)
Cash provided by financing activities	324,272			1,055,051
Change in cash and cash equivalents	2,675			195,906
Change in cash and cash equivalents included in discontinued operations	3,163			1,358
Change in cash and cash equivalents included in continuing operations	5,838			197,264
Cash and cash equivalents at beginning of period	145,565			579,578
Cash and cash equivalents at end of period	$	151,403		$	776,842

See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY

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

See accompanying Notes to Consolidated Financial Statements.

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

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ONEOK, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS


A.	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

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

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

Organization and Nature of Operations - We are the sole general partner and own limited partner units of ONEOK Partners (NYSE: OKS), which together represent an aggregate 38.3 percent interest in ONEOK Partners at September 30, 2014. On January 31, 2014, we completed the separation of our natural gas distribution business into a stand-alone publicly traded company called ONE Gas (NYSE: OGS). On March 31, 2014, we completed the accelerated wind down of our energy services business. The results of operations for our former natural gas distribution and energy services businesses have been classified as discontinued operations for all periods presented. Following the ONE Gas separation and wind down of our energy services business, our primary source of income and cash flow is generated from our investment in ONEOK Partners. See Note B for additional information.

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

Change in Reportable Segments - Following the separation of our natural gas distribution business into ONE Gas and wind down of our energy services business, our chief operating decision maker reviews the financial performance of each of the three businesses of ONEOK Partners on a regular basis to assess the performance of, and allocate resources to, ONEOK Partners. As a result, our reportable segments have changed effective for the first quarter 2014 to reflect the three business segments of ONEOK Partners, which include the following:


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


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


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

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

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

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

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

In August 2014, the FASB issued ASU 2014-15, “Going Concern,” which provides guidance on determining when and how to disclose going-concern uncertainties in the financial statements. The new standard requires management to perform interim and annual assessments of an entity’s ability to continue as a going concern within one year of the date the financial statements are issued. An entity must provide certain disclosures if conditions or events raise substantial doubt about the entity’s ability to continue as a going concern. The standard applies to all entities and is effective for annual periods ending after December 15, 2016, and interim periods thereafter, with early adoption permitted. We will adopt this guidance beginning in the first quarter 2017, and we do not expect it to materially impact us.


B.	DISCONTINUED OPERATIONS

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

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

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



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

We expect future cash payments associated with previously released transportation and storage capacity from the wind down of our energy services business on an after-tax basis to be approximately $53 million, with approximately $8 million to be paid in the remainder of 2014, $23 million in 2015, $11 million in 2016 and $11 million over the period 2017 through 2023.

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



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

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

(b) - Represents primarily accretion expense.



	Three Months Ended									Nine Months Ended
	September 30, 2013									September 30, 2013
	Natural Gas Distribution			Energy Services			Total			Natural Gas Distribution			Energy Services			Total
	(Thousands of dollars)
Revenues	$	219,723		$	298,145		$	517,868		$	1,167,260		$	1,128,324		$	2,295,584
Cost of sales and fuel	60,492			320,411			380,903			577,912			1,287,731			1,865,643
Net margin	159,231			(22,266		)	136,965			589,348			(159,407		)	429,941
Operating costs	103,682			2,178			105,860			321,467			10,545			332,012
Depreciation and amortization	32,347			70			32,417			100,118			209			100,327
Operating income (loss)	23,202			(24,514		)	(1,312		)	167,763			(170,161		)	(2,398		)
Other income (expense), net	1,354			41			1,395			1,929			86			2,015
Interest expense, net	(15,233		)	(488		)	(15,721		)	(45,702		)	(1,581		)	(47,283		)
Income taxes	(3,571		)	9,083			5,512			(44,372		)	62,832			18,460
Income (loss) from discontinued operations, net	$	5,752		$	(15,878	)	$	(10,126	)	$	79,618		$	(108,824	)	$	(29,206	)

Prior to the ONE Gas separation, natural gas sales and transportation and storage services provided to our former natural gas distribution business by ONEOK Partners were $17.7 million for the three months ended September 30, 2013, and $7.5 million and $45.8 million for the nine months ended September 30, 2014 and 2013, respectively. Prior to February 1, 2014, these revenues and related costs were eliminated in consolidation. Beginning February 1, 2014, these revenues represent third-party transactions with ONE Gas and are not eliminated in consolidation, as such sales and services have continued subsequent to the separation and are expected to continue in future periods.

Prior to the completion of the energy services wind down, natural gas sales and transportation and storage services provided to our energy services business by ONEOK Partners were $63.6 million for the three months ended September 30, 2013, and $46.0 million and $209.5 million for the nine months ended September 30, 2014 and 2013, respectively. While these transactions were eliminated in consolidation in previous periods, they are reflected now as affiliate transactions and not eliminated in consolidation as these transactions have continued with third parties.

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



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

At September 30, 2014, the major classes of assets and liabilities in discontinued operations related to our former energy services business. These amounts consisted of current assets, which included income taxes receivable of $43.8 million and deferred tax assets of $12.4 million; noncurrent assets, which included deferred tax assets of $25.7 million; current liabilities, which included capacity release obligations of $43.5 million and deferred tax liabilities of $11.7 million; and noncurrent liabilities, which included $43.1 million of noncurrent capacity release obligations.


C.	FAIR VALUE MEASUREMENTS

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

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

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

In addition, as prescribed by the income approach, ONEOK Partners computes the fair value of its derivative portfolio by discounting the projected future cash flows from its derivative assets and liabilities to present value using interest-rate yields to calculate present-value discount factors derived from LIBOR, Eurodollar futures and interest-rate swaps. ONEOK Partners also takes into consideration the potential impact on market prices of liquidating positions in an orderly manner over a

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reasonable period of time under current market conditions. It considers current market data in evaluating counterparties’, as well as its own, nonperformance risk, net of collateral, by using specific and sector bond yields and monitoring the credit default swap markets. Although ONEOK Partners uses its best estimates to determine the fair value of the derivative contracts it has executed, the ultimate market prices realized could differ from its estimates, and the differences could be material.

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

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


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


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

•

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

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



	September 30, 2014
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)
Assets
Derivatives
Commodity contracts
Financial contracts	$	9,093		$	439		$	—		$	9,532		$	(3,004	)	$	6,528
Physical contracts	—			—			2,900			2,900			(329		)	2,571
Interest-rate contracts	—			20,962			—			20,962			—			20,962
Total derivatives	9,093			21,401			2,900			33,394			(3,333		)	30,061
Available-for-sale investment securities (c)	1,599			—			—			1,599			—			1,599
Total assets	$	10,692		$	21,401		$	2,900		$	34,993		$	(3,333	)	$	31,660
Liabilities
Derivatives
Commodity contracts
Financial contracts	$	(83	)	$	—		$	(2,921	)	$	(3,004	)	$	3,004		$	—
Physical contracts	—			—			(683		)	(683		)	329			(354		)
Interest-rate contracts	—			(23,308		)	—			(23,308		)	—			(23,308		)
Total liabilities	$	(83	)	$	(23,308	)	$	(3,604	)	$	(26,995	)	$	3,333		$	(23,662	)

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

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

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

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

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

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



	Three Months Ended						Nine Months Ended
	September 30,						September 30,
Derivative Assets (Liabilities)	2014			2013			2014			2013
	(Thousands of dollars)
Net assets (liabilities) at beginning of period	$	(1,313	)	$	7,682		$	(782	)	$	(2,423	)
Total realized/unrealized gains (losses):
Included in earnings (a)	207			—			(688		)	—
Included in other comprehensive income (loss)	402			(7,181		)	(2,968		)	2,924
Purchases, issuances and settlements	—			—			3,734			—
Net assets (liabilities) at end of period	$	(704	)	$	501		$	(704	)	$	501

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

Realized/unrealized gains (losses) include the realization of ONEOK Partners’ derivative contracts through maturity. During the three and nine months ended September 30, 2014 and 2013, gains or losses included in earnings attributable to the change in unrealized gains or losses relating to assets and liabilities still held at the end of the period were not material.

ONEOK Partners recognizes transfers into and out of the levels in the fair value hierarchy as of the end of each reporting period. During the three and nine months ended September 30, 2014 and 2013, there were no transfers between levels.

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

The estimated fair value of our consolidated long-term debt, including current maturities, was $7.9 billion and $8.2 billion at September 30, 2014, and December 31, 2013, respectively. The book value of long-term debt, including current maturities, was $7.2 billion and $7.8 billion at September 30, 2014, and December 31, 2013, respectively. The estimated fair value of the

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aggregate of ONEOK’s and ONEOK Partners’ senior notes outstanding was determined using quoted market prices for similar issues with similar terms and maturities. The estimated fair value of our consolidated long-term debt is classified as Level 2.

During the three months ended September 30, 2014, ONEOK Partners recorded a noncash impairment to its equity investment in Bighorn Gas Gathering. The valuation of this investment required use of significant unobservable inputs. ONEOK Partners used an income approach to estimate the fair value of its investment. ONEOK Partners’ discounted cash flow analysis included the following inputs that are not readily available: a discount rate reflective of its cost of capital and estimated contract rates, volumes, operating and maintenance costs and capital expenditures. The estimated fair value of this investment is classified as Level 3. See Note K for additional information about ONEOK Partners’ investment in Bighorn Gas Gathering and the impairment charge.


D.	RISK-MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

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

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


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


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


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

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

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

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

Interest-rate risk - We and ONEOK Partners manage interest-rate risk through the use of fixed-rate debt, floating-rate debt and interest-rate swaps. Interest-rate swaps are agreements to exchange interest payments at some future point based on specified notional amounts. At September 30, 2014, ONEOK Partners had forward-starting interest-rate swaps with notional amounts

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totaling $900 million that have been 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, of which $400 million have settlement dates greater than 12 months.

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

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



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

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

The realized revenues and purchase costs of derivative instruments that are not considered held for trading purposes and derivatives that qualify as normal purchases or normal sales that are expected to result in physical delivery are reported on a gross basis.

Cash flows from futures, forwards and swaps that are accounted for as hedges are included in the same category as the cash flows from the related hedged items in our Consolidated Statements of Cash Flows.

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



	September 30, 2014					December 31, 2013
	Assets (a)		(Liabilities) (a)			Assets (a)		(Liabilities) (a)
	(Thousands of dollars)
Derivatives designated as hedging instruments
Commodity contracts
Financial contracts	$	9,532	$	(3,004	)	$	6,469	$	(5,107	)
Physical contracts	2,554		(608		)	1,064		(3,463		)
Interest-rate contracts	20,962		(23,308		)	54,503		—
Total derivatives designated as hedging instruments	33,048		(26,920		)	62,036		(8,570		)
Derivatives not designated as hedging instruments
Commodity contracts
Physical contracts	346		(75		)	959		—
Total derivatives not designated as hedging instruments	346		(75		)	959		—
Total derivatives	$	33,394	$	(26,995	)	$	62,995	$	(8,570	)

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

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



		September 30, 2014					December 31, 2013
	Contract Type	Purchased/ Payor		Sold/ Receiver			Purchased/ Payor		Sold/ Receiver
Derivatives designated as hedging instruments:
Cash flow hedges
Fixed price
- Natural gas (Bcf)	Futures and swaps	—		(31.2		)	—		(48.1		)
- Crude oil and NGLs (MMbbl)	Futures, forwards and swaps	—		(1.7		)	—		(4.0		)
Basis
- Natural gas (Bcf)	Futures and swaps	—		(31.2		)	—		(48.1		)
Interest-rate contracts (Millions of dollars)	Forward-starting swaps	$	900.0	$	—		$	400.0	$	—

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

Cash Flow Hedges - Accumulated other comprehensive income (loss) at September 30, 2014, includes gains of approximately $1.5 million, net of tax, related to ONEOK Partners’ commodity derivative instruments that will be recognized within the next 15 months as the forecasted transactions affect earnings. If prices remain at current levels, we will recognize $1.3 million in net gains over the next 12 months and net gains of $0.2 million thereafter. The amount deferred in accumulated other comprehensive income (loss) attributable to our and ONEOK Partners’ settled interest-rate swaps is a loss of $38.6 million, net of tax, which will be recognized over the life of the long-term, fixed-rate debt. We expect that losses of $4.8 million will be reclassified into earnings during the next 12 months as the hedged items affect earnings. The remaining amounts in accumulated other comprehensive income (loss) are attributable primarily to ONEOK Partners’ forward-starting interest-rate swaps with future settlement dates, which will be amortized to interest expense over the life of long-term, fixed-rate debt upon issuance of ONEOK Partners’ debt.

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



Derivatives in Cash Flow Hedging Relationships	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2014			2013			2014			2013
	(Thousands of dollars)
Commodity contracts	$	17,133		$	(10,317	)	$	(24,743	)	$	3,060
Interest-rate contracts	(9,755		)	6,721			(56,849		)	35,726
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives(effective portion)	$	7,378		$	(3,596	)	$	(81,592	)	$	38,786

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



Derivatives in Cash Flow Hedging Relationships	Location of Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) into Net Income (Effective Portion)	Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
		(Thousands of dollars)
Commodity contracts	Commodity sales revenues	$	(355	)	$	361		$	(31,961	)	$	4,172
Interest-rate contracts	Interest expense	(3,525		)	(3,696		)	(18,372		)	(10,840		)
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income on derivatives (effective portion)		$	(3,880	)	$	(3,335	)	$	(50,333	)	$	(6,668	)

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

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

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

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

Some of ONEOK Partners’ financial derivative instruments contain provisions that require it to maintain an investment-grade credit rating from S&P and/or Moody’s. If ONEOK Partners’ credit ratings on senior unsecured long-term debt were to decline below investment grade, the counterparties to the derivative instruments could request collateralization on derivative instruments in net liability positions. There were no financial derivative instruments with contingent features related to credit risk in a net liability position at September 30, 2014.

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

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E.	CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE

ONEOK Credit Agreement - The ONEOK Credit Agreement, which was amended and restated effective on January 31, 2014, and expires in January 2019, is a $300 million revolving credit facility and contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of indebtedness to Consolidated EBITDA (EBITDA, as defined in our ONEOK Credit Agreement) of no more than 4.0 to 1. Upon breach of certain covenants by us in the ONEOK Credit Agreement, amounts outstanding under the ONEOK Credit Agreement, if any, may become due and payable immediately. At September 30, 2014, ONEOK’s ratio of indebtedness to Consolidated EBITDA was 1.9 to 1, and ONEOK was in compliance with all covenants under the ONEOK Credit Agreement. As a result of a reduction in the borrowing capacity of the ONEOK Credit Agreement, we wrote off approximately $2.9 million in interest expense of previously deferred credit agreement issuance costs in the first quarter 2014.

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

In February 2014, we repaid all amounts outstanding under our commercial paper program, with a portion of the proceeds received from ONE Gas in connection with the separation, and terminated the program. See Note F for additional information. At September 30, 2014, ONEOK had $2.1 million in letters of credit issued and no borrowings under the ONEOK Credit Agreement.

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

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

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

The ONEOK Partners Credit Agreement contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of indebtedness to adjusted EBITDA (EBITDA, as defined in the ONEOK Partners Credit Agreement, adjusted for all noncash charges and increased for projected EBITDA from certain lender-approved capital expansion projects) of no more than 5.0 to 1. If ONEOK Partners consummates one or more acquisitions in which the aggregate purchase price is $25 million or more, the allowable ratio of indebtedness to adjusted EBITDA will increase to 5.5 to 1 for the quarter in which the acquisition was completed and the two following quarters. As a result of a pipeline acquisition ONEOK Partners completed in the first quarter 2014, the allowable ratio of indebtedness to adjusted EBITDA increased to 5.5 to 1 through the third quarter 2014. Upon breach of certain covenants by ONEOK Partners in the ONEOK Partners Credit Agreement, amounts outstanding under the ONEOK Partners Credit Agreement, if any, may become due and payable immediately. At September 30, 2014, its ratio of indebtedness to adjusted EBITDA was 3.4 to 1, and ONEOK Partners was in compliance with all covenants under the ONEOK Partners Credit Agreement.

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

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F.	LONG-TERM DEBT

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



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

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

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

In September 2013, ONEOK Partners completed an underwritten public offering of $1.25 billion of senior notes, consisting of $425 million, 3.2 percent senior notes due 2018, $425 million, 5.0 percent senior notes due 2023 and $400 million, 6.2 percent senior notes due 2043. A portion of the net proceeds from the offering of approximately $1.24 billion was used to repay amounts outstanding under its commercial paper program, and the balance was used for general partnership purposes, including but not limited to capital expenditures.


G.	EQUITY

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



	Three Months Ended									Three Months Ended
	September 30, 2014									September 30, 2013
	ONEOK Shareholders’ Equity			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity			ONEOK Shareholders’ Equity			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity
	(Thousands of dollars)
Beginning balance	$	656,425		$	3,136,906		$	3,793,331		$	2,085,349		$	2,089,007		$	4,174,356
Net income	64,458			49,823			114,281			62,356			85,342			147,698
Other comprehensive income (loss)	5,471			6,172			11,643			(7,522		)	(1,964		)	(9,486		)
Common stock issued	5,757			—			5,757			4,142			—			4,142
Common stock dividends	(121,367		)	—			(121,367		)	(78,367		)	—			(78,367		)
Issuance of common units of ONEOK Partners	11,185			62,078			73,263			81,502			420,391			501,893
Distribution of ONE Gas to shareholders	1,735			—			1,735			—			—			—
Distributions to noncontrolling interests	—			(118,816		)	(118,816		)	—			(91,824		)	(91,824		)
Other	(432		)	—			(432		)	42,234			—			42,234
Ending balance	$	623,232		$	3,136,163		$	3,759,395		$	2,189,694		$	2,500,952		$	4,690,646

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	Nine Months Ended									Nine Months Ended
	September 30, 2014									September 30, 2013
	ONEOK Shareholders’ Equity			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity			ONEOK Shareholders’ Equity			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity
	(Thousands of dollars)
Beginning balance	$	2,337,851		$	2,507,329		$	4,845,180		$	2,129,609		$	2,102,841		$	4,232,450
Net income	219,563			241,980			461,543			175,796			217,102			392,898
Other comprehensive income (loss)	10,942			(27,336		)	(16,394		)	(2,694		)	22,612			19,918
Common stock issued	19,661			—			19,661			11,892			—			11,892
Common stock dividends	(321,051		)	—			(321,051		)	(226,349		)	—			(226,349		)
Issuance of common units of ONEOK Partners	138,310			739,348			877,658			84,458			431,743			516,201
Distribution of ONE Gas to shareholders	(1,745,689		)	—			(1,745,689		)	—			—			—
Distributions to noncontrolling interests	—			(325,158		)	(325,158		)	—			(273,346		)	(273,346		)
Other	(36,355		)	—			(36,355		)	16,982			—			16,982
Ending balance	$	623,232		$	3,136,163		$	3,759,395		$	2,189,694		$	2,500,952		$	4,690,646

Dividends - Dividends paid on our common stock to shareholders of record at the close of business on February 10, 2014, April 30, 2014, and August 14, 2014, were $0.40 per share, $0.56 per share and $0.575 per share, respectively. A dividend of $0.59 per share was declared for shareholders of record at the close of business on November 3, 2014, payable November 14, 2014.

See Note L for a discussion of ONEOK Partners’ 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 (a)			Unrealized Holding Gains (Losses) on Investment Securities (a)			Pension and Postretirement Benefit Plan Obligations (a)			Accumulated Other Comprehensive Income (Loss) (a)
	(Thousands of dollars)
January 1, 2014	$	(43,168	)	$	857		$	(79,676	)	$	(121,987	)
Other comprehensive income (loss) before reclassifications	(20,717		)	(6		)	(79		)	(20,802		)
Amounts reclassified from accumulated other comprehensive income (loss)	23,596			—			8,148			31,744
Other comprehensive income (loss) attributable to ONEOK	2,879			(6		)	8,069			10,942
Transfer to ONE Gas	—			—			3,389			3,389
September 30, 2014	$	(40,289	)	$	851		$	(68,218	)	$	(107,656	)

(a) All amounts are presented net of tax.

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



Details about Accumulated Other Comprehensive Income (Loss) Components	Three Months Ended						Nine Months Ended						Affected Line Item in the Consolidated Statements of Income
	September 30,						September 30,
	2014			2013			2014			2013
	(Thousands of dollars)
Unrealized (gains) losses on energy marketing and risk-management assets/liabilities
Commodity contracts	$	355		$	(361	)	$	31,961		$	(4,172	)	Commodity sales revenues
Interest-rate contracts	3,525			3,696			18,372			10,840			Interest expense
	3,880			3,335			50,333			6,668			Income before income taxes
	(748		)	(781		)	(9,845		)	(1,836		)	Income tax expense
	3,132			2,554			40,488			4,832			Income from continuing operations
	—			(1,765		)	7,682			(138		)	Income (loss) from discontinued operations
	3,132			789			48,170			4,694			Net income
Noncontrolling interest	1,928			1,317			24,574			1,923			Less: Net income attributable to noncontrolling interest
	$	1,204		$	(528	)	$	23,596		$	2,771		Net income (loss) attributable to ONEOK

Pension and postretirement benefit plan obligations (a)
Amortization of net loss	$	4,009		$	5,078		$	11,936		$	15,234
Amortization of unrecognized prior service cost	(368		)	(113		)	(1,102		)	(339		)
Amortization of unrecognized net asset at adoption	—			7			—			21
	3,641			4,972			10,834			14,916			Income before income taxes
	(1,456		)	(1,924		)	(4,334		)	(5,770		)	Income tax expense
	2,185			3,048			6,500			9,146			Income from continuing operations
	—			8,379			1,648			25,381			Income from discontinued operations
	$	2,185		$	11,427		$	8,148		$	34,527		Net income attributable to ONEOK

Total reclassifications for the period attributable to ONEOK	$	3,389		$	10,899		$	31,744		$	37,298		Net income attributable to ONEOK

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


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

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	Three Months Ended September 30, 2013
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	72,482	206,235	$	0.35
Diluted EPS from continuing operations
Effect of dilutive securities	—		3,658
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	72,482	209,893	$	0.35



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



	Nine Months Ended September 30, 2013
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	205,002	205,952	$	1.00
Diluted EPS from continuing operations
Effect of dilutive securities	—		3,456
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	205,002	209,408	$	0.98


J.	EMPLOYEE BENEFIT PLANS

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



	Pension Benefits						Pension Benefits
	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2014			2013			2014			2013
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	1,784		$	1,532		$	5,429		$	4,596
Interest cost	4,488			3,906			13,744			11,718
Expected return on assets	(4,775		)	(4,969		)	(14,644		)	(14,907		)
Amortization of unrecognized prior service cost	48			58			144			174
Amortization of net loss	3,798			4,755			11,309			14,265
Other	16			—			136			—
Net periodic benefit cost	$	5,359		$	5,282		$	16,118		$	15,846

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	Postretirement Benefits						Postretirement Benefits
	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2014			2013			2014			2013
	(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	175		$	118		$	533		$	354
Interest cost	603			298			1,825			894
Expected return on assets	(513		)	(314		)	(1,623		)	(942		)
Amortization of unrecognized net asset at adoption	—			7			—			21
Amortization of unrecognized prior service cost	(416		)	(171		)	(1,246		)	(513		)
Amortization of net loss	211			323			627			969
Other	—			—			(2		)	—
Net periodic benefit cost	$	60		$	261		$	114		$	783


K.	UNCONSOLIDATED AFFILIATES

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



	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2014			2013		2014			2013
	(Thousands of dollars)
Share of investee earnings (loss)
Northern Border Pipeline	$	14,371		$	16,464	$	53,657		$	48,133
Overland Pass Pipeline Company	3,856			5,783		12,708			14,210
Fort Union Gas Gathering	4,169			2,946		12,578			9,895
Bighorn Gas Gathering (a)	(23,472		)	559		(24,745		)	1,897
Other	2,150			1,716		5,970			5,609
Total share of investee earnings	1,074			27,468		60,168			79,744
Impairment of investment in Bighorn Gas Gathering	(53,421		)	—		(53,421		)	—
Equity earnings (loss) from investments	$	(52,347	)	$	27,468	$	6,747		$	79,744

(a) Includes proportionate share of investee impairment of long-lived assets charge of $23.0 million.

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



	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2014			2013		2014		2013
	(Thousands of dollars)
Income Statement
Operating revenues	$	126,218		$	131,959	$	403,006	$	391,912
Operating expenses (a)	$	123,620		$	63,971	$	247,169	$	189,366
Net income (loss) (a)	$	(5,119	)	$	61,630	$	134,432	$	185,580

Distributions paid to ONEOK Partners	$	31,574		$	34,409	$	109,223	$	103,913

(a) - Includes long-lived asset impairment charge on Bighorn Gas Gathering.

ONEOK Partners incurred expenses in transactions with unconsolidated affiliates of $15.0 million and $15.9 million for the three months ended September 30, 2014 and 2013, respectively, and $43.5 million and $36.3 million for the nine months ended September 30, 2014 and 2013, respectively, primarily related to Overland Pass Pipeline Company and Northern Border

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Pipeline Company, which are included in cost of sales and fuel in our Consolidated Statements of Income. Accounts payable to ONEOK Partners’ equity method investees at September 30, 2014, and December 31, 2013, were not material.

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

During 2014 through the third quarter, the volumes gathered on the Bighorn Gas Gathering system declined at a rate greater than in prior periods and greater than expected. Due to these additional declines in volumes, Bighorn Gas Gathering recorded an impairment of its underlying assets in September 2014, when the operator determined that the volume decline was other than temporary. As a result of these developments, ONEOK Partners reviewed its equity method investment in Bighorn Gas Gathering for impairment as of September 30, 2014. ONEOK Partners recorded noncash impairment charges of $76.4 million related to Bighorn Gas Gathering. The noncash impairment charges are included in equity earnings (loss) from investments in our accompanying Consolidated Statements of Income. The remaining net book value of ONEOK Partners’ equity method investment in Bighorn Gas Gathering is $8.8 million, and no equity method goodwill remains.


L.	ONEOK PARTNERS

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

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

During the nine months ended September 30, 2014, ONEOK Partners sold approximately 4.4 million common units through this program. The net proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, were approximately $245.4 million, which were used for general partnership purposes.

As a result of these transactions, our aggregate ownership interest in ONEOK Partners decreased to 38.3 percent at September 30, 2014, from 41.2 percent at December 31, 2013.

In August 2013, ONEOK Partners completed an underwritten public offering of 11.5 million common units at a public offering price of $49.61 per common unit, generating net proceeds of approximately $553.4 million. In conjunction with this issuance, we contributed approximately $11.6 million in order to maintain our 2 percent general partner interest in ONEOK Partners. ONEOK Partners used a portion of the proceeds from its August 2013 equity issuance to repay amounts outstanding under its commercial paper program, and the balance was used for general partnership purposes.

During the three months ended March 31, 2013, ONEOK Partners sold 300,000 common units through the “at-the-market” program that resulted in net proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, of approximately $16.3 million and used the proceeds for general partnership purposes. There were no common units sold through this program in the second or third quarter 2013.

We account for the difference between the carrying amount of our investment in ONEOK Partners and the underlying book value arising from issuance of common units by ONEOK Partners as an equity transaction. If ONEOK Partners issues

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common units at a price different than our carrying value per unit, we account for the premium or deficiency as an adjustment to paid-in capital. As a result of ONEOK Partners’ issuance of common units, we recognized an increase to paid-in capital of approximately $138.3 million, net of taxes, for the nine months ended September 30, 2014.

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



General partner interest	2.0	%
Limited partner interest (a)	36.3	%
Total ownership interest	38.3	%

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

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


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


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


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

In October 2014, a cash distribution of $0.775 per unit ($3.10 per unit on an annualized basis), an increase of 1.5 cents from the previous quarter, was declared for the third quarter 2014 and will be paid on November 14, 2014, to unitholders of record at the close of business on November 3, 2014.

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



	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2014		2013		2014		2013
	(Thousands, except per unit amounts)
Distribution per unit	$	0.760	$	0.720	$	2.235	$	2.145

General partner distributions	$	5,501	$	4,512	$	15,361	$	13,399
Incentive distributions	80,381		62,634		220,547		184,647
Distributions to general partner	85,882		67,146		235,908		198,046
Limited partner distributions to ONEOK	70,519		66,807		207,381		199,031
Limited partner distributions to noncontrolling interest	118,644		91,676		324,805		272,904
Total distributions paid	$	275,045	$	225,629	$	768,094	$	669,981

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



	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2014		2013		2014		2013
	(Thousands, except per unit amounts)
Distribution per unit	$	0.775	$	0.725	$	2.280	$	2.160

General partner distributions	$	5,683	$	4,795	$	16,195	$	13,776
Incentive distributions	84,452		67,017		236,744		191,226
Distributions to general partner	90,135		71,812		252,939		205,002
Limited partner distributions to ONEOK	71,911		67,271		211,557		200,422
Limited partner distributions to noncontrolling interest	122,105		100,650		345,255		283,365
Total distributions declared	$	284,151	$	239,733	$	809,751	$	688,789

West Texas LPG Acquisition - In October 2014, ONEOK Partners announced that it has agreed to acquire an 80 percent interest in the West Texas LPG Limited Partnership (West Texas LPG) and 100 percent interest in the Mesquite Pipeline (Mesquite) from affiliates of Chevron Corporation for approximately $800 million, subject to customary post-closing adjustments. Closing is subject to customary conditions, including antitrust clearance from the Federal Trade Commission under the Hart-Scott-Rodino Act. Following the closing of the transaction, ONEOK Partners will be the operator of both pipelines. Financing to close this transaction is expected to come from ONEOK Partners’ available cash on hand or borrowing under its existing $1.7 billion commercial paper program or its existing $1.7 billion credit facility. We expect to account for this transaction using the acquisition method of accounting, which requires, among other things, that the asset acquired and liabilities assumed, which could include intangible assets and goodwill, be recognized on the balance sheet at their fair values as of the acquisition date.

The West Texas LPG and Mesquite systems consist of approximately 2,600 miles of NGL gathering pipelines extending from the Permian Basin in southeastern New Mexico to East Texas and Mont Belvieu, Texas. The West Texas LPG and Mesquite systems are expected to provide ONEOK Partners additional fee-based earnings and its NGL infrastructure with access to a new NGL supply basin. The pipelines are expected to initially add an additional 230,000 bpd of unfractionated NGLs to ONEOK Partners’ expanding NGL systems. The West Texas LPG and Mesquite pipelines access NGL supply from producers actively developing the Delaware, Midland and Central Basins in the Permian Basin, in addition to the Barnett Shale, East Texas and north Louisiana regions.

Sage Creek Acquisition - On September 30, 2013, ONEOK Partners completed the Sage Creek acquisition for $305 million of certain natural gas gathering and processing, and natural gas liquids facilities in Converse and Campbell counties, Wyoming, in the NGL-rich Niobrara Shale formation of the Powder River Basin. The Sage Creek acquisition consists primarily of a 50 MMcf/d natural gas processing facility, the Sage Creek plant, and related natural gas gathering and natural gas liquids infrastructure. Included in the acquisition were supply contracts providing for long-term acreage dedications from producers in the area, which are structured with POP and fee-based contractual terms.

ONEOK Partners accounted for this acquisition as a business combination, which, among other things, requires assets acquired and liabilities assumed to be measured at their acquisition-date fair values. ONEOK Partners allocated $152 million to the Natural Gas Gathering and Processing segment, and allocated $153 million to the Natural Gas Liquids Segment. The excess of the purchase price over the fair values of the identifiable assets acquired of $92 million was recorded as goodwill.

Revenues and earnings related to the Sage Creek acquisition are included within the Consolidated Statement of Income since the acquisition dates. Supplemental pro forma revenue and earnings reflecting this acquisition as if it had occurred as of January 1, 2013, are not materially different from the information presented in the accompanying Consolidated Statement of Income and are, therefore, not presented.

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

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

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

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

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

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



	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2014		2013		2014		2013
	(Thousands of dollars)
Revenues	$	—	$	81,324	$	53,526	$	255,298
Expenses
Cost of sales and fuel	$	—	$	9,562	$	10,835	$	27,855
Administrative and general expenses	84,221		58,549		240,172		192,906
Total expenses	$	84,221	$	68,111	$	251,007	$	220,761

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


M.	COMMITMENTS AND CONTINGENCIES

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

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existing environmental statutes and regulations will not be revised or that new regulations will not be adopted or become applicable to it.

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

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

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

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

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

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


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


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


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


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

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

Legal Proceedings - Gas Index Pricing Litigation - As previously reported, ONEOK and its subsidiary, ONEOK Energy Services Company L.P. (OESC), along with several other energy companies, are defending multiple lawsuits arising from alleged market manipulation or false reporting of natural gas prices to natural gas-index publications. On April 10, 2013, the United States Court of Appeals for the Ninth Circuit reversed the summary judgments that had been granted in favor of ONEOK, OESC and other unaffiliated defendants in the following cases: Reorganized FLI, Learjet, Arandell, Heartland and NewPage. The Ninth Circuit also reversed the summary judgment that had been granted in favor of OESC on all state law claims asserted in the Sinclair case. ONEOK, OESC and the other unaffiliated defendants filed a Petition for Writ of Certiorari with the United States Supreme Court on August 26, 2013, seeking review of the Ninth Circuit decision. On July 1, 2014, the United States Supreme Court granted the the Petition for Writ of Certiorari. We expect a decision by mid 2015.

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

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

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

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


N.	SEGMENTS

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


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


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


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

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

Following the separation of our natural gas distribution business into ONE Gas and wind down of our energy services business, our chief operating decision maker reviews the financial performance of each of the three businesses of ONEOK Partners on a regular basis to assess the performance of, and allocate resources to, ONEOK Partners. As a result, effective for the first quarter 2014, our reportable segments have changed to reflect the three business segments of ONEOK Partners. Prior periods presented have been recast to conform to the current presentation.

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

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

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

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



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

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

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

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Three Months Ended	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)			Other and Eliminations (c)			Total
September 30, 2013	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)			Other and Eliminations (c)			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	162,677	$	2,840,108	$	50,624		$	648		$	3,054,057
Sales to affiliated customers	57,400		—		23,924			—			81,324
Intersegment revenues	312,940		34,740		1,330			(349,010		)	—
Total revenues	$	533,017	$	2,874,848	$	75,878		$	(348,362	)	$	3,135,381
Net margin	$	130,882	$	226,242	$	69,457		$	(2,359	)	$	424,222
Operating costs	45,074		57,010		23,457			5,460			131,001
Depreciation and amortization	27,356		22,993		10,833			668			61,850
Gain (loss) on sale of assets	31		7		(16		)	(1		)	21
Operating income	$	58,483	$	146,246	$	35,151		$	(8,488	)	$	231,392
Equity earnings from investments	$	4,668	$	6,336	$	16,464		$	—		$	27,468
Capital expenditures	$	204,542	$	230,780	$	11,148		$	91,017		$	537,487

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $147.1 million, of which $130.2 million was related to sales within the segment, net margin of $89.5 million and operating income of $53.4 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $57.5 million, net margin of $52.8 million and operating income of $22.6 million.



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

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

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

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

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Nine Months Ended	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)			Other and Eliminations (c)			Total
September 30, 2013	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)			Other and Eliminations (c)			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	466,631	$	7,539,470	$	158,960		$	1,961		$	8,167,022
Sales to affiliated customers	179,636		—		75,662			—			255,298
Intersegment revenues	806,523		91,161		2,327			(900,011		)	—
Total revenues	$	1,452,790	$	7,630,631	$	236,949		$	(898,050	)	$	8,422,320
Net margin	$	365,436	$	632,087	$	211,224		$	(660	)	$	1,208,087
Operating costs	141,737		171,076		75,608			9,480			397,901
Depreciation and amortization	76,366		65,033		32,687			1,930			176,016
Gain (loss) on sale of assets	344		10		(12		)	(1		)	341
Operating income	$	147,677	$	395,988	$	102,917		$	(12,071	)	$	634,511
Equity earnings from investments	$	16,228	$	15,383	$	48,133		$	—		$	79,744
Investments in unconsolidated affiliates	$	331,124	$	494,702	$	376,047		$	—		$	1,201,873
Total assets	$	3,808,135	$	6,610,205	$	1,786,413		$	5,405,590		$	17,610,343
Noncontrolling interests in consolidated subsidiaries	$	4,574	$	—	$	—		$	2,496,378		$	2,500,952
Capital expenditures	$	574,509	$	774,284	$	22,497		$	226,530		$	1,597,820

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $376.9 million, of which $321.3 million was related to sales within the segment, net margin of $227.8 million and operating income of $129.0 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $182.0 million, net margin of $162.5 million and operating income of $67.0 million.

(c) - Other and Eliminations includes assets and capital expenditures of discontinued operations of $4.0 billion and $206.4 million, respectively.

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

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

RECENT DEVELOPMENTS

ONEOK and its subsidiaries continue to own all of the general partner interest and a portion of the limited partner interests, which, together, represent a 38.3 percent ownership interest at September 30, 2014, in ONEOK Partners (NYSE: OKS), one of the largest publicly traded master limited partnerships.

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

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

Wind Down of Energy Services Business - We completed the accelerated wind down of our energy services business which ceased operations on March 31, 2014, and was classified as discontinued operations. The energy services business generated net losses of approximately $0.2 million and $9.0 million for the three and nine months ended September 30, 2014, respectively. See additional discussion in Note B.

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

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

Commodity prices, particularly crude oil and NGL products, decreased in the three months ended September 30, 2014, due to increased supply and global economic conditions. ONEOK Partners expects the lower commodity prices to continue through 2015, which ONEOK Partners expects will impact its net realized prices for natural gas, NGLs and condensate and its financial results. However, ONEOK Partners does not anticipate that the lower commodity prices will result in reduced drilling activity in the basins in which ONEOK Partners operates or demand for NGL products from the petrochemical industry.

When economic conditions warrant, certain natural gas processors elect not to recover the ethane component in the natural gas stream, also known as ethane rejection, and instead leave the ethane component in the natural gas stream sold at the tailgate of natural gas processing plants. Natural gas prices were favorable to ethane prices on a Btu basis, which resulted in ethane

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rejection at most of ONEOK Partners’ natural gas processing plants and many of its customers’ natural gas processing plants connected to its natural gas liquids gathering system in the Mid-Continent and Rocky Mountain regions during 2013 and the first nine months of 2014, which reduced natural gas liquids volumes gathered and fractionated in the Natural Gas Liquids segment and reduced its results of operations.

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

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

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

ONEOK Partners’ Growth Projects - Crude oil and natural gas producers continue to drill aggressively for crude oil and NGL-rich natural gas in many regions where ONEOK Partners has operations. ONEOK Partners expects continued development of the crude oil and NGL-rich natural gas reserves in the Bakken Shale and Three Forks formations in the Williston Basin, the Niobrara Shale and other formations in the Powder River Basin and in the Cana-Woodford Shale, Woodford Shale, Granite Wash, Mississippian Lime, Springer Shale, Stack and SCOOP areas in the Mid-Continent region. In response to this increased production of crude oil, natural gas and NGLs, and higher demand for NGL products from the petrochemical industry, ONEOK Partners is investing approximately $8.3 billion to $9.0 billion in new capital projects and acquisitions from 2010 through 2016 to meet the needs of natural gas producers and processors in these regions, as well as enhance its natural gas liquids fractionation, distribution and storage infrastructure in the Gulf Coast region. The execution of these capital investments aligns with ONEOK Partners’ strategy to grow fee-based earnings. Acreage dedications and contractual commitments from producers and natural gas processors in regions associated with ONEOK Partners’ growth projects are expected to provide incremental cash flows and long-term fee-based earnings.

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

West Texas LPG Acquisition - In October 2014, ONEOK Partners announced that it has agreed to acquire an 80 percent interest in the West Texas LPG Pipeline Limited Partnership and 100 percent interest in the Mesquite Pipeline for approximately $800 million from affiliates of Chevron Corporation. We expect to close the transaction in the fourth quarter 2014. See additional discussion in the “Financial Results and Operating Information” section in the Natural Gas Liquids segment.

Bighorn Gas Gathering Impairment Charge - As a result of the continued decline in dry natural gas volumes gathered in the coal-bed methane area of the Powder River Basin and impairment of the underlying assets of Bighorn Gas Gathering in September 2014, ONEOK Partners reviewed its equity method investment in Bighorn Gas Gathering as of September 30, 2014,

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and recorded noncash impairment charges totaling $76.4 million. See additional discussion in the “Financial Results and Operating Information” section in the Natural Gas Gathering and Processing segment.

Dividends/Distributions - We declared a quarterly dividend of $0.59 per share ($2.36 per share on an annualized basis) in October 2014. ONEOK Partners declared a cash distribution of $0.775 per unit ($3.10 per unit on an annualized basis) in October 2014 for the third quarter 2014, an increase of 1.5 cents from the previous quarter. The quarterly dividend and distribution will be paid November 14, 2014, to shareholders and unitholders of record at the close of business on November 3, 2014.

FINANCIAL RESULTS AND OPERATING INFORMATION

Consolidated Operations

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



	Three Months Ended						Nine Months Ended						Three Months					Nine Months
	September 30,						September 30,						2014 vs. 2013					2014 vs. 2013
Financial Results	2014			2013			2014			2013			Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
Revenues
Commodity sales	$	2,754.5		$	2,807.3		$	8,276.3		$	7,453.5		$	(52.8	)	(2	)%	$	822.8		11	%
Services	365.6			328.1			1,074.0			968.8			37.5			11	%	105.2			11	%
Total revenues	3,120.1			3,135.4			9,350.3			$	8,422.3		(15.3		)	—	%	928.0			11	%
Cost of sales and fuel	2,583.2			2,711.2			7,807.3			7,214.2			(128.0		)	(5	)%	593.1			8	%
Net margin	536.9			424.2			1,543.0			1,208.1			112.7			27	%	334.9			28	%
Operating costs	172.4			131.0			493.6			397.9			41.4			32	%	95.7			24	%
Depreciation and amortization	74.6			61.9			214.1			176.0			12.7			21	%	38.1			22	%
Gain (loss) on sale of assets	1.5			0.1			1.5			0.3			1.4			*		1.2			*
Operating income	$	291.4		$	231.4		$	836.8		$	634.5		$	60.0		26	%	$	202.3		32	%
Equity earnings (loss) from investments	$	(52.3	)	$	27.5		$	6.7		$	79.7		$	(79.8	)	*		$	(73.0	)	(92	)%
Interest expense	$	(86.1	)	$	(66.2	)	$	(269.7	)	$	(196.8	)	$	19.9		30	%	$	72.9		37	%
Income from continuing operations	$	114.5		$	157.8		$	467.9		$	422.1		$	(43.3	)	(27	)%	$	45.8		11	%
Net income attributable to noncontrolling interests	$	49.8		$	85.3		$	242.0		$	217.1		$	(35.5	)	(42	)%	$	24.9		11	%
Net income attributable to ONEOK	$	64.5		$	62.4		$	219.6		$	175.8		$	2.1		3	%	$	43.8		25	%
Capital expenditures (a)	$	382.2		$	537.5		$	1,204.4		$	1,597.8		$	(155.3	)	(29	)%	$	(393.4	)	(25	)%

* Percentage change is greater than 100 percent.

(a) - Includes capital expenditures of discontinued operations of $23.9 million for the nine months ended September, 30, 2014, $83.8 million for the three months ended September 30, 2013, and $206.4 million for the nine months ended September 30, 2013.

Commodity sales revenues increased for the nine months ended September 30, 2014, compared with the same period in 2013, due to higher natural gas and NGL volumes from ONEOK Partners’ recently completed capital projects, increased optimization and marketing activities from wider NGL product price differentials and seasonal propane demand in the first quarter 2014, and higher isomerization volumes due to wider normal butane and iso-butane differentials in the Natural Gas Liquids segment, and higher realized prices in the Natural Gas Gathering and Processing segment.

Services revenues increased for the three and nine months ended September 30, 2014, compared with the same periods in 2013, due to higher natural gas and NGL volumes from ONEOK Partners’ recently completed capital projects in the Natural Gas Gathering and Processing and Natural Gas Liquids segments. Services revenues also increased in the Natural Gas Pipelines segment for these periods due to higher transportation revenues due to increased rates and higher volumes. The nine-month period also realized higher transportation revenues in the Natural Gas Pipelines segment due to increased park-and-loan services as a result of weather-related seasonal demand during the first quarter. These increases were offset partially by increased ethane rejection in the Natural Gas Liquids segment and lower storage revenues from lower contracted capacity in the Natural Gas Pipelines segment.

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

Equity earnings from investments decreased for the three and nine months ended September 30, 2014, compared with the same periods in 2013, due primarily to noncash impairment charges totaling $76.4 million related to ONEOK Partners’ equity method investment in Bighorn Gas Gathering in the Natural Gas Gathering and Processing segment.

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

Net income attributable to noncontrolling interests, which reflects primarily the portion of ONEOK Partners that we do not own, decreased for the three months ended September 30, 2014, and increased for the nine months ended September 30, 2014, compared with the same periods in 2013, due primarily to the changes in earnings at ONEOK Partners. The increases in the distributions declared by ONEOK Partners in the three and nine months ended September 30, 2014, compared with the same periods in 2013, increased the incentive distributions to us which further decreased net income attributable to noncontrolling interests for the three months ended September 30, 2014 and partially offset the increase in net income attributable to noncontrolling interests for the nine months ended September 30, 2014.

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

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

Natural Gas Gathering and Processing

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

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

The significant growth in the development of crude oil and NGL-rich natural gas in the Williston Basin has caused natural gas production to exceed the capacity of existing natural gas gathering and processing infrastructure, which results in the flaring of natural gas (the controlled burning of natural gas at the wellhead). In July 2014, the North Dakota Industrial Commission approved a policy designed to limit flaring at existing and future crude oil wells in the Bakken and Three Forks formations in the Williston Basin. The policy establishes crude oil production limits that will take effect if a producer fails to meet requirements to capture natural gas at the wellhead. ONEOK Partners is constructing additional natural gas gathering

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pipelines, compression and processing plants, and natural gas liquids pipeline capacity that are expected to help alleviate capacity constraints. ONEOK Partners is evaluating the potential impact the new regulation might have on future crude oil and natural gas production and the natural gas volumes it gathers and processes in the Williston Basin.

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

ONEOK Partners expects its capital projects will continue to generate additional revenues, earnings and cash flows as they are completed. ONEOK Partners expects its natural gas liquids and natural gas commodity-price sensitivity within this segment to increase in the future as its capital projects are completed and volumes increase under POP contracts with a fee-based component with its customers. ONEOK Partners uses commodity derivative instruments and physical-forward contracts to mitigate its sensitivity to fluctuations in the natural gas, crude oil and NGL prices received for its share of volumes.

Growth Projects - The Natural Gas Gathering and Processing segment is investing approximately $4.2 billion to $4.8 billion from 2010 through 2016 in growth projects in NGL-rich areas in the Williston Basin, the Powder River Basin, the Cana-Woodford Shale, the Springer Shale, the Stack and the SCOOP areas that it expects will enable it to meet the rapidly growing needs of crude oil and natural gas producers in those areas. Nearly all of the new natural gas production is from horizontally drilled and completed wells in nonconventional resource areas. These wells tend to produce volumes at higher initial production rates resulting generally in higher initial decline rates than conventional vertical wells; however, the decline rates flatten out over time. These wells are expected to have long productive lives.

ONEOK Partners has completed approximately $2.3 billion of the growth projects and acquisitions in this segment from 2010 through October 2014, which include the following:



Completed Projects	Location	Capacity	Approximate Costs (a)	Completion Date
			(In millions)
Rocky Mountain Region
Garden Creek I processing plant and infrastructure	Williston Basin	100 MMcf/d	$360	December 2011
Stateline I & II processing plants and infrastructure	Williston Basin	200 MMcf/d	$565	September 2012/April 2013
Divide County gathering system	Williston Basin	270 miles	$125	June 2013
Sage Creek processing plant and infrastructure (b)	Powder River Basin	50 MMcf/d	$152	September 2013
Garden Creek II processing plant and infrastructure	Williston Basin	100 MMcf/d	$310-$345	August 2014
Garden Creek III processing plant and infrastructure	Williston Basin	100 MMcf/d	$325-$360	October 2014
Mid-Continent Region
30 percent interest in Maysville processing plant (b)	Cana-Woodford Shale	40 MMcf/d	$90	December 2013
Canadian Valley processing plant and infrastructure	Cana-Woodford Shale	200 MMcf/d	$300	March 2014
Total			$2,227-$2,297

(a) Excludes AFUDC.

(b) Acquisition.

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



Projects in Progress	Location	Capacity	Approximate Costs (a)	Expected Completion Date
			(In millions)
Rocky Mountain Region
Lonesome Creek processing plant and infrastructure	Williston Basin	200 MMcf/d	$550-$680	Fourth quarter 2015
Sage Creek infrastructure	Powder River Basin	Various	$50	Fourth quarter 2015
Natural gas compression	Williston Basin	100 MMcf/d	$80-$100	Fourth quarter 2015
Bear Creek processing plant and infrastructure	Williston Basin	80 MMcf/d	$230-$330	Second quarter 2016
Demicks Lake processing plant and infrastructure	Williston Basin	200 MMcf/d	$515-$670	Third quarter 2016
Bronco processing plant and infrastructure	Powder River Basin	100 MMcf/d	$170-$245	Third quarter 2016
Mid-Continent Region
Knox processing plant and infrastructure	SCOOP	200 MMcf/d	$365-$470	Fourth quarter 2016
Total			$1,960-$2,545

(a) Excludes AFUDC.

Rocky Mountain Region:

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

Garden Creek II Plant - The Garden Creek II natural gas processing plant was completed in August 2014.

Garden Creek III Plant - The Garden Creek III natural gas processing plant, originally scheduled for completion in the first quarter 2015, was completed in October 2014.

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

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

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

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

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

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

Bronco Plant - In September 2014, ONEOK Partners announced it will construct the Bronco natural gas processing plant and related natural gas gathering and natural gas liquids infrastructure in Campbell and Converse counties, Wyoming.

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Mid-Continent Region:

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

Canadian Valley Plant - In March 2014, ONEOK Partners completed the Canadian Valley natural gas processing plant, which is located in the Cana-Woodford Shale.

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

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

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

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

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



	Three Months Ended					Nine Months Ended					Three Months					Nine Months
	September 30,					September 30,					2014 vs. 2013					2014 vs. 2013
Financial Results	2014			2013		2014			2013		Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
NGL sales	$	394.1		$	299.6	$	1,128.8		$	763.6	$	94.5		32	%	$	365.2		48	%
Condensate sales	24.5			23.8		82.0			84.7		0.7			3	%	(2.7		)	(3	%)
Residue natural gas sales	284.0			153.0		849.4			442.7		131.0			86	%	406.7			92	%
Gathering, compression, dehydration and processing fees and other revenue	75.2			56.6		203.1			161.8		18.6			33	%	41.3			26	%
Cost of sales and fuel	599.6			402.1		1,776.6			1,087.4		197.5			49	%	689.2			63	%
Net margin	178.2			130.9		486.7			365.4		47.3			36	%	121.3			33	%
Operating costs	64.3			45.1		188.5			141.7		19.2			43	%	46.8			33	%
Depreciation and amortization	31.3			27.4		89.6			76.4		3.9			14	%	13.2			17	%
Gain on sale of assets	0.3			0.1		0.3			0.4		0.2			*		(0.1		)	(25	%)
Operating income	$	82.9		$	58.5	$	208.9		$	147.7	$	24.4		42	%	$	61.2		41	%
Equity earnings (loss) from investments	$	(71.1	)	$	4.7	$	(60.5	)	$	16.2	$	(75.8	)	*		$	(76.7	)	*
Capital expenditures	$	214.9		$	204.5	$	506.0		$	574.5	$	10.4		5	%	$	(68.5	)	(12	%)

* Percentage change is greater than 100 percent

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


•	an increase of $50.0 million due primarily to natural gas volume growth in the Williston Basin and Cana-Woodford Shale and increased ownership of the Maysville, Oklahoma, natural gas processing plant resulting in higher natural gas volumes gathered, compressed, processed, transported and sold, and higher NGL volumes sold, and higher fees; and


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


•	a decrease of $6.1 million due primarily to lower net realized NGL and condensate prices.

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

•

an increase of $111.4 million due primarily to natural gas volume growth in the Williston Basin and Cana-Woodford Shale and increased ownership of the Maysville, Oklahoma, natural gas processing plant resulting in higher natural gas volumes gathered, compressed, processed, transported and sold, higher NGL volumes sold and higher fees, offset partially by wellhead freeze-offs due to severely cold weather in the first quarter 2014;


•	an increase of $8.5 million due primarily to changes in contract mix; and


•	an increase of $7.8 million due primarily to higher net realized natural gas and NGL prices; offset partially by


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

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


•	an increase of $10.9 million and $32.3 million, respectively, due to higher materials and supplies, and outside services expenses; and


•	an increase of $8.5 million and $17.3 million, respectively, in employee-related costs due to higher labor and employee benefit costs.

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

Equity earnings (loss) from investments decreased for the three and nine months ended September 30, 2014, compared with the same periods in 2013, due to $76.4 million in impairment charges in the third quarter 2014 on ONEOK Partners’ investment in Bighorn Gas Gathering. See additional discussion in “Equity Investments” below.

Capital expenditures increased for the three months ended September 30, 2014, and decreased for the nine months ended September 30, 2014, compared with the same periods in 2013, due primarily to the timing of expenditures for ONEOK Partners’ growth projects discussed above. During the third quarter 2014, ONEOK Partners connected approximately 420 new wells to its systems compared with approximately 340 in the same period in 2013. For the nine months ended September 30, 2014, ONEOK Partners connected approximately 1,010 wells to its system compared with approximately 950 in the same period in 2013.

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



	Three Months Ended				Nine Months Ended
	September 30,				September 30,
Operating Information (a)	2014		2013		2014		2013
Natural gas gathered (BBtu/d)	1,847		1,389		1,665		1,311
Natural gas processed (BBtu/d) (b)	1,666		1,135		1,462		1,060
NGL sales (MBbl/d)	111		83		100		77
Residue natural gas sales (BBtu/d)	792		521		682		475
Realized composite NGL net sales price ($/gallon) (c)	$	0.93	$	0.90	$	0.97	$	0.87
Realized condensate net sales price ($/Bbl) (c)	$	81.02	$	90.68	$	78.00	$	87.40
Realized residue gas net sales price ($/MMBtu) (c)	$	3.92	$	3.36	$	3.91	$	3.48
Average fee rate ($/MMBtu)	$	0.36	$	0.35	$	0.36	$	0.35

(a) - Includes volumes for consolidated entities only.

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

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

The quantity and composition of NGLs and natural gas continues to change as ONEOK Partners’ new natural gas processing plants in the Williston Basin and Mid-Continent are placed in service. In March 2014, ONEOK Partners’ Canadian Valley plant in Oklahoma was completed, which has better ethane rejection capabilities than its other processing plants in the Mid-Continent region. As a result, ONEOK Partners’ realized composite NGL net sales price for the three months ended September 30, 2014, increased compared with the same period in 2013, while most individual NGL product prices were lower compared with the same period in 2013. ONEOK Partners’ Garden Creek I, Garden Creek II, Stateline I and Stateline II plants in the Williston Basin have the capability to recover ethane when economic conditions warrant but did not do so during the first nine months of 2014. Equity NGL volumes also are expected to be weighted more toward propane, iso-butane, normal butane and natural gasoline due to expected ethane rejection at least through 2016.



	Three Months Ended		Nine Months Ended
	September 30,		September 30,
Equity Volume Information (a)	2014	2013	2014	2013

NGL sales (MBbl/d)	16.0	14.6	16.6	13.8
Condensate sales (MBbl/d)	2.6	2.0	3.1	2.4
Residue natural gas sales (BBtu/d)	134.5	76.8	109.6	67.7

(a) - Includes volumes for consolidated entities only.

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



	Three Months Ending December 31, 2014
	Volumes Hedged	Average Price			Percentage Hedged
NGLs (MBbl/d)	11.3	$	1.17	/ gallon	63%
Condensate (MBbl/d)	2.7	$	2.21	/ gallon	73%
Total (MBbl/d)	14.0	$	1.37	/ gallon	64%
Natural gas (BBtu/d)	96.0	$	4.07	/ MMBtu	73%



	Year Ending December 31, 2015
	Volumes Hedged	Average Price			Percentage Hedged
NGLs (MBbl/d)	1.2	$	1.07	/ gallon	5%
Natural gas (BBtu/d)	61.3	$	4.34	/ MMBtu	41%

ONEOK Partners expects its natural gas liquids and natural gas commodity-price sensitivity within this segment to increase in the future as capital projects are completed and volumes increase under POP contracts with a fee-based component with its customers. The Natural Gas Gathering and Processing segment’s commodity-price sensitivity is estimated as a hypothetical change in the price of NGLs, crude oil and natural gas at September 30, 2014, excluding the effects of hedging and assuming normal operating conditions. Condensate sales are based on the price of crude oil. ONEOK Partners estimates the following:


•	a $0.01 per-gallon change in the composite price of NGLs would change twelve-month forward net margin by approximately $3.1 million;


•	a $1.00 per-barrel change in the price of crude oil would change twelve-month forward net margin by approximately $1.6 million; and


•	a $0.10 per-MMBtu change in the price of residue natural gas would change twelve-month forward net margin by approximately $5.1 million.

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

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

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

During 2014 through the third quarter, the coal-bed methane volumes gathered on the Bighorn Gas Gathering system declined at a rate greater than in prior periods and greater than expected. Due to these additional declines in volumes, Bighorn Gas Gathering recorded an impairment of its underlying assets in September 2014, when the operator determined that the volume decline was other than temporary. As a result of these developments, ONEOK Partners reviewed its equity method investment in Bighorn Gas Gathering for impairment as of September 30, 2014. ONEOK Partners recorded noncash impairment charges of $76.4 million related to Bighorn Gas Gathering. The noncash impairment charges are included in equity earnings (loss) from investments in our accompanying Consolidated Statements of Income. The remaining net book value of ONEOK Partners’ equity method investment in Bighorn Gas Gathering is $8.8 million, and no equity method goodwill remains.

In the near term, a continued decline in volumes gathered in the coal-bed methane area of the Powder River Basin may reduce ONEOK Partners’ ability to recover the carrying value of its equity investments in this area and could result in additional noncash charges to earnings.

Natural Gas Liquids

Overview - The Natural Gas Liquids segment owns and operates facilities that gather, fractionate, treat and distribute NGLs and store NGL products, primarily in Oklahoma, Kansas, Texas and the Rocky Mountain region where it provides nondiscretionary services to producers of NGLs. It owns or has an ownership interest in FERC-regulated natural gas liquids gathering and distribution pipelines in Oklahoma, Kansas, Texas, Montana, North Dakota, Wyoming and Colorado, and terminal and storage facilities in Missouri, Nebraska, Iowa and Illinois. ONEOK Partners also owns FERC-regulated natural gas liquids distribution and refined petroleum products pipelines in Kansas, Missouri, Nebraska, Iowa, Illinois and Indiana that connect its Mid-Continent assets with Midwest markets, including Chicago, Illinois. The majority of the pipeline-connected natural gas processing plants in Oklahoma, Kansas and the Texas Panhandle, which extract unfractionated NGLs from unprocessed natural gas, are connected to its gathering systems. ONEOK Partners owns and operates truck- and rail-loading and -unloading facilities that connect with its NGL fractionation and pipeline assets. In April 2013, ONEOK Partners began transporting unfractionated NGLs from natural gas processing plants in the Williston Basin on its Bakken NGL Pipeline. These unfractionated NGLs previously were transported by rail to its Mid-Continent natural gas liquids fractionation facilities. ONEOK Partners continues to use its rail-terminal facilities in its NGL marketing activities.

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

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


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

•

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


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


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


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

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

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

The Natural Gas Liquids segment is investing approximately $4.1 billion in NGL-related projects from 2010 through 2016. These investments will accommodate the transportation and fractionation of growing NGL supply from shale and other resource development areas across ONEOK Partners’ asset base and alleviate infrastructure constraints between the Mid-Continent and Gulf Coast market centers to meet increasing petrochemical industry and NGL export demand in the Gulf Coast. Over time, these growing fee-based NGL volumes are expected to fill much of ONEOK Partners’ natural gas liquids pipeline capacity used historically to capture the NGL location price differentials between the two market centers.

ONEOK Partners has completed approximately $2.4 billion in growth projects in this segment from 2010 through October 2014, which include the following:



Completed Projects	Capacity	Approximate Costs (a)	Completion Date
		(In millions)
Sterling I expansion	15 MBbl/d	$30	November 2011
Cana-Woodford/Granite Wash NGL plant connections	60 MBbl/d	$220	April 2012
Bushton fractionator expansion	60 MBbl/d	$117	September 2012
Bakken NGL Pipeline	60 MBbl/d	$455	April 2013
Overland Pass Pipeline expansion	45 MBbl/d	$36	April 2013
Ethane Header pipeline	250 MBbl/d	$23	April 2013
Sage Creek NGL infrastructure (b)	Various	$153	September 2013
MB-2 Fractionator	75 MBbl/d	$375	December 2013
Ethane/Propane Splitter	40 MBbl/d	$46	March 2014
Sterling III Pipeline and reconfigure Sterling I and II	193 MBbl/d	$808	March 2014
Bakken NGL Pipeline expansion - Phase I	75 MBbl/d	$100	September 2014
Niobrara NGL Lateral	90 miles	$85	September 2014
Total		$2,448

(a) Excludes AFUDC.

(b) Acquisition.

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



Projects in Progress	Capacity	Approximate Costs (a)	Expected Completion Date
		(In millions)
MB-3 Fractionator	75 MBbl/d	$525-$575	Fourth quarter 2014
West Texas LPG System (b)	2,600 miles	$800	Fourth quarter 2014
NGL Pipeline and Hutchinson Fractionator infrastructure	95 miles	$140	First quarter 2015
Bakken NGL Pipeline expansion - Phase II	25 MBbl/d	$100	Second quarter 2016
Bronco NGL infrastructure	65 miles	$45-$60	Third quarter 2016
Bear Creek NGL infrastructure	40 miles	$35-$45	Third quarter 2016
Demicks Lake NGL infrastructure	12 miles	$10-$15	Third quarter 2016
Total		$1,655-$1,735

(a) Excludes AFUDC.

(b) Acquisition.

West Texas LPG Acquisition - In October 2014, ONEOK Partners announced that it has agreed to acquire an 80 percent interest in the West Texas LPG Pipeline Limited Partnership (West Texas LPG) and 100 percent interest in the Mesquite Pipeline (Mesquite) for approximately $800 million from affiliates of Chevron Corporation. We expect the transaction to close by the fourth quarter 2014. Closing is subject to customary conditions including antitrust clearance from the Federal Trade Commission under the Hart-Scott-Rodino Act. Following the closing of the transaction, ONEOK Partners will be the operator of both pipelines. The West Texas LPG and Mesquite systems consist of approximately 2,600 miles of NGL gathering pipelines extending from the Permian Basin in southeastern New Mexico to East Texas and Mont Belvieu, Texas. The West Texas LPG and Mesquite systems will increase ONEOK Partners’ NGL gathering system by approximately 60 percent to nearly 6,900 miles of NGL gathering pipelines and initially add approximately 230,000 bpd of NGL supply. ONEOK Partners plans to invest approximately $500 million, excluding AFUDC, between 2015 and 2019 to expand the capacity of the systems. These assets are expected to provide ONEOK Partners additional fee-based earnings and its NGL infrastructure with access to a new NGL supply basin.

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

Sterling I and Sterling II pipelines to transport either unfractionated NGLs or NGL products. The reconfiguration was completed in July 2014.

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

Bakken NGL Pipeline expansions - The first expansion completed in September 2014 increased the pipeline’s capacity to 135 MBbl/d from the original capacity of 60 MBbl/d, with the second expansion expected to bring the pipeline’s capacity to 160 MBbl/d. These expansions will accommodate the growing NGL supply from the Williston and Powder River Basins.

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

Niobrara NGL Lateral - ONEOK Partners constructed new natural gas liquids pipeline infrastructure to connect the Sage Creek natural gas processing plant to its Bakken NGL Pipeline, which was completed in September 2014.

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

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

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

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

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

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



	Three Months Ended					Nine Months Ended					Three months					Nine Months
	September 30,					September 30,					2014 vs. 2013					2014 vs. 2013
Financial Results	2014			2013		2014			2013		Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
NGL and condensate sales	$	2,450.2		$	2,642.9	$	7,341.0		$	6,960.5	$	(192.7	)	(7	%)	$	380.5		5	%
Exchange service and storage revenues	265.0			215.9		710.9			617.3		49.1			23	%	93.6			15	%
Transportation revenues	19.3			16.0		59.7			52.8		3.3			21	%	6.9			13	%
Cost of sales and fuel	2,451.5			2,648.6		7,293.5			6,998.5		(197.1		)	(7	%)	295.0			4	%
Net margin	283.0			226.2		818.1			632.1		56.8			25	%	186.0			29	%
Operating costs	77.0			57.0		218.2			171.1		20.0			35	%	47.1			28	%
Depreciation and amortization	31.7			23.0		89.8			65.0		8.7			38	%	24.8			38	%
Loss on sale of assets	(0.5		)	—		(0.6		)	—		(0.5		)	*		(0.6		)	*
Operating income	$	173.8		$	146.2	$	509.5		$	396.0	$	27.6		19	%	$	113.5		29	%
Equity earnings from investments	$	4.4		$	6.3	$	13.6		$	15.4	$	(1.9	)	(30	%)	$	(1.8	)	(12	%)
Capital expenditures	$	153.8		$	230.8	$	637.5		$	774.3	$	(77.0	)	(33	%)	$	(136.8	)	(18	%)

* Percentage change is greater than 100 percent

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

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

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


•	an increase of $53.0 million in exchange-services margins, which resulted primarily from increased volumes from new plants connected in the Williston Basin and Mid-Continent region, and higher fees for exchange-services activities resulting from contract renegotiations, offset partially by lower volumes from the termination of a contract; and


•	an increase of $11.7 million in optimization and marketing margins, which resulted from a $8.7 million increase in margins due primarily to marketing and truck and rail activities, and a $7.5 million increase due primarily to wider NGL product price differentials; offset by a decrease of $4.5 million due primarily to lower optimization volumes; offset partially by


•	a decrease of $5.6 million resulting from the impact of ethane rejection, which resulted in lower NGL volumes.

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


•	an increase of $92.4 million in exchange-services margins, which resulted primarily from increased volumes from new plants connected in the Williston Basin and Mid-Continent region, and higher fees for exchange-services activities resulting from contract renegotiations, offset partially by lower volumes from the termination of a contract;

•

an increase of $84.1 million in optimization and marketing margins, which resulted from a $33.7 million increase due primarily to wider NGL product price differentials; a $26.7 million increase in marketing margins related primarily to increased weather-related seasonal demand for propane during the first quarter 2014, and marketing and truck and rail activities in the second and third quarters 2014; and a $23.7 million increase due primarily to significantly wider NGL location price differentials, primarily related to increased weather-related seasonal demand for propane during the first quarter 2014;


•	an increase of $18.7 million related to higher isomerization volumes, resulting from the wider NGL product price differential between normal butane and iso-butane; and


•	an increase of $4.5 million in storage margins due primarily to contract renegotiations; offset partially by


•	a decrease of $9.4 million resulting from the impact of ethane rejection, which resulted in lower NGL volumes; and


•	a decrease of $5.0 million due to the impact of lower operational measurement gains.

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


•	an increase of $7.5 million and $12.5 million, respectively, due to higher employee-related costs due primarily to higher labor and employee benefit costs;


•	an increase of $5.9 million and $16.9 million, respectively, due to higher outside services expenses associated primarily with scheduled maintenance and the growth of ONEOK Partners’ operations related to its completed capital projects;


•	an increase of $3.3 million and $9.9 million, respectively, due to higher ad valorem taxes related to completed capital projects; and


•	an increase of $1.3 million and $2.7 million, respectively, due to higher chemical, materials and supplies expense.

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

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

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

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



	Three Months Ended				Nine Months Ended
	September 30,				September 30,
Operating Information	2014		2013		2014		2013
NGL sales (MBbl/d)	626		686		598		647
NGLs transported-gathering lines (MBbl/d) (a)	529		574		508		542
NGLs fractionated (MBbl/d) (b)	553		557		515		535
NGLs transported-distribution lines (MBbl/d) (a)	377		454		412		426
Average Conway-to-Mont Belvieu OPIS price differential - ethane in ethane/propane mix ($/gallon)	$	0.03	$	0.04	$	0.06	$	0.04

(a) - Includes volumes for consolidated entities only.

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

NGLs transported on gathering lines and NGLs fractionated decreased for the three and nine months ended September 30, 2014, compared with the same periods in 2013, due primarily to the termination of a contract and increased ethane rejection in the Mid-Continent and Rocky Mountain regions, offset partially by volumes from new plants connected in the Williston Basin and Mid-Continent region.

NGLs transported on distribution lines decreased for the three months ended September 30, 2014, compared with the same period in 2013, due primarily to lower volumes transported for ONEOK Partners’ optimization business due to narrow location price differentials between the Conway and Mont Belvieu market centers and increased ethane rejection, offset partially by an increase in volumes delivered to Mont Belvieu for ONEOK Partners’ fee-based contracts due to the completed Sterling III Pipeline, which was placed into service in March 2014.

NGLs transported on distribution lines decreased for the nine months ended September 30, 2014, compared with the same period in 2013, due primarily to lower volumes transported for ONEOK Partners’ optimization business due to narrower location price differentials during the second and third quarters 2014 between the Conway and Mont Belvieu market centers and increased ethane rejection, offset partially by an increase in exchange services volumes delivered to Mont Belvieu due to the completed Sterling III Pipeline, which was placed into service in March 2014, and higher NGL volumes, primarily propane, during the first quarter 2014, transported to the Mid-Continent region due to increased demand.

Natural Gas Pipelines

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

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


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

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


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


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

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

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

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

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

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



	Three Months Ended				Nine Months Ended				Three Months					Nine Months
	September 30,				September 30,				2014 vs. 2013					2014 vs. 2013
Financial Results	2014		2013		2014		2013		Increase (Decrease)					Increase (Decrease)
	(Millions of dollars)
Transportation revenues	$	64.3	$	55.6	$	204.7	$	171.2	$	8.7		16	%	$	33.5		20	%
Storage revenues	12.6		17.6		48.6		52.6		(5.0		)	(28	%)	(4.0		)	(8	%)
Gas sales and other revenues	2.2		2.7		12.6		13.1		(0.5		)	(19	%)	(0.5		)	(4	%)
Cost of sales	5.7		6.4		23.5		25.7		(0.7		)	(11	%)	(2.2		)	(9	%)
Net margin	73.4		69.5		242.4		211.2		3.9			6	%	31.2			15	%
Operating costs	28.0		23.5		82.8		75.6		4.5			19	%	7.2			10	%
Depreciation and amortization	10.9		10.8		32.6		32.7		0.1			1	%	(0.1		)	—	%
Gain on sale of assets	1.7		—		1.7		—		1.7			*		1.7			*
Operating income	$	36.2	$	35.2	$	128.7	$	102.9	$	1.0		3	%	$	25.8		25	%
Equity earnings from investments	$	14.4	$	16.5	$	53.7	$	48.1	$	(2.1	)	(13	%)	$	5.6		12	%
Capital expenditures	$	10.7	$	11.1	$	26.0	$	22.5	$	(0.4	)	(4	%)	$	3.5		16	%
Cash paid for acquisitions	$	—	$	—	$	14.0	$	—	$	—		—	%	$	14.0		*

* Percentage change is greater than 100 percent.

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


•	an increase of $7.7 million due to higher transportation revenues primarily from increased rates on ONEOK Partners’ intrastate pipelines, higher rates and contracted capacity on Midwestern Gas Transmission Company and increased interruptible transportation revenues from higher natural gas volumes transported; and


•	an increase of $1.0 million from additional storage services to meet utility customers’ peak-day demand; offset partially by


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

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


•	an increase of $21.5 million due to higher transportation revenues primarily from increased rates on ONEOK Partners’ intrastate pipelines, higher contracted capacity and rates on Midwestern Gas Transmission Company and increased interruptible transportation revenues from higher natural gas volumes transported;


•	an increase of $6.0 million from increased short-term natural gas storage services due to increased park-and-loan services as a result of weather-related seasonal demand primarily in the first quarter 2014;


•	an increase of $5.9 million from higher net retained fuel due to higher natural gas prices and additional natural gas volumes retained;


•	an increase of $5.0 million due to increased park-and-loan services on ONEOK Partners’ interstate pipelines as a result of weather-related seasonal demand in the first quarter 2014; and


•	an increase of $2.6 million primarily from additional storage services to meet utility customers’ peak-day demand; offset partially by


•	a decrease of $10.0 million due to lower storage revenues from lower contracted capacity.

Operating costs increased for the three and nine months ended September 30, 2014, compared with the same periods in 2013, primarily as a result of increased employee-related costs due to higher labor and employee benefit costs, as well as higher expenditures for outside services associated with scheduled maintenance and higher materials and supplies expenses.

Gain on sale of assets increased for the three and nine months ended September 30, 2014, compared with the same periods in 2013, as a result of an excess pad gas sale.

Equity earnings from ONEOK Partners’ investments decreased for the three months ended September 30, 2014, compared with the same period in 2013, due primarily to lower contracted capacity.

Equity earnings from ONEOK Partners’ investments increased for the nine months ended September 30, 2014, compared with the same period in 2013, due primarily to increased park-and-loan services on Northern Border Pipeline as a result of increased weather-related seasonal demand in the first quarter 2014, offset partially by lower contracted capacity in the third quarter 2014.

Capital expenditures increased for the nine months ended September 30, 2014, compared with the same period in 2013, due primarily to system improvements.

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



	Three Months Ended						Nine Months Ended
	September 30,						September 30,
Operating Information (a)	2014			2013			2014			2013
Natural gas transportation capacity contracted (MDth/d)	5,725			5,428			5,760			5,486
Transportation capacity subscribed	90		%	89		%	91		%	90		%
Average natural gas price
Mid-Continent region ($/MMBtu)	$	3.77		$	3.42		$	4.58		$	3.56

(a) - Includes volumes for consolidated entities only.

ONEOK Partners’ natural gas pipelines primarily serve end users, such as natural gas distribution and electric-generation companies that require natural gas to operate their businesses regardless of location price differentials. The development of shale and other resource areas has continued to increase available natural gas supply resulting in narrower location and seasonal

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

In August 2014, Viking Gas Transmission Company filed a prefiling “Stipulation and Agreement in Resolutions of All Issues Concerning Adjustment in Rates of Viking Gas Transmission Company” (settlement) with the FERC. The settlement was approved on October 1, 2014, as filed, and became final on October 31, 2014. Rates under the settlement become effective January 1, 2015, and we do not expect the settlement to materially impact ONEOK Partners.

CONTINGENCIES

Gas Index Pricing Litigation - As previously reported, ONEOK and its subsidiary, ONEOK Energy Services Company L.P. (OESC), along with several other energy companies, are defending multiple lawsuits arising from alleged market manipulation or false reporting of natural gas prices to natural gas-index publications. On April 10, 2013, the United States Court of Appeals for the Ninth Circuit reversed the summary judgments that had been granted in favor of ONEOK, OESC and other unaffiliated defendants in the following cases: Reorganized FLI, Learjet, Arandell, Heartland and NewPage. The Ninth Circuit also reversed the summary judgment that had been granted in favor of OESC on all state law claims asserted in the Sinclair case. ONEOK, OESC and the other unaffiliated defendants filed a Petition for Writ of Certiorari with the United States Supreme Court on August 26, 2013, seeking review of the Ninth Circuit decision. On July 1, 2014, the United States Supreme Court granted the Petition for Writ of Certiorari. We expect a decision by mid 2015.

LIQUIDITY AND CAPITAL RESOURCES

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

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

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

ONEOK - In March 2014, we completed the wind down of our energy services business. We expect future cash expenditures associated with the released transportation and storage capacity from the wind down of our energy services business on an after-tax basis to be approximately $53 million, with approximately $8 million to be paid in the remainder of 2014, $23 million in 2015, $11 million in 2016 and $11 million from 2017 through 2023.

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


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


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


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


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


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


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


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


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

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

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

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

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

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

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

In February 2014, ONEOK repaid all commercial paper outstanding. At September 30, 2014, ONEOK had $2.1 million in letters of credit issued under the ONEOK Credit Agreement and approximately $97.4 million of cash and cash equivalents. ONEOK had approximately $297.9 million of credit available at September 30, 2014, under the ONEOK Credit Agreement.

The ONEOK Credit Agreement is a $300 million revolving credit facility and contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of indebtedness to Consolidated EBITDA (EBITDA, as defined in the ONEOK Credit Agreement) of no more than 4.0 to 1. Upon breach of certain covenants by us in the ONEOK Credit Agreement, amounts outstanding under the ONEOK Credit Agreement, if any, may become due and payable immediately. At September 30, 2014, ONEOK’s ratio of indebtedness to Consolidated EBITDA, was 1.9 to 1, and ONEOK was in compliance with all covenants under the ONEOK Credit Agreement.

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ONEOK Partners Credit Agreement - The total amount of short-term borrowings authorized by the Board of Directors of ONEOK Partners GP, the general partner of ONEOK Partners, is $2.5 billion. At September 30, 2014, ONEOK Partners had no commercial paper outstanding, $14.0 million of letters of credit issued, no borrowings outstanding under the ONEOK Partners Credit Agreement, approximately $54.0 million of cash and approximately $1.7 billion of credit available under the ONEOK Partners Credit Agreement. At September 30, 2014, ONEOK Partners could have issued $3.8 billion of short- and long-term debt to meet its liquidity needs under the most restrictive provisions contained in its various borrowing agreements. Based on the forward LIBOR curve, ONEOK Partners expects interest rates to increase in the next year, compared with interest rates on amounts outstanding during the previous 24 months.

Financing to close the West Texas LPG acquisition is expected to come from ONEOK Partners’ available cash on hand or borrowing under its existing $1.7 billion commercial paper program or its existing $1.7 billion credit facility. See additional discussion of this acquisition in the “Financial Results and Operating Information” section in the Natural Gas Liquids segment.

The ONEOK Partners Credit Agreement contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of indebtedness to adjusted EBITDA (EBITDA, as defined in the ONEOK Partners Credit Agreement, adjusted for all noncash charges and increased for projected EBITDA from certain lender-approved capital expansion projects) of no more than 5.0 to 1. If ONEOK Partners consummates one or more acquisitions in which the aggregate purchase price is $25 million or more, the allowable ratio of indebtedness to adjusted EBITDA will be increased to 5.5 to 1 for the quarter in which the acquisition was completed and the two following quarters. As a result of a pipeline acquisition ONEOK Partners completed in the first quarter 2014, the allowable ratio of indebtedness to adjusted EBITDA increased to 5.5 to 1 through the third quarter 2014. Upon breach of certain covenants by ONEOK Partners in the ONEOK Partners Credit Agreement, amounts outstanding under the ONEOK Partners Credit Agreement, if any, may become due and payable immediately. At September 30, 2014, ONEOK Partners’ ratio of indebtedness to adjusted EBITDA was 3.4 to 1, and ONEOK Partners was in compliance with all covenants under the ONEOK Partners Credit Agreement.

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

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

ONEOK Partners is subject to changes in the debt and equity markets, and there is no assurance it will be able or willing to access the public or private markets in the future. ONEOK Partners may choose to meet its cash requirements by utilizing some combination of cash flows from operations, borrowing under its commercial paper program or its existing 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 result in higher costs or negatively affect their respective credit ratings, among other factors. Based on ONEOK Partners’ general financial condition, market expectations regarding its future earnings and projected cash flows, and ONEOK Partners’ investment-grade credit ratings, we expect ONEOK Partners will be able to meet its cash requirements and maintain its investment-grade credit ratings.

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

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

We recorded a loss on extinguishment of $24.8 million related to the early retirement of long-term debt, which is included in other expense in our Consolidated Statements of Income. We reclassified a loss of $4.6 million, net of tax of $3.1 million, from

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accumulated other comprehensive income (loss) for terminated cash flow hedges related to the debt retirements, which is included in interest expense in our Consolidated Statements of Income.

ONEOK Partners’ Debt Issuances - In September 2013, ONEOK Partners completed an underwritten public offering of $1.25 billion of senior notes, consisting of $425 million, 3.2 percent senior notes due 2018, $425 million, 5.0 percent senior notes due 2023 and $400 million, 6.2 percent senior notes due 2043. A portion of the net proceeds from the offering of approximately $1.24 billion was used to repay amounts outstanding under its commercial paper program, and the balance was used for general partnership purposes, including but not limited to capital expenditures.

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

ONEOK Partners has an “at-the-market” equity program for the offer and sale from time to time of its common units. The program allows ONEOK Partners to offer and sell its common units at prices ONEOK Partners deems appropriate through a sales agent. Sales of common units are made by means of ordinary brokers’ transactions on the NYSE, in block transactions or as otherwise agreed to between ONEOK Partners and the sales agent. ONEOK Partners is under no obligation to offer and sell common units under the program. At September 30, 2014, ONEOK Partners had approximately $19.3 million available for issuance under its existing $300 million registration statement. In August 2014, ONEOK Partners filed a registration statement with the SEC, which was declared effective in September 2014, to register an additional $650 million of common units. ONEOK Partners anticipates using the new shelf capacity to fund a portion of its future equity capital requirements.

During the three months ended September 30, 2014, ONEOK Partners sold approximately 1.4 million common units through its “at-the-market” equity program. The gross proceeds, including ONEOK Partners GP’s contribution to maintain its 2 percent general partner interest in ONEOK Partners, were approximately $82.1 million. Net cash proceeds, after deducting agent commissions and other related costs, were approximately $81.3 million, which were used for general partnership purposes.

During the nine months ended September 30, 2014, ONEOK Partners sold approximately 4.4 million common units through this program. The gross proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, were approximately $249.5 million. Net cash proceeds, after deducting agent commissions and other related costs, were approximately $245.4 million, which were used for general partnership purposes.

As a result of these transactions, our aggregate ownership interest in ONEOK Partners decreased to 38.3 percent at September 30, 2014, from 41.2 percent at December 31, 2013.

In August 2013, ONEOK Partners completed an underwritten public offering of 11.5 million common units at a public offering price of $49.61 per common unit, generating net proceeds of approximately $553.4 million. In conjunction with issuance, we contributed approximately $11.6 million in order to maintain our 2 percent general partner interest in ONEOK Partners. ONEOK Partners used a portion of the proceeds to repay amounts outstanding under its commercial paper program, and the balance was used for general partnership purposes.

During the three months ended March 31, 2013, ONEOK Partners sold 300,000 common units through its “at-the-market” program that resulted in net proceeds, including ONEOK Partners GP’s contribution to maintain our 2 percent general partner interest in ONEOK Partners, of approximately $16.3 million and used the proceeds for general partnership purposes. There were no common units sold through this program in the second or third quarter 2013.

Interest-rate Swaps - ONEOK Partners has entered into forward-starting interest-rate swaps to hedge the variability of interest payments on a portion of forecasted debt issuances that may result from changes in the benchmark interest rate before the debt is issued. At December 31, 2013, ONEOK Partners had forward-starting interest-rate swaps with notional amounts totaling $400 million, which had settlement dates greater than 12 months and are designated as cash flow hedges. In the first quarter 2014, ONEOK Partners entered into forward-starting interest-rate swaps with notional amounts totaling $500 million with settlement dates of less than 12 months that were designated as cash flow hedges.

Capital Expenditures - ONEOK Partners’ capital expenditures are financed typically through operating cash flows, short- and long-term debt and the issuance of equity. Consolidated capital expenditures were $1.2 billion and $1.6 billion for the nine months ending September 30, 2014 and 2013, respectively. Of these amounts, ONEOK Partners’ capital expenditures were $1.2 billion and $1.4 billion for the nine months ended September 30, 2014 and 2013, respectively. Capital expenditures

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

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



2014 Projected Capital Expenditures
	(Millions of dollars)
Natural Gas Gathering and Processing	$	919
Natural Gas Liquids	716
Natural Gas Pipelines	71
Other	19
Total projected capital expenditures	$	1,725

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



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

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

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

If ONEOK Partners’ credit ratings were downgraded, the cost to borrow funds under its commercial paper program or credit agreement would increase, and ONEOK Partners potentially could lose access to the commercial paper market. In the event that ONEOK Partners is unable to borrow funds under its commercial paper program and there has not been a material adverse change in its business, ONEOK Partners would continue to have access to the ONEOK Partners Credit Agreement, which expires in January 2019. An adverse credit rating change alone is not a default under the ONEOK Credit Agreement or the ONEOK Partners Credit Agreement.

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

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

Commodity Prices - ONEOK Partners is subject to commodity-price volatility. Significant fluctuations in commodity prices will affect its overall liquidity due to the impact commodity-price changes have on its cash flows from operating activities, including the impact on working capital for NGLs and natural gas held in storage, margin requirements and certain energy-related receivables. ONEOK Partners believes that its available credit and cash and cash equivalents are adequate to meet liquidity requirements associated with commodity-price volatility. See discussion under “Commodity-Price Risk” in Part I,

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Item 3, Quantitative and Qualitative Disclosures about Market Risk, in this Quarterly Report for information on ONEOK Partners’ hedging activities.

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

CASH FLOW ANALYSIS

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

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



							Variances
	Nine Months Ended						2014 vs. 2013
	September 30,						Increase (Decrease)
	2014			2013			Increase (Decrease)
	(Millions of dollars)
Total cash provided by (used in):
Operating activities	$	870.5		$	1,021.5		$	(151.0	)
Investing activities	(1,192.1		)	(1,880.7		)	688.6
Financing activities	324.3			1,055.1			(730.8		)
Change in cash and cash equivalents	2.7			195.9			(193.2		)
Change in cash and cash equivalents included in discontinued operations	3.1			1.3			1.8
Change in cash and cash equivalents included in continuing operations	5.8			197.2			(191.4		)
Cash and cash equivalents at beginning of period	145.6			579.6			(434.0		)
Cash and cash equivalents at end of period	$	151.4		$	776.8		$	(625.4	)

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

Cash flows from operating activities, before changes in operating assets and liabilities, were approximately $884.5 million for the nine months ended September 30, 2014, compared with $916.5 million for the same period in 2013. The decrease was due primarily to the 2013 operating activities, including the operations of our former natural gas distribution business, which was discontinued effective January 31, 2014, as discussed in Note B, offset partially by higher operating income from ONEOK Partners, as discussed in “Financial Results and Operating Information.”

The changes in operating assets and liabilities decreased operating cash flows by approximately $14.0 million for the nine months ended September 30, 2014, compared with an increase of $105.0 million for the same period in 2013. This change is due primarily to the change in NGL volumes in storage and commodity imbalances, as well as the settlement of liabilities related to the wind down of our former energy services business. This change also is due to the change in accounts receivable, accounts payable and affiliate payables resulting from the timing of receipt of cash from customers and payments to vendors and suppliers, which vary from period to period.

Investing Cash Flows - Cash used in investing activities decreased for the nine months ended September 30, 2014, compared with the same period in 2013, due primarily to the separation of ONE Gas, resulting in lower capital expenditures. Cash used in investing activities at ONEOK Partners decreased due to the timing of expenditures for its growth projects in the Natural Gas Gathering and Processing, and Natural Gas Liquids segments, as well as a ONEOK Partners acquisition in 2013.

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Financing Cash Flows - Cash provided by financing activities decreased for the nine months ended September 30, 2014, as compared with the same period in 2013, due primarily to ONEOK debt retirements, repayment of notes payable, $60 million of cash included in the ONE Gas separation and higher dividends and distributions paid. ONEOK Partners also issued $1.25 billion of senior notes in September 2013. These decreases were offset partially by the issuance of $1.2 billion of ONE Gas debt and higher issuances of ONEOK Partners common units.

REGULATORY, ENVIRONMENTAL AND SAFETY MATTERS

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

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


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


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


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


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

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

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

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

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

In April 2014, the EPA and the United States Army Corps of Engineers proposed a joint rule-making to redefine the definition of “Waters of the United States” under the Clean Water Act. The public comment period on the proposed rule-making remains pending and, as a result, the impact of any such proposed regulatory actions on ONEOK Partners’ projects, facilities and operations is unknown.

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

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monitoring and record-keeping at affected facilities in the crude oil and natural gas industry. ONEOK Partners does not expect these expenditures will have a material impact on its results of operations, financial position or cash flows.

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

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

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

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

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

IMPACT OF NEW ACCOUNTING STANDARDS

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

ESTIMATES AND CRITICAL ACCOUNTING POLICIES

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

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

FORWARD-LOOKING STATEMENTS

Some of the statements contained and incorporated in this Quarterly Report are forward-looking statements as defined under federal securities laws. The forward-looking statements relate to our anticipated financial performance (including projected operating income, net income, capital expenditures, cash flow and projected levels of dividends), liquidity, management’s plans and objectives for our future growth projects and other future operations (including plans to construct additional natural gas and

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natural gas liquids pipelines and processing facilities and related cost estimates), our business prospects, the outcome of regulatory and legal proceedings, market conditions and other matters. We make these forward-looking statements in reliance on the safe harbor protections provided under federal securities legislation and other applicable laws. The following discussion is intended to identify important factors that could cause future outcomes to differ materially from those set forth in the forward-looking statements.

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

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


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


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


•	the capital intensive nature of our businesses;


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


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


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


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


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


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


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


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


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


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


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


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


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


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


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


•	the impact and outcome of pending and future litigation;


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


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


–	competitive conditions in the overall energy market;


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


–	availability of additional storage capacity;

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


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


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


•	the mechanical integrity of facilities operated;


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


•	our ability to control operating costs;


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


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


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


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


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


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


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


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


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


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


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


•	the impact of potential impairment charges;


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


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


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

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


ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

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

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

COMMODITY-PRICE RISK

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

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INTEREST-RATE RISK

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


ITEM 4.	CONTROLS AND PROCEDURES

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

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

PART II - OTHER INFORMATION


ITEM 1.	LEGAL PROCEEDINGS

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


ITEM 1A.	RISK FACTORS

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


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

Not Applicable.


ITEM 3.	DEFAULTS UPON SENIOR SECURITIES

Not Applicable.


ITEM 4.	MINE SAFETY DISCLOSURES

Not Applicable.


ITEM 5.	OTHER INFORMATION

Not Applicable.


ITEM 6.	EXHIBITS

Readers of this report should not rely on or assume the accuracy of any representation or warranty or the validity of any opinion contained in any agreement filed as an exhibit to this Quarterly Report, because such representation, warranty or

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

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



Exhibit No.		Exhibit Description

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

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

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

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

	101.INS	XBRL Instance Document

	101.SCH	XBRL Taxonomy Extension Schema Document

	101.CAL	XBRL Taxonomy Calculation Linkbase Document

	101.DEF	XBRL Taxonomy Extension Definitions Document

	101.LAB	XBRL Taxonomy Label Linkbase Document

	101.PRE	XBRL Taxonomy Presentation Linkbase Document

Attached as Exhibit 101 to this Quarterly Report are the following XBRL-related documents: (i) Document and Entity Information; (ii) Consolidated Statements of Income for the three and nine months ended September 30, 2014 and 2013; (iii) Consolidated Statements of Comprehensive Income for the three and nine months ended September 30, 2014 and 2013; (iv) Consolidated Balance Sheets at September 30, 2014, and December 31, 2013; (v) Consolidated Statements of Cash Flows for the nine months ended September 30, 2014 and 2013; (vi) Consolidated Statement of Changes in Equity for the nine months ended September 30, 2014; and (vii) Notes to Consolidated Financial Statements.

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

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SIGNATURE

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



	ONEOK, Inc.
	Registrant


Date: November 5, 2014	By:	/s/ Derek S. Reiners
		Derek S. Reiners
		Senior Vice President,
		Chief Financial Officer and Treasurer
		(Principal Financial Officer)